ENTERGY ARKANSAS, LLC, 10-Q filed on 8/1/2025
Quarterly Report
v3.25.2
Document and Entity Information
 6 Months Ended
Jun. 30, 2025
shares
Registrant Name ENTERGY CORPORATION
City Area Code 504
Local Phone Number 576-4000
Entity Tax Identification Number 72-1229752
Entity File Number 1-11299
Central Index Key 0000065984
Document Type 10-Q
Document Period End Date Jun. 30, 2025
Amendment Flag false
Document Fiscal Year Focus 2025
Document Fiscal Period Focus Q2
Current Fiscal Year End Date --12-31
Entity Current Reporting Status Yes
Entity Filer Category Large Accelerated Filer
Entity Incorporation, State or Country Code DE
Entity Address, Address Line One 639 Loyola Avenue
Entity Address, City or Town New Orleans
Entity Address, State or Province LA
Entity Address, Postal Zip Code 70113
Entity Common Stock, Shares Outstanding 446,409,069
Entity Emerging Growth Company false
Entity Small Business false
Entity Shell Company false
Entity Interactive Data Current Yes
Document Quarterly Report true
Document Transition Report false
NEW YORK STOCK EXCHANGE, INC. [Member]  
Trading Symbol ETR
Security Exchange Name NYSE
Title of 12(b) Security Common Stock, $0.01 Par Value
NYSE CHICAGO, INC. [Member]  
Trading Symbol ETR
Title of 12(b) Security Common Stock, $0.01 Par Value
NYSE Texas  
Security Exchange Name CHX
Entergy Arkansas [Member]  
Registrant Name ENTERGY ARKANSAS, LLC
City Area Code 501
Local Phone Number 377-4000
Entity Tax Identification Number 83-1918668
Entity File Number 1-10764
Central Index Key 0000007323
Entity Current Reporting Status Yes
Entity Filer Category Non-accelerated Filer
Entity Incorporation, State or Country Code TX
Entity Address, Address Line One 425 West Capitol Avenue
Entity Address, City or Town Little Rock
Entity Address, State or Province AR
Entity Address, Postal Zip Code 72201
Entity Emerging Growth Company false
Entity Small Business false
Entity Shell Company false
Entity Interactive Data Current Yes
Entergy Louisiana [Member]  
Registrant Name ENTERGY LOUISIANA, LLC
City Area Code 504
Local Phone Number 576-4000
Entity Tax Identification Number 47-4469646
Entity File Number 1-32718
Central Index Key 0001348952
Entity Current Reporting Status Yes
Entity Filer Category Non-accelerated Filer
Entity Incorporation, State or Country Code TX
Entity Address, Address Line One 4809 Jefferson Highway
Entity Address, City or Town Jefferson
Entity Address, State or Province LA
Entity Address, Postal Zip Code 70121
Entity Emerging Growth Company false
Entity Small Business false
Entity Shell Company false
Entity Interactive Data Current Yes
Entergy Mississippi [Member]  
Registrant Name ENTERGY MISSISSIPPI, LLC
City Area Code 601
Local Phone Number 368-5000
Entity Tax Identification Number 83-1950019
Entity File Number 1-31508
Central Index Key 0000066901
Entity Current Reporting Status Yes
Entity Filer Category Non-accelerated Filer
Entity Incorporation, State or Country Code TX
Entity Address, Address Line One 308 East Pearl Street
Entity Address, City or Town Jackson
Entity Address, State or Province MS
Entity Address, Postal Zip Code 39201
Entity Emerging Growth Company false
Entity Small Business false
Entity Shell Company false
Entity Interactive Data Current Yes
Entergy New Orleans [Member]  
Registrant Name ENTERGY NEW ORLEANS, LLC
City Area Code 504
Local Phone Number 670-3702
Entity Tax Identification Number 82-2212934
Entity File Number 1-35747
Central Index Key 0000071508
Entity Current Reporting Status Yes
Entity Filer Category Non-accelerated Filer
Entity Incorporation, State or Country Code TX
Entity Address, Address Line One 1600 Perdido Street
Entity Address, City or Town New Orleans
Entity Address, State or Province LA
Entity Address, Postal Zip Code 70112
Entity Emerging Growth Company false
Entity Small Business false
Entity Shell Company false
Entity Interactive Data Current Yes
Entergy Texas [Member]  
Registrant Name ENTERGY TEXAS, INC.
City Area Code 409
Local Phone Number 981-2000
Entity Tax Identification Number 61-1435798
Entity File Number 1-34360
Central Index Key 0001427437
Entity Current Reporting Status Yes
Entity Filer Category Non-accelerated Filer
Entity Incorporation, State or Country Code TX
Entity Address, Address Line One 2107 Research Forest Drive
Entity Address, City or Town The Woodlands
Entity Address, State or Province TX
Entity Address, Postal Zip Code 77380
Entity Emerging Growth Company false
Entity Small Business false
Entity Shell Company false
Entity Interactive Data Current Yes
Title of 12(g) Security Common Stock, no par value
System Energy [Member]  
Registrant Name SYSTEM ENERGY RESOURCES, INC.
City Area Code 601
Local Phone Number 368-5000
Entity Tax Identification Number 72-0752777
Entity File Number 1-09067
Central Index Key 0000202584
Entity Current Reporting Status Yes
Entity Filer Category Non-accelerated Filer
Entity Incorporation, State or Country Code AR
Entity Address, Address Line One 1340 Echelon Parkway
Entity Address, City or Town Jackson
Entity Address, State or Province MS
Entity Address, Postal Zip Code 39213
Entity Emerging Growth Company false
Entity Small Business false
Entity Shell Company false
Entity Interactive Data Current Yes
Mortgage Bonds5.50% Series Due April 2066 [Member] | Entergy New Orleans [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]  
Trading Symbol ENO
Security Exchange Name NYSE
Title of 12(b) Security Mortgage Bonds, 5.50% Series due April 2066
Mortgage Bonds 5.0% Series Due December 2052 [Member] | Entergy New Orleans [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]  
Trading Symbol ENJ
Security Exchange Name NYSE
Title of 12(b) Security Mortgage Bonds, 5.0% Series due December 2052
Mortgage Bonds 4.90% Series Due October 2066 [Member] | Entergy Mississippi [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]  
Trading Symbol EMP
Security Exchange Name NYSE
Title of 12(b) Security Mortgage Bonds, 4.90% Series due October 2066
Mortgage Bonds 4.875% Series Due September 2066 [Member] | Entergy Arkansas [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]  
Trading Symbol EAI
Security Exchange Name NYSE
Title of 12(b) Security Mortgage Bonds, 4.875% Series due September 2066
Mortgage Bonds 4.875% Series Due September 2066 [Member] | Entergy Louisiana [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]  
Trading Symbol ELC
Security Exchange Name NYSE
Title of 12(b) Security Mortgage Bonds, 4.875% Series due September 2066
5.375% Series A Preferred Stock, Cumulative, No Par Value [Member] | Entergy Texas [Member] | NEW YORK STOCK EXCHANGE, INC. [Member]  
Trading Symbol ETI/PR
Security Exchange Name NYSE
Title of 12(b) Security 5.375% Series A Preferred Stock, Cumulative, No Par Value (Liquidation Value $25 Per Share)
v3.25.2
Consolidated Statements Of Income - USD ($)
$ in Thousands
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Revenues [Abstract]        
Revenues $ 3,328,849 $ 2,953,620 $ 6,175,723 $ 5,748,248
Operation and Maintenance:        
Utilities Operating Expense, Fuel Used 636,274 522,550 980,796 1,139,166
Utilities Operating Expense, Purchased Power 376,105 200,705 721,851 428,847
Nuclear Refueling Outage Expenses 29,613 38,277 62,654 76,540
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses 724,463 701,775 1,397,130 1,388,806
Asset Impairment Charges 0 0 0 131,775
Accretion Expense, Including Asset Retirement Obligations 56,569 54,193 112,498 107,574
Taxes, Other 201,774 187,520 400,539 379,949
Cost, Depreciation and Amortization 522,583 505,363 1,035,526 1,005,024
Other Regulatory Charges (Credits) - Net (55,957) 125,607 (72,800) 234,954
Costs and Expenses, Total 2,491,424 2,335,990 4,638,194 4,892,635
Operating Income (Loss), Total 837,425 617,630 1,537,529 855,613
Nonoperating Income (Expense) [Abstract]        
Public Utilities, Allowance for Funds Used During Construction, Capitalized Cost of Equity 51,305 29,275 95,323 56,070
Investment Income, Net 87,419 70,587 120,825 221,283
Other Nonoperating Income (Expense) (43,722) (342,549) (28,996) (393,294)
Nonoperating Income (Expense), Total 95,002 (242,687) 187,152 (115,941)
Interest Expense, Operating and Nonoperating [Abstract]        
Interest Expense, Debt 343,067 301,263 691,451 579,006
Public Utilities, Allowance for Funds Used During Construction, Additions 20,993 11,686 39,586 22,229
Interest Expense, Nonoperating, Total 322,074 289,577 651,865 556,777
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total 610,353 85,366 1,072,816 182,895
Income Tax Expense (Benefit) 138,399 33,634 238,440 54,627
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest, Total 471,954 51,732 834,376 128,268
Preferred dividend requirements of subsidiaries and net income (loss) attributable to noncontrolling interests 4,024 2,810 5,686 4,065
Net Income (Loss) Available to Common Stockholders, Basic, Total $ 467,930 $ 48,922 $ 828,690 $ 124,203
Earnings Per Share [Abstract]        
Earnings Per Share, Basic $ 1.07 $ 0.11 $ 1.91 $ 0.29
Earnings Per Share, Diluted $ 1.05 $ 0.11 $ 1.87 $ 0.29
Weighted Average Number of Shares Outstanding, Basic 439,182,369 427,234,219 434,789,473 426,760,829
Weighted Average Number of Shares Outstanding, Diluted 445,700,889 428,753,441 443,446,875 428,311,535
Electricity, US Regulated [Member]        
Revenues [Abstract]        
Revenues $ 3,274,945 $ 2,906,047 $ 6,032,811 $ 5,612,553
Natural Gas, US Regulated [Member]        
Revenues [Abstract]        
Revenues 40,778 35,357 112,509 101,024
Product and Service, Other [Member]        
Revenues [Abstract]        
Revenues 13,126 12,216 30,403 34,671
Entergy Mississippi [Member]        
Revenues [Abstract]        
Revenues 491,875 442,894 915,584 857,750
Operation and Maintenance:        
Utilities Operating Expense, Fuel Used 53,061 63,978 79,112 181,827
Utilities Operating Expense, Purchased Power 90,660 66,848 178,171 134,502
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses 85,066 67,700 163,866 138,906
Taxes, Other 43,800 37,496 87,310 75,806
Cost, Depreciation and Amortization 68,478 67,130 136,462 133,048
Other Regulatory Charges (Credits) - Net 16,767 9,873 52,354 3,382
Costs and Expenses, Total 357,832 313,025 697,275 667,471
Operating Income (Loss), Total 134,043 129,869 218,309 190,279
Nonoperating Income (Expense) [Abstract]        
Public Utilities, Allowance for Funds Used During Construction, Capitalized Cost of Equity 5,142 3,094 10,412 5,012
Investment Income, Net 6,553 948 8,870 1,141
Other Nonoperating Income (Expense) (777) (1,771) 3,317 (3,393)
Nonoperating Income (Expense), Total 10,918 2,271 22,599 2,760
Interest Expense, Operating and Nonoperating [Abstract]        
Interest Expense, Debt 36,540 28,499 72,720 54,896
Public Utilities, Allowance for Funds Used During Construction, Additions 1,966 1,204 3,982 1,951
Interest Expense, Nonoperating, Total 34,574 27,295 68,738 52,945
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total 110,387 104,845 172,170 140,094
Income Tax Expense (Benefit) 26,115 25,280 41,032 33,097
Net Income (Loss) 84,684 81,298 134,029 111,032
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest, Total 84,272 79,565 131,138 106,997
Net Income (Loss) Attributable to Noncontrolling Interest (412) (1,733) (2,891) (4,035)
Entergy Mississippi [Member] | Noncontrolling Interest [Member]        
Interest Expense, Operating and Nonoperating [Abstract]        
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest, Total (412) (1,733)    
Entergy Mississippi [Member] | Electricity, US Regulated [Member]        
Revenues [Abstract]        
Revenues 491,875 442,894 915,584 857,750
Entergy Arkansas [Member]        
Revenues [Abstract]        
Revenues 697,687 608,798 1,311,198 1,230,843
Operation and Maintenance:        
Utilities Operating Expense, Fuel Used 113,093 52,756 160,652 159,195
Utilities Operating Expense, Purchased Power 58,964 55,602 123,911 107,922
Nuclear Refueling Outage Expenses 10,668 14,101 21,249 28,189
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses 180,510 174,835 352,028 352,876
Asset Impairment Charges 0 0 0 131,775
Accretion Expense, Including Asset Retirement Obligations 24,988 22,832 49,610 45,479
Taxes, Other 35,430 34,390 71,411 70,614
Cost, Depreciation and Amortization 117,121 103,966 230,389 206,957
Other Regulatory Charges (Credits) - Net (7,763) (20,934) (12,880) 27,685
Costs and Expenses, Total 533,011 437,548 996,370 1,130,692
Operating Income (Loss), Total 164,676 171,250 314,828 100,151
Nonoperating Income (Expense) [Abstract]        
Public Utilities, Allowance for Funds Used During Construction, Capitalized Cost of Equity 5,355 5,862 9,617 11,394
Investment Income, Net 14,801 5,181 28,380 77,941
Other Nonoperating Income (Expense) (3,547) (2,799) (6,325) (6,380)
Nonoperating Income (Expense), Total 16,609 8,244 31,672 82,955
Interest Expense, Operating and Nonoperating [Abstract]        
Interest Expense, Debt 59,057 54,879 116,800 104,144
Public Utilities, Allowance for Funds Used During Construction, Additions 2,642 2,864 4,695 5,563
Interest Expense, Nonoperating, Total 56,415 52,015 112,105 98,581
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total 124,870 127,479 234,395 84,525
Income Tax Expense (Benefit) 25,677 32,120 48,679 21,446
Net Income (Loss) 100,082 96,184 187,796 65,722
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest, Total 99,193 95,359 185,716 63,079
Net Income (Loss) Attributable to Noncontrolling Interest (889) (825) (2,080) (2,643)
Entergy Arkansas [Member] | Noncontrolling Interest [Member]        
Interest Expense, Operating and Nonoperating [Abstract]        
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest, Total (889) (825)    
Entergy Arkansas [Member] | Electricity, US Regulated [Member]        
Revenues [Abstract]        
Revenues 697,687 608,798 1,311,198 1,230,843
Entergy Louisiana [Member]        
Revenues [Abstract]        
Revenues 1,510,063 1,276,124 2,811,610 2,478,564
Operation and Maintenance:        
Utilities Operating Expense, Fuel Used 326,256 246,571 540,108 486,658
Utilities Operating Expense, Purchased Power 297,179 166,868 558,967 367,148
Nuclear Refueling Outage Expenses 14,809 20,041 33,180 37,554
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses 275,187 275,168 533,224 536,147
Accretion Expense, Including Asset Retirement Obligations 19,608 20,061 39,025 39,725
Taxes, Other 68,010 70,629 134,231 140,468
Cost, Depreciation and Amortization 201,842 190,861 399,464 380,405
Other Regulatory Charges (Credits) - Net (61,915) 120,298 (109,148) 111,944
Costs and Expenses, Total 1,140,976 1,110,497 2,129,051 2,100,049
Operating Income (Loss), Total 369,087 165,627 682,559 378,515
Nonoperating Income (Expense) [Abstract]        
Public Utilities, Allowance for Funds Used During Construction, Capitalized Cost of Equity 18,470 7,522 33,676 14,807
Other Nonoperating Income (Expense) (33,797) (20,646) (16,726) (67,821)
Nonoperating Income (Expense), Total 113,467 82,180 223,403 185,657
Interest Expense, Operating and Nonoperating [Abstract]        
Interest Expense, Debt 116,524 98,536 237,858 195,731
Public Utilities, Allowance for Funds Used During Construction, Additions 6,691 2,593 12,876 5,070
Interest Expense, Nonoperating, Total 109,833 95,943 224,982 190,661
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total 372,721 151,864 680,980 373,511
Income Tax Expense (Benefit) 72,541 20,750 126,603 59,674
Net Income (Loss) 299,435 130,326 552,880 312,254
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest, Total 300,180 131,114 554,377 313,837
Net Income (Loss) Attributable to Noncontrolling Interest 745 788 1,497 1,583
Entergy Louisiana [Member] | Noncontrolling Interest [Member]        
Interest Expense, Operating and Nonoperating [Abstract]        
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest, Total 745 788    
Entergy Louisiana [Member] | Affiliated Entity [Member]        
Nonoperating Income (Expense) [Abstract]        
Investment Income, Net 75,195 80,075 151,766 160,479
Entergy Louisiana [Member] | Nonrelated Party [Member]        
Nonoperating Income (Expense) [Abstract]        
Investment Income, Net 53,599 15,229 54,687 78,192
Entergy Louisiana [Member] | Electricity, US Regulated [Member]        
Revenues [Abstract]        
Revenues 1,495,504 1,261,444 2,767,450 2,434,237
Entergy Louisiana [Member] | Natural Gas, US Regulated [Member]        
Revenues [Abstract]        
Revenues 14,559 14,680 44,160 44,327
Entergy New Orleans [Member]        
Revenues [Abstract]        
Revenues 210,000 199,341 391,055 392,302
Operation and Maintenance:        
Utilities Operating Expense, Fuel Used 26,546 18,314 38,909 49,139
Utilities Operating Expense, Purchased Power 69,126 64,318 136,867 124,700
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses 44,269 41,720 82,927 85,052
Taxes, Other 14,979 14,187 29,872 29,609
Cost, Depreciation and Amortization 22,358 21,130 44,203 42,044
Other Regulatory Charges (Credits) - Net (3,160) 1,659 (6,590) 83,179
Costs and Expenses, Total 174,118 161,328 326,188 413,723
Operating Income (Loss), Total 35,882 38,013 64,867 (21,421)
Nonoperating Income (Expense) [Abstract]        
Public Utilities, Allowance for Funds Used During Construction, Capitalized Cost of Equity 494 511 800 889
Investment Income, Net 168 316 602 457
Other Nonoperating Income (Expense) (794) 381 (1,373) 352
Nonoperating Income (Expense), Total (132) 1,208 29 1,698
Interest Expense, Operating and Nonoperating [Abstract]        
Interest Expense, Debt 12,236 10,810 25,711 20,336
Public Utilities, Allowance for Funds Used During Construction, Additions 272 214 439 371
Interest Expense, Nonoperating, Total 11,964 10,596 25,272 19,965
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total 23,786 28,625 39,624 (39,688)
Income Tax Expense (Benefit) 5,744 7,492 9,483 (11,841)
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest, Total 18,042 21,133 30,141 (27,847)
Entergy New Orleans [Member] | Electricity, US Regulated [Member]        
Revenues [Abstract]        
Revenues 183,781 178,664 322,706 335,605
Entergy New Orleans [Member] | Natural Gas, US Regulated [Member]        
Revenues [Abstract]        
Revenues 26,219 20,677 68,349 56,697
Entergy Texas [Member]        
Revenues [Abstract]        
Revenues 531,641 519,077 973,580 963,568
Operation and Maintenance:        
Utilities Operating Expense, Fuel Used 96,736 115,520 121,128 211,657
Utilities Operating Expense, Purchased Power 124,880 88,713 257,498 183,056
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses 83,818 83,176 158,273 161,136
Taxes, Other 29,792 22,979 60,419 47,546
Cost, Depreciation and Amortization 80,830 90,824 161,510 180,329
Other Regulatory Charges (Credits) - Net 2,587 (12,477) 5,844 (13,452)
Costs and Expenses, Total 418,643 388,735 764,672 770,272
Operating Income (Loss), Total 112,998 130,342 208,908 193,296
Nonoperating Income (Expense) [Abstract]        
Public Utilities, Allowance for Funds Used During Construction, Capitalized Cost of Equity 19,963 10,834 37,335 20,082
Investment Income, Net 1,975 2,791 4,734 6,695
Other Nonoperating Income (Expense) (2,477) (3,186) (3,631) (5,498)
Nonoperating Income (Expense), Total 19,461 10,439 38,438 21,279
Interest Expense, Operating and Nonoperating [Abstract]        
Interest Expense, Debt 43,147 34,483 86,219 66,449
Public Utilities, Allowance for Funds Used During Construction, Additions 8,502 4,219 15,887 7,821
Interest Expense, Nonoperating, Total 34,645 30,264 70,332 58,628
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total 97,814 110,517 177,014 155,947
Income Tax Expense (Benefit) 16,318 20,295 28,662 28,981
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest, Total 81,496 90,222 148,352 126,966
Preferred Stock Dividends, Income Statement Impact 518 518 1,036 1,036
Net Income (Loss) Available to Common Stockholders, Basic, Total 80,978 89,704 147,316 125,930
Entergy Texas [Member] | Electricity, US Regulated [Member]        
Revenues [Abstract]        
Revenues 531,641 519,077 973,580 963,568
System Energy [Member]        
Revenues [Abstract]        
Revenues 143,858 145,934 285,669 298,554
Operation and Maintenance:        
Utilities Operating Expense, Fuel Used 16,122 17,120 30,938 30,237
Nuclear Refueling Outage Expenses 4,135 4,136 8,225 10,797
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses 47,016 45,746 90,495 97,169
Accretion Expense, Including Asset Retirement Obligations 11,257 10,815 22,401 21,522
Taxes, Other 6,555 6,892 13,359 14,101
Cost, Depreciation and Amortization 31,063 30,443 61,827 60,121
Other Regulatory Charges (Credits) - Net (2,473) 27,188 (2,380) 22,215
Costs and Expenses, Total 113,675 142,340 224,865 256,162
Operating Income (Loss), Total 30,183 3,594 60,804 42,392
Nonoperating Income (Expense) [Abstract]        
Public Utilities, Allowance for Funds Used During Construction, Capitalized Cost of Equity 1,881 1,451 3,484 3,885
Investment Income, Net 10,672 38,967 23,111 46,940
Other Nonoperating Income (Expense) 56 (165) 293 72
Nonoperating Income (Expense), Total 12,609 40,253 26,888 50,897
Interest Expense, Operating and Nonoperating [Abstract]        
Interest Expense, Debt 17,270 12,072 33,292 23,243
Public Utilities, Allowance for Funds Used During Construction, Additions 922 594 1,709 1,453
Interest Expense, Nonoperating, Total 16,348 11,478 31,583 21,790
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest, Total 26,444 32,369 56,109 71,499
Income Tax Expense (Benefit) 5,119 7,521 11,395 15,533
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest, Total $ 21,325 $ 24,848 $ 44,714 $ 55,966
v3.25.2
Consolidated Statements Of Cash Flows - USD ($)
$ in Thousands
 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Dec. 31, 2024
Dec. 31, 2023
Net Cash Provided by (Used in) Operating Activities [Abstract]        
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest $ 834,376 $ 128,268    
Consolidated Net Income Adjustments To Reconcile Consolidated Net Income To Net Cash Flow [Abstract]        
Depreciation, Amortization and Accretion, Net 1,255,204 1,206,492    
Deferred Income Taxes and Tax Credits 231,274 15,998    
Asset Impairment Charges 0 131,775    
Pension Expense (Reversal of Expense), Noncash 0 316,738    
Changes In Working Capital [Abstract]        
Increase (Decrease) in Receivables (275,045) (187,554)    
Increase (Decrease) in Fuel Inventories (4,852) 18,324    
Increase (Decrease) in Accounts Payable (53,439) (149,554)    
Increase (Decrease) in Accrued Taxes Payable 11,230 16,546    
Increase (Decrease) in Interest Payable, Net 22,867 23,560    
Increase (Decrease) in Deferred Fuel Costs (263,205) 134,953    
Increase (Decrease) in Other Operating Assets and Liabilities, Net 244,972 (120,277)    
Provision for Other Losses (38,444) 4,630    
Increase (Decrease) in Other Regulatory Assets 174,523 260,722    
Increase (Decrease) in Regulatory Liabilities 20,040 380,394    
Increase (Decrease) in Obligation, Pension and Other Postretirement Benefits (104,968) (131,539)    
Other Operating Activities, Cash Flow Statement (256,743) (503,020)    
Net Cash Provided by (Used in) Operating Activities, Total 1,797,790 1,546,456    
Net Cash Provided by (Used in) Investing Activities [Abstract]        
Payments to Acquire Property, Plant, and Equipment 3,668,326 2,124,279    
Allowance for Funds Used During Construction, Investing Activities 83,161 56,070    
Payments for Nuclear Fuel (129,124) (161,483)    
Payments for (Proceeds from) Productive Assets 1,608 172,614    
Payments for (Proceeds from) Other Investing Activities (1,659) (9,689)    
Proceeds from Decommissioning Trust Fund Assets 713,102 1,201,162    
Payments to Acquire Investments to be Held in Decommissioning Trust Fund (780,211) (1,250,039)    
Changes in securitization account 3,309 3,976    
Payments to storm reserve escrow accounts 6,808 9,595    
Receipts from storm reserve escrow accounts 43,789 0    
Payments for (Proceeds from) Other Investing Activities 1,659 9,689    
Litigation proceeds for reimbursement of spent nuclear fuel storage costs 3,546 0    
Net Cash Provided by (Used in) Investing Activities, Total (3,740,829) (2,466,491)    
Proceeds From Issuance Of [Abstract]        
Proceeds from Issuance of Long-Term Debt (3,517,949) (5,068,266)    
Proceeds from Sale of Treasury Stock 24,539 45,982    
Proceeds from Issuance of Common Stock 804,631 0    
Repayments of Long-Term Debt (1,599,728) (2,379,903)    
Dividends Paid [Abstract]        
Payments of Ordinary Dividends, Common Stock (516,716) (482,255)    
Payments of Ordinary Dividends, Preferred Stock and Preference Stock 9,159 9,159    
Proceeds from Advance for and Contribution in Aid of Construction, Financing Activity 732,454 192,426    
Payment for Advance for Construction, Financing Activity (245,481) (76,768)    
Proceeds from (Repayments of) Short-Term Debt (451,686) (205,820)    
Proceeds from (Payments for) Other Financing Activities 2,164 (10,118)    
Net Cash Provided by (Used in) Financing Activities, Total 2,258,967 2,142,651    
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total 315,928 1,222,616    
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents 1,175,631 1,355,164 $ 859,703 $ 132,548
Cash Paid Received During Period For [Abstract]        
Interest Paid, Excluding Capitalized Interest, Operating Activities 647,900 532,742    
Income Taxes Paid, Net 2,487 7,822    
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]        
Capital Expenditures Incurred but Not yet Paid 576,992 537,463    
Entergy Arkansas [Member]        
Net Cash Provided by (Used in) Operating Activities [Abstract]        
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest 185,716 63,079    
Consolidated Net Income Adjustments To Reconcile Consolidated Net Income To Net Cash Flow [Abstract]        
Depreciation, Amortization and Accretion, Net 324,540 287,564    
Deferred Income Taxes and Tax Credits 65,494 41,130    
Asset Impairment Charges 0 131,775    
Changes In Working Capital [Abstract]        
Increase (Decrease) in Receivables (63,276) 67,067    
Increase (Decrease) in Fuel Inventories (14,868) 10,890    
Increase (Decrease) in Accounts Payable 43,551 26,093    
Increase (Decrease) in Accrued Taxes Payable (19,741) (15,496)    
Increase (Decrease) in Interest Payable, Net 69 4,647    
Increase (Decrease) in Deferred Fuel Costs (33,234) 2,317    
Increase (Decrease) in Other Operating Assets and Liabilities, Net (25,426) (13,243)    
Provision for Other Losses (2,436) 5,725    
Increase (Decrease) in Other Regulatory Assets (4,658) 179,719    
Increase (Decrease) in Regulatory Liabilities 65,970 71,529    
Increase (Decrease) in Obligation, Pension and Other Postretirement Benefits (20,651) (27,588)    
Other Operating Activities, Cash Flow Statement (63,163) (310,500)    
Net Cash Provided by (Used in) Operating Activities, Total 437,887 524,708    
Net Cash Provided by (Used in) Investing Activities [Abstract]        
Payments to Acquire Property, Plant, and Equipment 400,384 394,973    
Allowance for Funds Used During Construction, Investing Activities 9,617 11,394    
Payments for Nuclear Fuel (73,283) (65,010)    
Payments for (Proceeds from) Productive Assets 1,608 169,694    
Proceeds from Nuclear Fuel 40,601 33,213    
Change in money pool receivable - net (49,019) (130,602)    
Payments for (Proceeds from) Other Investing Activities 51 30    
Proceeds from Decommissioning Trust Fund Assets 51,462 412,931    
Payments to Acquire Investments to be Held in Decommissioning Trust Fund (70,616) (418,818)    
Payments for (Proceeds from) Other Investing Activities (51) (30)    
Net Cash Provided by (Used in) Investing Activities, Total (493,179) (721,529)    
Proceeds From Issuance Of [Abstract]        
Proceeds from Issuance of Long-Term Debt (350,312) (970,030)    
Repayments of Long-Term Debt (40,311) (555,411)    
Proceeds from Contributions from Parent 0 695,000    
Change in money pool payable - net (15,190) (145,385)    
Dividends Paid [Abstract]        
Proceeds from (Payments for) Other Financing Activities (17,278) 15,287    
Net Cash Provided by (Used in) Financing Activities, Total 277,533 979,521    
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total 222,241 782,700    
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents 226,988 786,332 4,747 3,632
Cash Paid Received During Period For [Abstract]        
Interest Paid, Excluding Capitalized Interest, Operating Activities 115,404 49,597    
Income Taxes Paid, Net 0 1,569    
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]        
Capital Expenditures Incurred but Not yet Paid 77,169 36,355    
Entergy Louisiana [Member]        
Net Cash Provided by (Used in) Operating Activities [Abstract]        
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest 554,377 313,837    
Consolidated Net Income Adjustments To Reconcile Consolidated Net Income To Net Cash Flow [Abstract]        
Depreciation, Amortization and Accretion, Net 474,334 453,888    
Deferred Income Taxes and Tax Credits 225,635 146,540    
Changes In Working Capital [Abstract]        
Increase (Decrease) in Receivables (122,848) (161,001)    
Increase (Decrease) in Fuel Inventories 8,300 6,890    
Increase (Decrease) in Accounts Payable 9,253 (1,443)    
Increase (Decrease) in Accrued Taxes Payable (790) 27,677    
Increase (Decrease) in Interest Payable, Net 10,430 14,163    
Increase (Decrease) in Deferred Fuel Costs (92,390) 11,364    
Increase (Decrease) in Other Operating Assets and Liabilities, Net 77,581 (190,407)    
Provision for Other Losses (23,918) 9,519    
Increase (Decrease) in Other Regulatory Assets 48,355 (9,005)    
Increase (Decrease) in Regulatory Liabilities (70,161) 286,036    
Increase (Decrease) in Obligation, Pension and Other Postretirement Benefits (18,124) (22,548)    
Other Operating Activities, Cash Flow Statement (101,335) (77,112)    
Net Cash Provided by (Used in) Operating Activities, Total 978,699 808,398    
Net Cash Provided by (Used in) Investing Activities [Abstract]        
Payments to Acquire Property, Plant, and Equipment 1,450,693 685,206    
Allowance for Funds Used During Construction, Investing Activities 26,560 14,807    
Proceeds from Sale of Productive Assets 366 0    
Payments for Nuclear Fuel (130,279) (52,992)    
Proceeds from Nuclear Fuel 17,240 38,822    
Change in money pool receivable - net (48,540) (31,361)    
Redemption of preferred membership interests of affiliate 118,805 113,942    
Payments for (Proceeds from) Other Investing Activities 0 33    
Proceeds from Decommissioning Trust Fund Assets 291,901 333,149    
Payments to Acquire Investments to be Held in Decommissioning Trust Fund (321,342) (363,736)    
Payments to storm reserve escrow accounts 5,144 6,553    
Receipts from storm reserve escrow accounts 33,456 0    
Payments for (Proceeds from) Other Investing Activities 0 (33)    
Net Cash Provided by (Used in) Investing Activities, Total (1,467,670) (639,095)    
Proceeds From Issuance Of [Abstract]        
Proceeds from Issuance of Long-Term Debt (1,465,747) (1,825,954)    
Repayments of Long-Term Debt (936,318) (1,061,918)    
Change in money pool payable - net 0 (156,166)    
Dividends Paid [Abstract]        
Proceeds from Advance for and Contribution in Aid of Construction, Financing Activity 548,476 113,712    
Payment for Advance for Construction, Financing Activity (117,339) (39,888)    
Proceeds from (Payments for) Other Financing Activities (4,247) (3,888)    
Net Cash Provided by (Used in) Financing Activities, Total 461,319 13,706    
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total (27,652) 183,009    
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents 299,450 185,781 327,102 2,772
Cash Paid Received During Period For [Abstract]        
Interest Paid, Excluding Capitalized Interest, Operating Activities 222,889 177,455    
Income Taxes Paid, Net 0 58    
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]        
Capital Expenditures Incurred but Not yet Paid 258,408 81,177    
Distribution Made to Limited Liability Company (LLC) Member, Cash Distributions Paid (495,000) (664,100)    
Entergy Mississippi [Member]        
Net Cash Provided by (Used in) Operating Activities [Abstract]        
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest 131,138 106,997    
Consolidated Net Income Adjustments To Reconcile Consolidated Net Income To Net Cash Flow [Abstract]        
Depreciation, Amortization and Accretion, Net 136,462 133,048    
Deferred Income Taxes and Tax Credits (19,714) 24,931    
Changes In Working Capital [Abstract]        
Increase (Decrease) in Receivables (41,738) (26,254)    
Increase (Decrease) in Fuel Inventories (4,855) (2,331)    
Increase (Decrease) in Accounts Payable (9,305) 475    
Increase (Decrease) in Accrued Taxes Payable (3,929) (48,627)    
Increase (Decrease) in Interest Payable, Net 9,125 (1,845)    
Increase (Decrease) in Deferred Fuel Costs (64,303) 41,104    
Increase (Decrease) in Other Operating Assets and Liabilities, Net 85,185 (18,367)    
Provision for Other Losses (3,962) (11,575)    
Increase (Decrease) in Other Regulatory Assets 52,132 5,325    
Increase (Decrease) in Regulatory Liabilities (1,066) (3,415)    
Increase (Decrease) in Obligation, Pension and Other Postretirement Benefits (6,261) (8,968)    
Other Operating Activities, Cash Flow Statement 28,104 (5,194)    
Net Cash Provided by (Used in) Operating Activities, Total 287,013 185,304    
Net Cash Provided by (Used in) Investing Activities [Abstract]        
Payments to Acquire Property, Plant, and Equipment 703,400 319,053    
Allowance for Funds Used During Construction, Investing Activities 5,365 5,012    
Change in money pool receivable - net (93,459) 0    
Payments for (Proceeds from) Other Investing Activities 46 (104)    
Payments for (Proceeds from) Other Investing Activities (46) 104    
Net Cash Provided by (Used in) Investing Activities, Total (791,448) (314,145)    
Proceeds From Issuance Of [Abstract]        
Proceeds from Issuance of Long-Term Debt (592,679) (396,105)    
Repayments of Long-Term Debt 0 (200,000)    
Proceeds from Contributions from Parent 62,500 0    
Change in money pool payable - net 0 (33,414)    
Dividends Paid [Abstract]        
Proceeds from Advance for and Contribution in Aid of Construction, Financing Activity 155,594 4,290    
Payment for Advance for Construction, Financing Activity (59,271) (18,080)    
Proceeds from (Payments for) Other Financing Activities (1,394) (1,277)    
Net Cash Provided by (Used in) Financing Activities, Total 750,108 125,324    
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total 245,673 (3,517)    
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents 401,366 3,113 155,693 6,630
Cash Paid Received During Period For [Abstract]        
Interest Paid, Excluding Capitalized Interest, Operating Activities 62,373 55,538    
Income Taxes Paid, Net 0 2,356    
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]        
Capital Expenditures Incurred but Not yet Paid 78,363 22,334    
Distribution Made to Limited Liability Company (LLC) Member, Cash Distributions Paid 0 (22,300)    
Entergy New Orleans [Member]        
Net Cash Provided by (Used in) Operating Activities [Abstract]        
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest 30,141 (27,847)    
Consolidated Net Income Adjustments To Reconcile Consolidated Net Income To Net Cash Flow [Abstract]        
Depreciation, Amortization and Accretion, Net 44,203 42,044    
Deferred Income Taxes and Tax Credits (9,350) (19,560)    
Changes In Working Capital [Abstract]        
Increase (Decrease) in Receivables (22,585) (111,913)    
Increase (Decrease) in Fuel Inventories (1,188) 544    
Increase (Decrease) in Accounts Payable (5,661) (10,311)    
Increase (Decrease) in Accrued Taxes Payable 19,556 7,345    
Increase (Decrease) in Interest Payable, Net (2,629) (1,220)    
Increase (Decrease) in Deferred Fuel Costs (4,203) (51)    
Increase (Decrease) in Other Operating Assets and Liabilities, Net (8,825) (8,120)    
Provision for Other Losses (10,772) 2,473    
Increase (Decrease) in Other Regulatory Assets 10,338 11,073    
Increase (Decrease) in Regulatory Liabilities (13,791) 167,529    
Increase (Decrease) in Obligation, Pension and Other Postretirement Benefits (4,804) (3,876)    
Other Operating Activities, Cash Flow Statement 3,222 (2,694)    
Net Cash Provided by (Used in) Operating Activities, Total 23,652 45,416    
Net Cash Provided by (Used in) Investing Activities [Abstract]        
Payments to Acquire Property, Plant, and Equipment 91,611 72,409    
Allowance for Funds Used During Construction, Investing Activities 800 889    
Change in money pool receivable - net 3,146 (1,110)    
Changes in securitization account 1,611 1,120    
Payments to storm reserve escrow accounts 1,664 2,939    
Receipts from storm reserve escrow accounts 10,333 0    
Net Cash Provided by (Used in) Investing Activities, Total (77,385) (74,449)    
Proceeds From Issuance Of [Abstract]        
Proceeds from Issuance of Long-Term Debt (79,717) (149,075)    
Repayments of Long-Term Debt (78,000) (91,245)    
Change in money pool payable - net 20,884 (21,651)    
Dividends Paid [Abstract]        
Proceeds from (Payments for) Other Financing Activities (619) (614)    
Net Cash Provided by (Used in) Financing Activities, Total 21,982 35,565    
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total (31,751) 6,532    
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents 26 6,558 31,777 26
Cash Paid Received During Period For [Abstract]        
Interest Paid, Excluding Capitalized Interest, Operating Activities 27,816 20,159    
Income Taxes Paid, Net 0 2,598    
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]        
Capital Expenditures Incurred but Not yet Paid 5,059 4,263    
Entergy Texas [Member]        
Net Cash Provided by (Used in) Operating Activities [Abstract]        
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest 148,352 126,966    
Consolidated Net Income Adjustments To Reconcile Consolidated Net Income To Net Cash Flow [Abstract]        
Depreciation, Amortization and Accretion, Net 161,510 180,329    
Deferred Income Taxes and Tax Credits 21,466 21,112    
Changes In Working Capital [Abstract]        
Increase (Decrease) in Receivables (36,849) (64,108)    
Increase (Decrease) in Fuel Inventories 9,817 1,877    
Increase (Decrease) in Accounts Payable 37,267 13,853    
Increase (Decrease) in Accrued Taxes Payable (20,591) (21,155)    
Increase (Decrease) in Interest Payable, Net 5,971 (561)    
Increase (Decrease) in Deferred Fuel Costs (69,075) 80,220    
Increase (Decrease) in Other Operating Assets and Liabilities, Net (6,447) (9,386)    
Provision for Other Losses 1,201 (1,384)    
Increase (Decrease) in Other Regulatory Assets 60,125 40,197    
Increase (Decrease) in Regulatory Liabilities (13,317) (26,028)    
Increase (Decrease) in Obligation, Pension and Other Postretirement Benefits (7,131) (8,190)    
Other Operating Activities, Cash Flow Statement (49,963) (41,322)    
Net Cash Provided by (Used in) Operating Activities, Total 242,336 292,420    
Net Cash Provided by (Used in) Investing Activities [Abstract]        
Payments to Acquire Property, Plant, and Equipment 932,013 522,890    
Allowance for Funds Used During Construction, Investing Activities 37,335 20,082    
Change in money pool receivable - net 13,669 296,670    
Payments for (Proceeds from) Other Investing Activities 0 (12,660)    
Changes in securitization account 1,698 2,856    
Payments for (Proceeds from) Other Investing Activities 0 12,660    
Net Cash Provided by (Used in) Investing Activities, Total (879,311) (215,942)    
Proceeds From Issuance Of [Abstract]        
Proceeds from Issuance of Long-Term Debt (493,772) 0    
Repayments of Long-Term Debt (9,359) (9,104)    
Dividends Paid [Abstract]        
Payments of Ordinary Dividends, Preferred Stock and Preference Stock 1,036 1,036    
Proceeds from (Payments for) Other Financing Activities (13,656) 36,582    
Net Cash Provided by (Used in) Financing Activities, Total 469,721 26,442    
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total (167,254) 102,920    
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents 17,743 124,906 184,997 21,986
Cash Paid Received During Period For [Abstract]        
Interest Paid, Excluding Capitalized Interest, Operating Activities 78,477 65,529    
Income Taxes Paid, Net 2,077 5,862    
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]        
Capital Expenditures Incurred but Not yet Paid 127,069 343,525    
System Energy [Member]        
Net Cash Provided by (Used in) Operating Activities [Abstract]        
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest 44,714 55,966    
Consolidated Net Income Adjustments To Reconcile Consolidated Net Income To Net Cash Flow [Abstract]        
Depreciation, Amortization and Accretion, Net 111,023 106,652    
Deferred Income Taxes and Tax Credits 11,063 28,258    
Changes In Working Capital [Abstract]        
Increase (Decrease) in Receivables 722 (9,335)    
Increase (Decrease) in Accounts Payable (18,674) 74,527    
Increase (Decrease) in Accrued Taxes Payable (10,605) (19,301)    
Increase (Decrease) in Interest Payable, Net (99) (620)    
Increase (Decrease) in Other Operating Assets and Liabilities, Net 344 (27,233)    
Increase (Decrease) in Other Regulatory Assets 1,716 21,178    
Increase (Decrease) in Regulatory Liabilities 52,405 (115,256)    
Increase (Decrease) in Obligation, Pension and Other Postretirement Benefits (6,875) (6,952)    
Other Operating Activities, Cash Flow Statement (54,233) (80,464)    
Net Cash Provided by (Used in) Operating Activities, Total 131,501 27,420    
Net Cash Provided by (Used in) Investing Activities [Abstract]        
Payments to Acquire Property, Plant, and Equipment 51,746 87,410    
Allowance for Funds Used During Construction, Investing Activities 3,484 3,885    
Payments for Nuclear Fuel (26,957) (115,544)    
Proceeds from Nuclear Fuel 43,555 21    
Change in money pool receivable - net (5,810) (5,238)    
Payments for (Proceeds from) Other Investing Activities 0 23    
Proceeds from Decommissioning Trust Fund Assets 369,739 455,082    
Payments to Acquire Investments to be Held in Decommissioning Trust Fund (388,253) (467,485)    
Payments for (Proceeds from) Other Investing Activities 0 (23)    
Net Cash Provided by (Used in) Investing Activities, Total (55,988) (216,666)    
Proceeds From Issuance Of [Abstract]        
Proceeds from Issuance of Long-Term Debt (538,108) (544,736)    
Repayments of Long-Term Debt (535,740) (462,226)    
Proceeds from Contributions from Parent 0 150,000    
Change in money pool payable - net 0 (12,246)    
Dividends Paid [Abstract]        
Payments of Ordinary Dividends, Common Stock (75,000) 0    
Net Cash Provided by (Used in) Financing Activities, Total (72,632) 220,264    
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents, Period Increase (Decrease), Including Exchange Rate Effect, Total 2,881 31,018    
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents 31,789 31,078 $ 28,908 $ 60
Cash Paid Received During Period For [Abstract]        
Interest Paid, Excluding Capitalized Interest, Operating Activities 33,146 25,231    
Income Taxes Paid, Net 0 (2,326)    
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]        
Capital Expenditures Incurred but Not yet Paid $ 8,448 $ 24,234    
v3.25.2
Consolidated Balance Sheets - USD ($)
$ in Thousands
Jun. 30, 2025
Dec. 31, 2024
Cash and Cash Equivalents [Abstract]    
Cash $ 164,024 $ 48,424
Cash Equivalents, at Carrying Value 1,011,607 811,279
Cash and Cash Equivalents, at Carrying Value, Total 1,175,631 859,703
Accounts Receivable [Abstract]    
Accounts Receivable, before Allowance for Credit Loss, Current 839,379 681,504
Accounts Receivable, Allowance for Credit Loss, Current (23,010) (17,919)
Other Receivables 253,458 204,868
Unbilled Receivables, Current 595,617 521,946
Accounts and Other Receivables, Net, Current 1,665,444 1,390,399
Deferred Fuel Cost 99,774 0
Energy Related Inventory 170,925 166,408
Public Utilities, Inventory 1,627,718 1,631,056
Prepaid Expense and Other Assets, Current 327,284 233,212
Deferred Nuclear Refueling Outage Costs 103,072 99,885
Assets, Current, Total 5,189,450 4,396,237
Assets, Noncurrent [Abstract]    
Decommissioning Fund Investments 5,833,432 5,562,575
Property, Plant and Equipment, Net 468,635 423,764
Asset Recovery Damaged Property Costs, Noncurrent 303,479 340,460
Other Long-Term Investments 84,411 82,344
Long-Term Investments, Total 6,689,957 6,409,143
Public Utilities, Property, Plant and Equipment, Net [Abstract]    
Public Utilities, Property, Plant and Equipment, Electric 72,332,650 70,818,667
Public Utilities, Property, Plant and Equipment, Natural Gas 78,182 77,054
Public Utilities, Property, Plant and Equipment, Construction Work in Progress 5,014,935 3,206,308
Public Utilities, Property, Plant and Equipment, Fuel 727,407 765,661
Public Utilities, Property, Plant and Equipment, Plant in Service, Total 78,153,174 74,867,690
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation 28,147,570 27,444,740
Public Utilities, Property, Plant and Equipment, Net, Total 50,005,604 47,422,950
Regulatory Asset [Abstract]    
Regulatory Asset, Noncurrent 5,082,842 5,255,509
Deferred Fuel Cost, Noncurrent 172,201 172,201
Goodwill 367,582 367,625
Deferred Income Tax Assets, Net 24,777 18,986
Other Assets, Noncurrent 378,199 284,584
Deferred Costs and Other Assets 6,498,129 6,561,702
Assets, Total 68,383,140 64,790,032
Liabilities, Current [Abstract]    
Long-Term Debt, Current Maturities 1,815,112 1,378,090
Short-Term Debt 475,605 927,291
Accounts Payable, Current 2,133,797 1,929,162
Contract with Customer, Refund Liability, Current 477,258 462,436
Taxes Payable, Current 468,336 457,093
Interest Payable, Current 282,421 259,554
Deferred Fuel Costs Current Liabilities 73,937 237,146
Liability, Defined Benefit Plan, Current 61,457 64,854
Other Liabilities, Current 269,496 243,749
Liabilities, Current, Total 6,512,873 6,111,037
Liabilities, Noncurrent [Abstract]    
Deferred Income Taxes and Other Tax Liabilities, Noncurrent 4,733,580 4,467,748
Accumulated Deferred Investment Tax Credit 189,849 194,146
Regulatory Liability For Income Taxes - Net 1,140,587 1,168,078
Regulatory Liability, Noncurrent 3,659,163 3,609,463
Asset Retirement Obligations, Noncurrent 4,825,364 4,713,426
Loss Contingency Accrual 467,619 506,063
Liability, Defined Benefit Plan, Noncurrent 180,062 254,704
Long-Term Debt, Excluding Current Maturities 28,114,726 26,613,505
Deferred Credits and Other Liabilities 909,408 1,112,881
Liabilities, Noncurrent, Total 45,341,917 43,274,601
Commitments and Contingencies
Temporary Equity, Carrying Amount, Attributable to Parent 219,410 219,410
Common Shareholders Equity [Abstract]    
Preferred Stock, Value, Issued 0 0
Common Stock, Value, Issued 5,775 5,620
Additional Paid in Capital, Common Stock 8,612,713 7,833,525
Retained Earnings (Accumulated Deficit) 12,326,289 12,014,315
Accumulated Other Comprehensive Income (Loss), Net of Tax 34,438 42,769
Treasury Stock, Value 4,766,215 4,812,321
Equity, Attributable to Parent, Total 16,213,000 15,083,908
Equity, Attributable to Noncontrolling Interest 95,940 101,076
Equity, Including Portion Attributable to Noncontrolling Interest, Total 16,308,940 15,184,984
Liabilities and Equity, Total 68,383,140 64,790,032
Customer Advances, Current Liabilities 455,454 151,662
Customer advances for construction, noncurrent 1,121,559 634,587
Disposal Group, Including Discontinued Operation, Assets, Current 19,602 15,574
Disposal Group, Including Discontinued Operation, Assets, Noncurrent $ 472,528 $ 462,797
Common Stock, Shares, Issued 577,511,170 561,950,696
Entergy Arkansas [Member]    
Cash and Cash Equivalents [Abstract]    
Cash $ 44,574 $ 1,306
Cash Equivalents, at Carrying Value 182,414 3,441
Cash and Cash Equivalents, at Carrying Value, Total 226,988 4,747
Accounts Receivable [Abstract]    
Accounts Receivable, Allowance for Credit Loss, Current (6,356) (4,672)
Other Receivables 97,188 70,927
Unbilled Receivables, Current 148,697 125,824
Accounts and Other Receivables, Net, Current 479,020 366,725
Energy Related Inventory 64,805 49,937
Public Utilities, Inventory 426,029 384,238
Prepaid Expense and Other Assets, Current 55,249 41,404
Deferred Nuclear Refueling Outage Costs 27,408 48,879
Assets, Current, Total 1,279,499 895,930
Assets, Noncurrent [Abstract]    
Decommissioning Fund Investments 1,686,652 1,604,428
Other Long-Term Investments 795 797
Long-Term Investments, Total 1,687,447 1,605,225
Public Utilities, Property, Plant and Equipment, Net [Abstract]    
Public Utilities, Property, Plant and Equipment, Electric 16,502,576 16,371,182
Public Utilities, Property, Plant and Equipment, Construction Work in Progress 576,593 320,447
Public Utilities, Property, Plant and Equipment, Fuel 229,701 257,533
Public Utilities, Property, Plant and Equipment, Plant in Service, Total 17,308,870 16,949,162
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation 6,452,925 6,275,150
Public Utilities, Property, Plant and Equipment, Net, Total 10,855,945 10,674,012
Regulatory Asset [Abstract]    
Regulatory Asset, Noncurrent 1,704,768 1,700,110
Other Assets, Noncurrent 212,976 198,706
Deferred Costs and Other Assets 1,917,744 1,898,816
Assets, Total 15,740,635 15,073,983
Liabilities, Current [Abstract]    
Long-Term Debt, Current Maturities 600,000 0
Contract with Customer, Refund Liability, Current 132,692 129,267
Taxes Payable, Current 73,474 93,215
Interest Payable, Current 38,446 38,377
Deferred Fuel Costs Current Liabilities 11,924 45,158
Other Liabilities, Current 64,932 55,313
Liabilities, Current, Total 1,281,769 656,507
Liabilities, Noncurrent [Abstract]    
Deferred Income Taxes and Other Tax Liabilities, Noncurrent 1,550,533 1,489,169
Accumulated Deferred Investment Tax Credit 25,469 26,069
Regulatory Liability For Income Taxes - Net 425,296 417,561
Regulatory Liability, Noncurrent 889,400 831,165
Asset Retirement Obligations, Noncurrent 1,741,194 1,691,583
Loss Contingency Accrual 74,043 76,479
Long-Term Debt, Excluding Current Maturities 4,838,033 5,122,494
Deferred Credits and Other Liabilities 265,633 298,951
Liabilities, Noncurrent, Total 9,809,601 9,953,471
Commitments and Contingencies
Common Shareholders Equity [Abstract]    
Members' Equity 4,636,633 4,448,837
Equity, Attributable to Noncontrolling Interest 12,632 15,168
Equity, Including Portion Attributable to Noncontrolling Interest, Total 4,649,265 4,464,005
Liabilities and Equity, Total 15,740,635 15,073,983
Entergy Arkansas [Member] | Affiliated Entity [Member]    
Accounts Receivable [Abstract]    
Accounts Receivable, before Allowance for Credit Loss, Current 82,913 35,412
Liabilities, Current [Abstract]    
Accounts Payable, Current 49,653 85,137
Entergy Arkansas [Member] | Nonrelated Party [Member]    
Accounts Receivable [Abstract]    
Accounts Receivable, before Allowance for Credit Loss, Current 156,578 139,234
Liabilities, Current [Abstract]    
Accounts Payable, Current 310,648 210,040
Entergy Louisiana [Member]    
Cash and Cash Equivalents [Abstract]    
Cash 1,186 327
Cash Equivalents, at Carrying Value 298,264 326,775
Cash and Cash Equivalents, at Carrying Value, Total 299,450 327,102
Accounts Receivable [Abstract]    
Accounts Receivable, Allowance for Credit Loss, Current (6,246) (3,036)
Other Receivables 67,705 39,056
Unbilled Receivables, Current 222,520 213,026
Accounts and Other Receivables, Net, Current 817,578 646,190
Deferred Fuel Cost 84,372 0
Energy Related Inventory 41,622 49,515
Public Utilities, Inventory 718,589 782,459
Prepaid Expense and Other Assets, Current 273,298 84,236
Deferred Nuclear Refueling Outage Costs 63,821 31,121
Assets, Current, Total 2,303,575 1,923,097
Assets, Noncurrent [Abstract]    
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures 4,138,191 4,256,997
Decommissioning Fund Investments 2,540,476 2,429,088
Property, Plant and Equipment, Net 455,274 410,611
Asset Recovery Damaged Property Costs, Noncurrent 228,406 256,718
Other Long-Term Investments 9,969 9,749
Long-Term Investments, Total 7,372,316 7,363,163
Public Utilities, Property, Plant and Equipment, Net [Abstract]    
Public Utilities, Property, Plant and Equipment, Electric 29,556,060 28,736,547
Public Utilities, Property, Plant and Equipment, Natural Gas 34,460 33,775
Public Utilities, Property, Plant and Equipment, Construction Work in Progress 1,350,603 761,090
Public Utilities, Property, Plant and Equipment, Fuel 339,822 288,084
Public Utilities, Property, Plant and Equipment, Plant in Service, Total 31,280,945 29,819,496
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation 11,019,307 10,794,817
Public Utilities, Property, Plant and Equipment, Net, Total 20,261,638 19,024,679
Regulatory Asset [Abstract]    
Regulatory Asset, Noncurrent 1,591,621 1,637,967
Deferred Fuel Cost, Noncurrent 168,122 168,122
Other Assets, Noncurrent 76,624 57,853
Deferred Costs and Other Assets 2,015,113 2,037,611
Assets, Total 31,952,642 30,348,550
Liabilities, Current [Abstract]    
Long-Term Debt, Current Maturities 250,000 300,000
Contract with Customer, Refund Liability, Current 173,957 169,544
Taxes Payable, Current 28,225 29,002
Interest Payable, Current 130,616 120,186
Deferred Fuel Costs Current Liabilities 0 5,421
Other Liabilities, Current 119,510 96,426
Liabilities, Current, Total 1,826,304 1,514,016
Liabilities, Noncurrent [Abstract]    
Deferred Income Taxes and Other Tax Liabilities, Noncurrent 2,726,823 2,477,954
Accumulated Deferred Investment Tax Credit 86,428 88,679
Regulatory Liability For Income Taxes - Net 339,104 355,432
Regulatory Liability, Noncurrent 1,640,771 1,692,547
Asset Retirement Obligations, Noncurrent 1,884,745 1,842,855
Loss Contingency Accrual 255,705 279,623
Liability, Defined Benefit Plan, Noncurrent 149,085 160,577
Long-Term Debt, Excluding Current Maturities 10,149,823 9,566,453
Deferred Credits and Other Liabilities 516,438 479,178
Liabilities, Noncurrent, Total 18,471,901 17,235,140
Commitments and Contingencies
Common Shareholders Equity [Abstract]    
Members' Equity 11,560,886 11,503,030
Equity, Attributable to Noncontrolling Interest 42,996 42,706
Accumulated Other Comprehensive Income (Loss), Net of Tax 50,555 53,658
Equity, Including Portion Attributable to Noncontrolling Interest, Total 11,654,437 11,599,394
Liabilities and Equity, Total 31,952,642 30,348,550
Customer Advances, Current Liabilities 352,052 151,662
Customer advances for construction, noncurrent 722,979 291,842
Disposal Group, Including Discontinued Operation, Assets, Current 4,845 2,474
Disposal Group, Including Discontinued Operation, Assets, Noncurrent 178,746 173,669
Entergy Louisiana [Member] | Affiliated Entity [Member]    
Accounts Receivable [Abstract]    
Accounts Receivable, before Allowance for Credit Loss, Current 163,851 103,055
Liabilities, Current [Abstract]    
Accounts Payable, Current 83,160 108,688
Entergy Louisiana [Member] | Nonrelated Party [Member]    
Accounts Receivable [Abstract]    
Accounts Receivable, before Allowance for Credit Loss, Current 369,748 294,089
Liabilities, Current [Abstract]    
Accounts Payable, Current 688,784 533,087
Entergy Mississippi [Member]    
Cash and Cash Equivalents [Abstract]    
Cash 30 184
Cash Equivalents, at Carrying Value 401,336 155,509
Cash and Cash Equivalents, at Carrying Value, Total 401,366 155,693
Accounts Receivable [Abstract]    
Accounts Receivable, Allowance for Credit Loss, Current (2,733) (2,172)
Other Receivables 28,622 25,148
Unbilled Receivables, Current 88,411 75,740
Accounts and Other Receivables, Net, Current 355,431 220,234
Energy Related Inventory 19,818 14,963
Public Utilities, Inventory 115,092 113,256
Prepaid Expense and Other Assets, Current 41,422 19,764
Assets, Current, Total 933,129 523,910
Assets, Noncurrent [Abstract]    
Property, Plant and Equipment, Net 4,474 4,482
Other Long-Term Investments 834 880
Long-Term Investments, Total 5,308 5,362
Public Utilities, Property, Plant and Equipment, Net [Abstract]    
Public Utilities, Property, Plant and Equipment, Electric 8,053,037 7,860,409
Public Utilities, Property, Plant and Equipment, Construction Work in Progress 869,314 487,273
Public Utilities, Property, Plant and Equipment, Plant in Service, Total 8,922,351 8,347,682
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation 2,592,512 2,511,091
Public Utilities, Property, Plant and Equipment, Net, Total 6,329,839 5,836,591
Regulatory Asset [Abstract]    
Regulatory Asset, Noncurrent 473,715 525,847
Other Assets, Noncurrent 108,543 97,260
Deferred Costs and Other Assets 582,258 623,107
Assets, Total 7,850,534 6,988,970
Liabilities, Current [Abstract]    
Contract with Customer, Refund Liability, Current 97,049 94,009
Taxes Payable, Current 175,095 179,024
Interest Payable, Current 29,792 20,667
Deferred Fuel Costs Current Liabilities 62,013 126,316
Other Liabilities, Current 22,571 20,720
Liabilities, Current, Total 754,358 782,578
Liabilities, Noncurrent [Abstract]    
Deferred Income Taxes and Other Tax Liabilities, Noncurrent 857,418 870,116
Accumulated Deferred Investment Tax Credit 13,234 13,446
Regulatory Liability For Income Taxes - Net 175,747 180,851
Regulatory Liability, Noncurrent 63,582 59,544
Asset Retirement Obligations, Noncurrent 25,814 25,110
Loss Contingency Accrual 43,238 47,200
Long-Term Debt, Excluding Current Maturities 3,020,687 2,427,073
Deferred Credits and Other Liabilities 84,889 61,446
Liabilities, Noncurrent, Total 4,493,550 3,797,404
Commitments and Contingencies
Common Shareholders Equity [Abstract]    
Members' Equity 2,597,315 2,400,786
Equity, Attributable to Noncontrolling Interest 5,311 8,202
Equity, Including Portion Attributable to Noncontrolling Interest, Total 2,602,626 2,408,988
Liabilities and Equity, Total 7,850,534 6,988,970
Customer Advances, Current Liabilities 103,402 0
Customer advances for construction, noncurrent 208,941 112,618
Entergy Mississippi [Member] | Affiliated Entity [Member]    
Accounts Receivable [Abstract]    
Accounts Receivable, before Allowance for Credit Loss, Current 123,710 23,909
Liabilities, Current [Abstract]    
Accounts Payable, Current 50,498 58,087
Entergy Mississippi [Member] | Nonrelated Party [Member]    
Accounts Receivable [Abstract]    
Accounts Receivable, before Allowance for Credit Loss, Current 117,421 97,609
Liabilities, Current [Abstract]    
Accounts Payable, Current 213,938 283,755
Entergy New Orleans [Member]    
Cash and Cash Equivalents [Abstract]    
Cash 26 374
Cash Equivalents, at Carrying Value 0 31,403
Cash and Cash Equivalents, at Carrying Value, Total 26 31,777
Other Restricted Assets, Current 0 1,611
Accounts Receivable [Abstract]    
Accounts Receivable, Allowance for Credit Loss, Current (3,395) (6,735)
Other Receivables 5,772 9,467
Unbilled Receivables, Current 39,997 33,296
Accounts and Other Receivables, Net, Current 127,042 107,603
Deferred Fuel Cost 5,599 0
Energy Related Inventory 766 320
Public Utilities, Inventory 29,226 25,516
Prepaid Expense and Other Assets, Current 19,169 12,128
Assets, Current, Total 196,585 192,055
Assets, Noncurrent [Abstract]    
Asset Recovery Damaged Property Costs, Noncurrent 75,073 83,742
Other Long-Term Investments 832 832
Long-Term Investments, Total 75,905 84,574
Public Utilities, Property, Plant and Equipment, Net [Abstract]    
Public Utilities, Property, Plant and Equipment, Electric 2,193,823 2,160,165
Public Utilities, Property, Plant and Equipment, Natural Gas 43,723 43,279
Public Utilities, Property, Plant and Equipment, Construction Work in Progress 43,456 18,269
Public Utilities, Property, Plant and Equipment, Plant in Service, Total 2,281,002 2,221,713
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation 785,518 768,305
Public Utilities, Property, Plant and Equipment, Net, Total 1,495,484 1,453,408
Regulatory Asset [Abstract]    
Regulatory Asset, Noncurrent 122,938 133,261
Deferred Fuel Cost, Noncurrent 4,080 4,080
Other Assets, Noncurrent 74,779 71,037
Deferred Costs and Other Assets 490,923 493,116
Assets, Total 2,258,897 2,223,153
Liabilities, Current [Abstract]    
Long-Term Debt, Current Maturities 165,000 78,000
Contract with Customer, Refund Liability, Current 33,070 28,834
Taxes Payable, Current 28,342 8,786
Interest Payable, Current 6,042 8,671
Deferred Fuel Costs Current Liabilities 0 980
Other Liabilities, Current 18,165 14,427
Liabilities, Current, Total 355,755 230,067
Liabilities, Noncurrent [Abstract]    
Deferred Income Taxes and Other Tax Liabilities, Noncurrent 192,918 201,541
Accumulated Deferred Investment Tax Credit 15,566 15,617
Regulatory Liability For Income Taxes - Net 16,506 15,000
Regulatory Liability, Noncurrent 245,127 260,312
Loss Contingency Accrual 79,521 90,293
Long-Term Debt, Excluding Current Maturities 565,556 650,463
Deferred Credits and Other Liabilities 54,342 56,395
Liabilities, Noncurrent, Total 1,175,400 1,295,485
Commitments and Contingencies
Common Shareholders Equity [Abstract]    
Members' Equity 727,742 697,601
Equity, Including Portion Attributable to Noncontrolling Interest, Total 727,742 697,601
Liabilities and Equity, Total 2,258,897 2,223,153
Disposal Group, Including Discontinued Operation, Assets, Current 14,757 13,100
Disposal Group, Including Discontinued Operation, Assets, Noncurrent 289,126 284,738
Entergy New Orleans [Member] | Affiliated Entity [Member]    
Accounts Receivable [Abstract]    
Accounts Receivable, before Allowance for Credit Loss, Current 4,959 5,844
Liabilities, Current [Abstract]    
Notes Payable, Current 1,140 1,140
Accounts Payable, Current 63,780 45,479
Liabilities, Noncurrent [Abstract]    
Notes Payable, Noncurrent 5,864 5,864
Entergy New Orleans [Member] | Nonrelated Party [Member]    
Accounts Receivable [Abstract]    
Accounts Receivable, before Allowance for Credit Loss, Current 79,709 65,731
Liabilities, Current [Abstract]    
Accounts Payable, Current 40,216 43,750
Entergy Texas [Member]    
Cash and Cash Equivalents [Abstract]    
Cash 25 291
Cash Equivalents, at Carrying Value 17,718 184,706
Cash and Cash Equivalents, at Carrying Value, Total 17,743 184,997
Other Restricted Assets, Current 1,005 2,703
Accounts Receivable [Abstract]    
Accounts Receivable, Allowance for Credit Loss, Current (4,280) (1,304)
Other Receivables 29,000 43,773
Unbilled Receivables, Current 95,993 74,060
Accounts and Other Receivables, Net, Current 251,115 227,935
Deferred Fuel Cost 9,804 0
Energy Related Inventory 36,153 45,970
Public Utilities, Inventory 166,111 157,241
Prepaid Expense and Other Assets, Current 31,144 34,803
Assets, Current, Total 513,075 653,649
Assets, Noncurrent [Abstract]    
Investments in and Advance to Affiliates, Subsidiaries, Associates, and Joint Ventures 84 107
Other Long-Term Investments 16,076 15,878
Long-Term Investments, Total 16,160 15,985
Public Utilities, Property, Plant and Equipment, Net [Abstract]    
Public Utilities, Property, Plant and Equipment, Electric 8,955,667 8,628,625
Public Utilities, Property, Plant and Equipment, Construction Work in Progress 1,995,414 1,513,170
Public Utilities, Property, Plant and Equipment, Plant in Service, Total 10,951,081 10,141,795
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation 2,661,738 2,548,961
Public Utilities, Property, Plant and Equipment, Net, Total 8,289,343 7,592,834
Regulatory Asset [Abstract]    
Regulatory Asset, Noncurrent 489,583 549,708
Other Assets, Noncurrent 177,552 157,904
Deferred Costs and Other Assets 667,135 707,612
Assets, Total 9,485,713 8,970,080
Liabilities, Current [Abstract]    
Contract with Customer, Refund Liability, Current 40,490 40,782
Taxes Payable, Current 55,883 76,474
Interest Payable, Current 44,674 38,703
Deferred Fuel Costs Current Liabilities 0 59,271
Other Liabilities, Current 19,820 20,836
Liabilities, Current, Total 807,336 662,805
Liabilities, Noncurrent [Abstract]    
Deferred Income Taxes and Other Tax Liabilities, Noncurrent 905,093 868,849
Accumulated Deferred Investment Tax Credit 6,841 7,215
Regulatory Liability For Income Taxes - Net 81,364 93,766
Regulatory Liability, Noncurrent 17,790 18,705
Asset Retirement Obligations, Noncurrent 14,695 17,688
Loss Contingency Accrual 11,186 9,985
Long-Term Debt, Excluding Current Maturities 4,038,417 3,552,443
Deferred Credits and Other Liabilities 114,463 397,412
Liabilities, Noncurrent, Total 5,189,849 4,966,063
Commitments and Contingencies
Common Stock, No Par Value $ 0 $ 0
Common Shareholders Equity [Abstract]    
Preferred Stock, Value, Issued $ 38,750 $ 38,750
Common Stock, Value, Issued 49,452 49,452
Additional Paid in Capital, Common Stock 1,200,125 1,200,125
Retained Earnings (Accumulated Deficit) 2,200,201 2,052,885
Equity, Attributable to Parent, Total 3,449,778 3,302,462
Equity, Including Portion Attributable to Noncontrolling Interest, Total 3,488,528 3,341,212
Liabilities and Equity, Total $ 9,485,713 $ 8,970,080
Common Stock, Shares, Issued 46,525,000 46,525,000
Entergy Texas [Member] | Affiliated Entity [Member]    
Accounts Receivable [Abstract]    
Accounts Receivable, before Allowance for Credit Loss, Current $ 14,479 $ 26,564
Liabilities, Current [Abstract]    
Accounts Payable, Current 53,562 65,335
Entergy Texas [Member] | Nonrelated Party [Member]    
Accounts Receivable [Abstract]    
Accounts Receivable, before Allowance for Credit Loss, Current 115,923 84,842
Liabilities, Current [Abstract]    
Accounts Payable, Current 592,907 361,404
System Energy [Member]    
Cash and Cash Equivalents [Abstract]    
Cash 46 448
Cash Equivalents, at Carrying Value 31,743 28,460
Cash and Cash Equivalents, at Carrying Value, Total 31,789 28,908
Accounts Receivable [Abstract]    
Accounts Receivable, before Allowance for Credit Loss, Current 53,823 48,134
Other Receivables 4,824 5,425
Accounts and Other Receivables, Net, Current 58,647 53,559
Public Utilities, Inventory 168,078 163,814
Prepaid Expense and Other Assets, Current 10,929 5,768
Deferred Nuclear Refueling Outage Costs 11,844 19,884
Assets, Current, Total 281,287 271,933
Assets, Noncurrent [Abstract]    
Decommissioning Fund Investments 1,606,304 1,529,059
Long-Term Investments, Total 1,606,304 1,529,059
Public Utilities, Property, Plant and Equipment, Net [Abstract]    
Public Utilities, Property, Plant and Equipment, Electric 5,677,856 5,668,253
Public Utilities, Property, Plant and Equipment, Construction Work in Progress 125,685 85,127
Public Utilities, Property, Plant and Equipment, Fuel 157,883 220,044
Public Utilities, Property, Plant and Equipment, Plant in Service, Total 5,961,424 5,973,424
Public Utilities, Property, Plant and Equipment, Accumulated Depreciation 3,635,827 3,578,709
Public Utilities, Property, Plant and Equipment, Net, Total 2,325,597 2,394,715
Regulatory Asset [Abstract]    
Regulatory Asset, Noncurrent 424,778 426,494
Other Assets, Noncurrent 22,771 20,273
Deferred Costs and Other Assets 447,549 446,767
Assets, Total 4,660,737 4,642,474
Liabilities, Current [Abstract]    
Long-Term Debt, Current Maturities 112 200,090
Taxes Payable, Current 5,247 15,852
Interest Payable, Current 13,243 13,342
Other Liabilities, Current 4,475 4,473
Liabilities, Current, Total 56,028 297,251
Liabilities, Noncurrent [Abstract]    
Deferred Income Taxes and Other Tax Liabilities, Noncurrent 467,250 451,830
Accumulated Deferred Investment Tax Credit 42,244 42,984
Regulatory Liability For Income Taxes - Net 102,570 105,467
Regulatory Liability, Noncurrent 802,492 747,190
Asset Retirement Obligations, Noncurrent 1,150,113 1,127,712
Liability, Defined Benefit Plan, Noncurrent 4,001 8,353
Long-Term Debt, Excluding Current Maturities 1,094,284 889,646
Deferred Credits and Other Liabilities 2 2
Liabilities, Noncurrent, Total 3,662,956 3,373,184
Commitments and Contingencies
Common Stock, No Par Value $ 0 $ 0
Common Shareholders Equity [Abstract]    
Common Stock, Value, Issued $ 908,944 $ 958,944
Retained Earnings (Accumulated Deficit) 32,809 13,095
Equity, Including Portion Attributable to Noncontrolling Interest, Total 941,753 972,039
Liabilities and Equity, Total $ 4,660,737 $ 4,642,474
Common Stock, Shares, Issued 789,350 789,350
System Energy [Member] | Affiliated Entity [Member]    
Liabilities, Current [Abstract]    
Accounts Payable, Current $ 8,055 $ 18,477
System Energy [Member] | Nonrelated Party [Member]    
Liabilities, Current [Abstract]    
Accounts Payable, Current $ 24,896 $ 45,017
v3.25.2
Consolidated Statements Of Comprehensive Income - USD ($)
$ in Thousands
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest $ 471,954 $ 51,732 $ 834,376 $ 128,268
Other Comprehensive Income (Loss), Net of Tax [Abstract]        
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, after Tax 4,602 (246,489) 8,331 (242,821)
Other Comprehensive Income (Loss), Net of Tax, Total (4,602) 246,489 (8,331) 242,821
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest, Total 467,352 298,221 826,045 371,089
Preferred dividend requirements of subsidiaries and net income (loss) attributable to noncontrolling interests 4,024 2,810 5,686 4,065
Comprehensive Income (Loss), Net of Tax, Attributable to Parent, Total 463,328 295,411 820,359 367,024
Entergy Louisiana [Member]        
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest 300,180 131,114 554,377 313,837
Other Comprehensive Income (Loss), Net of Tax [Abstract]        
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, after Tax 2,132 2,023 3,103 4,047
Other Comprehensive Income (Loss), Net of Tax, Total (2,132) (2,023) (3,103) (4,047)
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest, Total 298,048 129,091 551,274 309,790
Net Income (Loss) Attributable to Noncontrolling Interest 745 788 1,497 1,583
Comprehensive Income (Loss), Net of Tax, Attributable to Parent, Total 297,303 128,303 549,777 308,207
Entergy Arkansas [Member]        
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest 99,193 95,359 185,716 63,079
Other Comprehensive Income (Loss), Net of Tax [Abstract]        
Net Income (Loss) Attributable to Noncontrolling Interest (889) (825) (2,080) (2,643)
System Energy [Member]        
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest $ 21,325 $ 24,848 $ 44,714 $ 55,966
v3.25.2
Consolidated Statements Of Changes In Equity - USD ($)
$ in Thousands
Total
Additional Paid-in Capital [Member]
Retained Earnings [Member]
AOCI Attributable to Parent [Member]
Common Stock [Member]
Treasury Stock, Common [Member]
Subsidiaries Preferred Stock and Noncontrolling Interests [Member]
Entergy Texas [Member]
Entergy Texas [Member]
Additional Paid-in Capital [Member]
Entergy Texas [Member]
Retained Earnings [Member]
Entergy Texas [Member]
Common Stock [Member]
Entergy Texas [Member]
Preferred Stock [Member]
Entergy Mississippi [Member]
Entergy Mississippi [Member]
Noncontrolling Interest [Member]
Entergy Mississippi [Member]
Member Units
Entergy Arkansas [Member]
Entergy Arkansas [Member]
Noncontrolling Interest [Member]
Entergy Arkansas [Member]
Member Units
Entergy Louisiana [Member]
Entergy Louisiana [Member]
Restoration Law Trust II [Member]
Entergy Finance Company [Member]
Entergy Louisiana [Member]
AOCI Attributable to Parent [Member]
Entergy Louisiana [Member]
Noncontrolling Interest [Member]
Entergy Louisiana [Member]
Member Units
Entergy New Orleans [Member]
System Energy [Member]
System Energy [Member]
Retained Earnings [Member]
System Energy [Member]
Common Stock [Member]
Entergy Corporation [Member]
Equity, Including Portion Attributable to Noncontrolling Interest $ 14,743,106 $ 7,792,601 $ 11,940,384 $ (162,460) $ 5,620 $ (4,953,498) $ 120,459 $ 3,118,662 $ 1,200,125 $ 1,830,335 $ 49,452 $ 38,750 $ 2,208,214 $ 18,753 $ 2,189,461 $ 3,760,670 $ 21,599 $ 3,739,071 $ 11,573,519   $ 54,798 $ 45,107 $ 11,473,614   $ 888,539 $ (28,311) $ 916,850  
Members' Equity                                               $ 806,754        
Dividends, Preferred Stock, Cash 4,580           4,580 518   518                                   $ 4,000
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest 76,536   75,281       1,255 36,744   36,744     27,432 (2,302) 29,734 (32,280) (1,818) (30,462) 182,723     795 181,928 (48,980) 31,118 31,118    
Capital Contribution from Parent                               275,000   275,000             150,000   150,000  
Common equity distributions                                     97,500       97,500          
Dividends, Common Stock, Cash (240,959)   (240,959)                                                  
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders (1,108)           (1,108)                 (250) (250)   (858)     (858)            
Other Comprehensive Income (Loss), Net of Tax (3,668)     (3,668)                             (2,024)   (2,024)              
Shares Issued, Value, Share-Based Payment Arrangement, after Forfeiture (5,039) 25,842       (30,881)                                            
Stockholders' Equity, Other                                     (43)       (43)          
Noncash Capital Contribution from Parent                                     976       976          
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest $ 128,268             126,966         106,997     63,079     313,837         (27,847) 55,966      
Common Stock, Dividends, Per Share, Declared $ 1.13                                                      
Payments of Ordinary Dividends, Preferred Stock and Preference Stock $ (9,159)             (1,036)                                        
Net Income (Loss) Attributable to Noncontrolling Interest                         (4,035)     (2,643)     1,583                  
Other Comprehensive Income (Loss), Net of Tax 242,821                                   (4,047)                  
Proceeds from Contributions from Parent                         0     695,000                 150,000      
Equity, Including Portion Attributable to Noncontrolling Interest 14,574,366 7,766,759 11,774,706 (166,128) 5,620 (4,922,617) 116,026 3,154,888 1,200,125 1,866,561 49,452 38,750 2,235,646 16,451 2,219,195 4,003,140 19,531 3,983,609 11,656,793   52,774 45,044 11,558,975   1,069,657 2,807 1,066,850  
Members' Equity                                               757,774        
Dividends, Preferred Stock, Cash 4,580           4,580 518 0 518 0 0                               4,000
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest 51,732   48,922       2,810 90,222 0 90,222 0 0 79,565 (1,733) 81,298 95,359 (825) 96,184 131,114     788 130,326 21,133 24,848 24,848    
Capital Contribution from Parent                               420,000   420,000                    
Common equity distributions                         22,300   22,300       566,600       566,600          
Dividends, Common Stock, Cash (241,296)   (241,296)                                                  
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders $ (330)           (330)                 (31) (31)   (299)     (299)            
Common Stock, Dividends, Per Share, Declared $ 0.57                                                      
Net Income (Loss) Attributable to Noncontrolling Interest                         (1,733)     (825)     788                  
Other Comprehensive Income (Loss), Net of Tax $ 246,489     246,489                             (2,023)   (2,023)              
Shares Issued, Value, Share-Based Payment Arrangement, after Forfeiture (55,274) (16,352)       (38,922)                                            
Stockholders' Equity, Other                                     (40)       (40)          
Equity, Including Portion Attributable to Noncontrolling Interest 14,681,655 7,783,111 11,582,332 80,361 5,620 (4,883,695) 113,926 3,244,592 1,200,125 1,956,265 49,452 38,750 2,292,911 14,718 2,278,193 4,518,468 18,675 4,499,793 11,218,945   50,751 45,533 11,122,661   1,094,505 27,655 1,066,850  
Members' Equity                                               778,907        
Equity, Including Portion Attributable to Noncontrolling Interest 15,184,984 7,833,525 12,014,315 42,769 5,620 (4,812,321) 101,076 3,341,212 1,200,125 2,052,885 49,452 38,750 2,408,988 8,202 2,400,786 4,464,005 15,168 4,448,837 11,599,394   53,658 42,706 11,503,030 697,601 972,039 13,095 958,944  
Redeemable Noncontrolling Interest, Equity, Preferred, Fair Value                                       $ 1,400,000                
Members' Equity                         2,400,786     4,448,837     11,503,030         697,601        
Dividends, Preferred Stock, Cash 4,580           4,580 518   518                                   4,000
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest 362,422   360,760       1,662 66,856   66,856     46,866 (2,479) 49,345 86,523 (1,191) 87,714 254,197     752 253,445 12,099 23,389 23,389    
Capital Contribution from Parent                         62,500   62,500                          
Dividends, Common Stock                                                 35,000 15,000 20,000  
Common equity distributions                                     36,250       36,250          
Dividends, Common Stock, Cash (258,249)   (258,249)                                                  
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders (1,069)           (1,069)                 (181) (181)   (888)     (888)            
Other Comprehensive Income (Loss), Net of Tax (3,729)     (3,729)                             (971)   (971)              
Shares Issued, Value, Share-Based Payment Arrangement, after Forfeiture (2,621) 40,777       (43,398)                                            
Stockholders' Equity, Other                                     (12)       (12)          
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest $ 834,376             148,352         131,138     185,716     554,377         30,141 44,714      
Common Stock, Dividends, Per Share, Declared $ 1.20                                                      
Payments of Ordinary Dividends, Preferred Stock and Preference Stock $ (9,159)             (1,036)                                        
Net Income (Loss) Attributable to Noncontrolling Interest                         (2,891)     (2,080)     1,497                  
Other Comprehensive Income (Loss), Net of Tax (8,331)                                   (3,103)                  
Proceeds from Contributions from Parent                         62,500     0                 0      
Equity, Including Portion Attributable to Noncontrolling Interest 15,282,400 7,792,748 12,116,826 39,040 5,620 (4,768,923) 97,089 3,407,550 1,200,125 2,119,223 49,452 38,750 2,518,354 5,723 2,512,631 4,550,347 13,796 4,536,551 11,815,470   52,687 42,570 11,720,213   960,428 21,484 938,944  
Members' Equity                                               709,700        
Dividends, Preferred Stock, Cash 4,580           4,580 518   518                                   $ 4,000
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest 471,954   467,930       4,024 81,496   81,496     84,272 (412) 84,684 99,193 (889) 100,082 300,180     745 299,435 18,042 21,325 21,325    
Dividends, Common Stock                                                 40,000 10,000 30,000  
Common equity distributions                                     458,750       458,750          
Dividends, Common Stock, Cash (258,467)   (258,467)                                                  
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders $ (593)           (593)                 (275) (275)   (319)     (319)            
Common Stock, Dividends, Per Share, Declared $ 0.60                                                      
Net Income (Loss) Attributable to Noncontrolling Interest                         (412)     (889)     745                  
Other Comprehensive Income (Loss), Net of Tax $ (4,602)     (4,602)                             (2,132)   (2,132)              
Shares Issued, Value, Share-Based Payment Arrangement, after Forfeiture (18,197) (15,489)       (2,708)                                            
Stockholders' Equity, Other                                     (12)       (12)          
Stock Issued During Period, Value, New Issues 813,871 813,716     155                                              
Adjustments to Additional Paid in Capital, Stock Issued, Issuance Costs (9,240) (9,240)                                                    
Equity, Including Portion Attributable to Noncontrolling Interest $ 16,308,940 $ 8,612,713 $ 12,326,289 $ 34,438 $ 5,775 $ (4,766,215) $ 95,940 $ 3,488,528 $ 1,200,125 $ 2,200,201 $ 49,452 $ 38,750 2,602,626 $ 5,311 $ 2,597,315 4,649,265 $ 12,632 $ 4,636,633 11,654,437   $ 50,555 $ 42,996 $ 11,560,886 727,742 $ 941,753 $ 32,809 $ 908,944  
Redeemable Noncontrolling Interest, Equity, Preferred, Fair Value                                       $ 1,300,000                
Members' Equity                         $ 2,597,315     $ 4,636,633     $ 11,560,886         $ 727,742        
v3.25.2
Consolidated Balance Sheets (Parenthetical) - USD ($)
$ in Thousands
Jun. 30, 2025
Dec. 31, 2024
Securitized Regulatory Transition Assets, Noncurrent $ 226,006 $ 234,112
Long-Term Transition Bond, Noncurrent $ 230,445 $ 239,622
Preferred Stock, Shares Issued 0 0
Preferred Stock, Shares Authorized 1,000,000 1,000,000
Preferred Stock, No Par Value $ 0 $ 0
Common Stock, Par or Stated Value Per Share $ 0.01 $ 0.01
Common Stock, Shares Authorized 998,000,000 998,000,000
Common Stock, Shares, Issued 577,511,170 561,950,696
Treasury Stock, Common, Shares 131,102,101 132,370,280
Disposal Group, Including Discontinued Operation, Assets, Current $ 19,602 $ 15,574
Disposal Group, Including Discontinued Operation, Assets, Noncurrent 472,528 462,797
Entergy Texas [Member]    
Securitized Regulatory Transition Assets, Noncurrent 226,006 234,112
Long-Term Transition Bond, Noncurrent $ 230,445 $ 239,622
Common Stock, Shares Authorized 200,000,000 200,000,000
Common Stock, Shares, Issued 46,525,000 46,525,000
Common Stock, Shares, Outstanding 46,525,000 46,525,000
Common Stock, No Par Value $ 0 $ 0
Entergy New Orleans [Member]    
Disposal Group, Including Discontinued Operation, Assets, Current $ 14,757 $ 13,100
Disposal Group, Including Discontinued Operation, Assets, Noncurrent $ 289,126 $ 284,738
System Energy [Member]    
Common Stock, Shares Authorized 1,000,000 1,000,000
Common Stock, Shares, Issued 789,350 789,350
Common Stock, Shares, Outstanding 789,350 789,350
Common Stock, No Par Value $ 0 $ 0
v3.25.2
Consolidated Statements of Comprehensive Income (Parentheticals) - USD ($)
$ in Thousands
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax $ (1,411) $ 65,371 $ (3,695) $ 64,170
Entergy Louisiana [Member]        
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, Tax $ 723 $ 745 $ 2,607 $ 1,491
v3.25.2
Commitments and Contingencies
 6 Months Ended
Jun. 30, 2025
Commitments and Contingencies Disclosure [Text Block] COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein.

Vidalia Purchased Power Agreement

See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. The following is an update to that discussion.

As discussed in the Form 10-K, in October 2024 the U.S. Court of Federal Claims issued a final judgment in the amount of $7 million in favor of Holtec Palisades, LLC (previously Entergy Nuclear Palisades) and against the DOE in the final round Palisades damages case. Holtec, as the current owner, received payment from the U.S. Treasury in March 2025 and subsequently transferred the $7 million judgment to Entergy. The effect in 2024 of recording the judgment was a reduction to asset write-offs, impairments, and related charges (credits). The damages awarded included $4 million related to costs previously recorded as plant and $3 million related to costs previously recorded as other operation and maintenance expenses.

Nuclear Insurance

See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.

Non-Nuclear Property Insurance

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program.

Employment and Labor-related Proceedings

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.

Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
Grand Gulf-Related Agreements

See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements, including the Unit Power Sales Agreement, the Availability Agreement, and the Reallocation Agreement.

Exclusivity Agreement with Major Vendor

Entergy entered into an exclusivity agreement with a major vendor to manufacture power island equipment (PIE) and combustion turbines (CT) for combustion turbine generator set frames larger than 400 MWs. The agreement guarantees Entergy one manufacturing slot per quarter for the shorter of a five-year period or until Entergy fulfills its minimum commitment. The agreement commits Entergy to a minimum order of 15 sets of PIE and two CTs during that time period. The commitments are fully transferable to any of the Utility operating companies.

Cancellation or failure to purchase the minimum commitment amounts will result in a charge. If any of the Utility operating companies purchases any PIEs or CTs within the scope of the agreement from another supplier (except as permitted under the agreement), then the vendor has the right to terminate all or a portion of the agreement. In the event of such termination, the Utility operating company would then be obligated to pay 50% of the base price for each PIE or CT not yet ordered. The agreement does not establish final pricing and delivery dates of purchases that will go towards meeting the commitments under the agreement. Such terms shall be agreed to in separate agreements.
Entergy Arkansas [Member]  
Commitments and Contingencies Disclosure [Text Block] COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein.

Vidalia Purchased Power Agreement

See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. The following is an update to that discussion.

As discussed in the Form 10-K, in October 2024 the U.S. Court of Federal Claims issued a final judgment in the amount of $7 million in favor of Holtec Palisades, LLC (previously Entergy Nuclear Palisades) and against the DOE in the final round Palisades damages case. Holtec, as the current owner, received payment from the U.S. Treasury in March 2025 and subsequently transferred the $7 million judgment to Entergy. The effect in 2024 of recording the judgment was a reduction to asset write-offs, impairments, and related charges (credits). The damages awarded included $4 million related to costs previously recorded as plant and $3 million related to costs previously recorded as other operation and maintenance expenses.

Nuclear Insurance

See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.

Non-Nuclear Property Insurance

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program.

Employment and Labor-related Proceedings

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.

Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
Grand Gulf-Related Agreements

See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements, including the Unit Power Sales Agreement, the Availability Agreement, and the Reallocation Agreement.

Exclusivity Agreement with Major Vendor

Entergy entered into an exclusivity agreement with a major vendor to manufacture power island equipment (PIE) and combustion turbines (CT) for combustion turbine generator set frames larger than 400 MWs. The agreement guarantees Entergy one manufacturing slot per quarter for the shorter of a five-year period or until Entergy fulfills its minimum commitment. The agreement commits Entergy to a minimum order of 15 sets of PIE and two CTs during that time period. The commitments are fully transferable to any of the Utility operating companies.

Cancellation or failure to purchase the minimum commitment amounts will result in a charge. If any of the Utility operating companies purchases any PIEs or CTs within the scope of the agreement from another supplier (except as permitted under the agreement), then the vendor has the right to terminate all or a portion of the agreement. In the event of such termination, the Utility operating company would then be obligated to pay 50% of the base price for each PIE or CT not yet ordered. The agreement does not establish final pricing and delivery dates of purchases that will go towards meeting the commitments under the agreement. Such terms shall be agreed to in separate agreements.
Entergy Louisiana [Member]  
Commitments and Contingencies Disclosure [Text Block] COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein.

Vidalia Purchased Power Agreement

See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. The following is an update to that discussion.

As discussed in the Form 10-K, in October 2024 the U.S. Court of Federal Claims issued a final judgment in the amount of $7 million in favor of Holtec Palisades, LLC (previously Entergy Nuclear Palisades) and against the DOE in the final round Palisades damages case. Holtec, as the current owner, received payment from the U.S. Treasury in March 2025 and subsequently transferred the $7 million judgment to Entergy. The effect in 2024 of recording the judgment was a reduction to asset write-offs, impairments, and related charges (credits). The damages awarded included $4 million related to costs previously recorded as plant and $3 million related to costs previously recorded as other operation and maintenance expenses.

Nuclear Insurance

See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.

Non-Nuclear Property Insurance

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program.

Employment and Labor-related Proceedings

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.

Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
Grand Gulf-Related Agreements

See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements, including the Unit Power Sales Agreement, the Availability Agreement, and the Reallocation Agreement.

Exclusivity Agreement with Major Vendor

Entergy entered into an exclusivity agreement with a major vendor to manufacture power island equipment (PIE) and combustion turbines (CT) for combustion turbine generator set frames larger than 400 MWs. The agreement guarantees Entergy one manufacturing slot per quarter for the shorter of a five-year period or until Entergy fulfills its minimum commitment. The agreement commits Entergy to a minimum order of 15 sets of PIE and two CTs during that time period. The commitments are fully transferable to any of the Utility operating companies.

Cancellation or failure to purchase the minimum commitment amounts will result in a charge. If any of the Utility operating companies purchases any PIEs or CTs within the scope of the agreement from another supplier (except as permitted under the agreement), then the vendor has the right to terminate all or a portion of the agreement. In the event of such termination, the Utility operating company would then be obligated to pay 50% of the base price for each PIE or CT not yet ordered. The agreement does not establish final pricing and delivery dates of purchases that will go towards meeting the commitments under the agreement. Such terms shall be agreed to in separate agreements.
Entergy Mississippi [Member]  
Commitments and Contingencies Disclosure [Text Block] COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein.

Vidalia Purchased Power Agreement

See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. The following is an update to that discussion.

As discussed in the Form 10-K, in October 2024 the U.S. Court of Federal Claims issued a final judgment in the amount of $7 million in favor of Holtec Palisades, LLC (previously Entergy Nuclear Palisades) and against the DOE in the final round Palisades damages case. Holtec, as the current owner, received payment from the U.S. Treasury in March 2025 and subsequently transferred the $7 million judgment to Entergy. The effect in 2024 of recording the judgment was a reduction to asset write-offs, impairments, and related charges (credits). The damages awarded included $4 million related to costs previously recorded as plant and $3 million related to costs previously recorded as other operation and maintenance expenses.

Nuclear Insurance

See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.

Non-Nuclear Property Insurance

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program.

Employment and Labor-related Proceedings

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.

Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
Grand Gulf-Related Agreements

See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements, including the Unit Power Sales Agreement, the Availability Agreement, and the Reallocation Agreement.

Exclusivity Agreement with Major Vendor

Entergy entered into an exclusivity agreement with a major vendor to manufacture power island equipment (PIE) and combustion turbines (CT) for combustion turbine generator set frames larger than 400 MWs. The agreement guarantees Entergy one manufacturing slot per quarter for the shorter of a five-year period or until Entergy fulfills its minimum commitment. The agreement commits Entergy to a minimum order of 15 sets of PIE and two CTs during that time period. The commitments are fully transferable to any of the Utility operating companies.

Cancellation or failure to purchase the minimum commitment amounts will result in a charge. If any of the Utility operating companies purchases any PIEs or CTs within the scope of the agreement from another supplier (except as permitted under the agreement), then the vendor has the right to terminate all or a portion of the agreement. In the event of such termination, the Utility operating company would then be obligated to pay 50% of the base price for each PIE or CT not yet ordered. The agreement does not establish final pricing and delivery dates of purchases that will go towards meeting the commitments under the agreement. Such terms shall be agreed to in separate agreements.
Entergy New Orleans [Member]  
Commitments and Contingencies Disclosure [Text Block] COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein.

Vidalia Purchased Power Agreement

See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. The following is an update to that discussion.

As discussed in the Form 10-K, in October 2024 the U.S. Court of Federal Claims issued a final judgment in the amount of $7 million in favor of Holtec Palisades, LLC (previously Entergy Nuclear Palisades) and against the DOE in the final round Palisades damages case. Holtec, as the current owner, received payment from the U.S. Treasury in March 2025 and subsequently transferred the $7 million judgment to Entergy. The effect in 2024 of recording the judgment was a reduction to asset write-offs, impairments, and related charges (credits). The damages awarded included $4 million related to costs previously recorded as plant and $3 million related to costs previously recorded as other operation and maintenance expenses.

Nuclear Insurance

See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.

Non-Nuclear Property Insurance

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program.

Employment and Labor-related Proceedings

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.

Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
Grand Gulf-Related Agreements

See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements, including the Unit Power Sales Agreement, the Availability Agreement, and the Reallocation Agreement.

Exclusivity Agreement with Major Vendor

Entergy entered into an exclusivity agreement with a major vendor to manufacture power island equipment (PIE) and combustion turbines (CT) for combustion turbine generator set frames larger than 400 MWs. The agreement guarantees Entergy one manufacturing slot per quarter for the shorter of a five-year period or until Entergy fulfills its minimum commitment. The agreement commits Entergy to a minimum order of 15 sets of PIE and two CTs during that time period. The commitments are fully transferable to any of the Utility operating companies.

Cancellation or failure to purchase the minimum commitment amounts will result in a charge. If any of the Utility operating companies purchases any PIEs or CTs within the scope of the agreement from another supplier (except as permitted under the agreement), then the vendor has the right to terminate all or a portion of the agreement. In the event of such termination, the Utility operating company would then be obligated to pay 50% of the base price for each PIE or CT not yet ordered. The agreement does not establish final pricing and delivery dates of purchases that will go towards meeting the commitments under the agreement. Such terms shall be agreed to in separate agreements.
Entergy Texas [Member]  
Commitments and Contingencies Disclosure [Text Block] COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein.

Vidalia Purchased Power Agreement

See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. The following is an update to that discussion.

As discussed in the Form 10-K, in October 2024 the U.S. Court of Federal Claims issued a final judgment in the amount of $7 million in favor of Holtec Palisades, LLC (previously Entergy Nuclear Palisades) and against the DOE in the final round Palisades damages case. Holtec, as the current owner, received payment from the U.S. Treasury in March 2025 and subsequently transferred the $7 million judgment to Entergy. The effect in 2024 of recording the judgment was a reduction to asset write-offs, impairments, and related charges (credits). The damages awarded included $4 million related to costs previously recorded as plant and $3 million related to costs previously recorded as other operation and maintenance expenses.

Nuclear Insurance

See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.

Non-Nuclear Property Insurance

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program.

Employment and Labor-related Proceedings

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.

Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
Grand Gulf-Related Agreements

See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements, including the Unit Power Sales Agreement, the Availability Agreement, and the Reallocation Agreement.

Exclusivity Agreement with Major Vendor

Entergy entered into an exclusivity agreement with a major vendor to manufacture power island equipment (PIE) and combustion turbines (CT) for combustion turbine generator set frames larger than 400 MWs. The agreement guarantees Entergy one manufacturing slot per quarter for the shorter of a five-year period or until Entergy fulfills its minimum commitment. The agreement commits Entergy to a minimum order of 15 sets of PIE and two CTs during that time period. The commitments are fully transferable to any of the Utility operating companies.

Cancellation or failure to purchase the minimum commitment amounts will result in a charge. If any of the Utility operating companies purchases any PIEs or CTs within the scope of the agreement from another supplier (except as permitted under the agreement), then the vendor has the right to terminate all or a portion of the agreement. In the event of such termination, the Utility operating company would then be obligated to pay 50% of the base price for each PIE or CT not yet ordered. The agreement does not establish final pricing and delivery dates of purchases that will go towards meeting the commitments under the agreement. Such terms shall be agreed to in separate agreements.
System Energy [Member]  
Commitments and Contingencies Disclosure [Text Block] COMMITMENTS AND CONTINGENCIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business.  While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition, except as otherwise discussed in the Form 10-K or in this report.  Entergy discusses regulatory proceedings in Note 2 to the financial statements in the Form 10-K and herein and discusses tax proceedings in Note 3 to the financial statements in the Form 10-K and Note 10 to the financial statements herein.

Vidalia Purchased Power Agreement

See Note 8 to the financial statements in the Form 10-K for information on Entergy Louisiana’s Vidalia purchased power agreement.

Spent Nuclear Fuel Litigation

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s spent nuclear fuel litigation. The following is an update to that discussion.

As discussed in the Form 10-K, in October 2024 the U.S. Court of Federal Claims issued a final judgment in the amount of $7 million in favor of Holtec Palisades, LLC (previously Entergy Nuclear Palisades) and against the DOE in the final round Palisades damages case. Holtec, as the current owner, received payment from the U.S. Treasury in March 2025 and subsequently transferred the $7 million judgment to Entergy. The effect in 2024 of recording the judgment was a reduction to asset write-offs, impairments, and related charges (credits). The damages awarded included $4 million related to costs previously recorded as plant and $3 million related to costs previously recorded as other operation and maintenance expenses.

Nuclear Insurance

See Note 8 to the financial statements in the Form 10-K for information on nuclear liability and property insurance associated with Entergy’s nuclear power plants.

Non-Nuclear Property Insurance

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s non-nuclear property insurance program.

Employment and Labor-related Proceedings

See Note 8 to the financial statements in the Form 10-K for information on Entergy’s employment and labor-related proceedings.

Asbestos Litigation (Entergy Arkansas, Entergy Louisiana, Entergy New Orleans, and Entergy Texas)

See Note 8 to the financial statements in the Form 10-K for information regarding asbestos litigation.
Grand Gulf-Related Agreements

See Note 8 to the financial statements in the Form 10-K for information regarding Grand Gulf-related agreements, including the Unit Power Sales Agreement, the Availability Agreement, and the Reallocation Agreement.

Exclusivity Agreement with Major Vendor

Entergy entered into an exclusivity agreement with a major vendor to manufacture power island equipment (PIE) and combustion turbines (CT) for combustion turbine generator set frames larger than 400 MWs. The agreement guarantees Entergy one manufacturing slot per quarter for the shorter of a five-year period or until Entergy fulfills its minimum commitment. The agreement commits Entergy to a minimum order of 15 sets of PIE and two CTs during that time period. The commitments are fully transferable to any of the Utility operating companies.

Cancellation or failure to purchase the minimum commitment amounts will result in a charge. If any of the Utility operating companies purchases any PIEs or CTs within the scope of the agreement from another supplier (except as permitted under the agreement), then the vendor has the right to terminate all or a portion of the agreement. In the event of such termination, the Utility operating company would then be obligated to pay 50% of the base price for each PIE or CT not yet ordered. The agreement does not establish final pricing and delivery dates of purchases that will go towards meeting the commitments under the agreement. Such terms shall be agreed to in separate agreements.
v3.25.2
Rate And Regulatory Matters
 6 Months Ended
Jun. 30, 2025
Public Utilities Disclosure [Text Block] RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Regulatory Assets and Regulatory Liabilities

See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

In March 2025, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.00882 per kWh to $0.01333 per kWh. The annual redetermination included a credit related to the remaining balance due to retail customers from the System Energy settlement with the APSC, plus carrying charges and interest. See “Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - Grand Gulf Credit Rider” below for further discussion. The primary reason for the rate increase is an adjustment to account for projected increases in natural gas prices in 2025. This adjustment is expected to reduce the rate change that will be reflected in its 2026 energy cost rate redetermination. The redetermined rate of $0.01333 per kWh became effective with the first billing cycle in April 2025 through the normal operation of the tariff.
Entergy Louisiana

As discussed in the Form 10-K, in January 2023 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2021 through 2022. In April 2025 the LPSC staff issued its audit report (for Entergy Louisiana’s gas operations), which included several prospective recommendations but no financial disallowances. The LPSC accepted the report in June 2025.

Entergy Texas

As discussed in the Form 10-K, in September 2024, Entergy Texas filed an application with the PUCT to reconcile its fuel and purchased power costs for the period from April 2022 through March 2024. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in eligible fuel and purchased power expenses to generate and purchase electricity to serve its customers, net of certain revenues credited to such expenses and other adjustments. Entergy Texas’s cumulative under-recovery balance for the reconciliation period was approximately $30 million, including interest, which Entergy Texas requested authority to carry over as part of the cumulative fuel balance for the subsequent reconciliation period beginning April 2024. In November 2024 the PUCT referred the proceeding to the State Office of Administrative Hearings. In March 2025, Texas Industrial Energy Consumers, an intervenor, filed testimony regarding the recovery of capacity costs for a certain power purchase agreement, arguing the capacity costs should be imputed and treated as non-reconcilable fuel expense, recovered in Entergy Texas’s base rates. In April 2025 the PUCT staff filed testimony and later in April 2025, Entergy Texas filed rebuttal testimony. In May 2025, Entergy Texas filed, and the ALJ with the State Office of Administrative Hearings granted, a request for a paper hearing and to cancel the oral hearing on the merits previously scheduled for later in May 2025. In June 2025, Entergy Texas filed, and the ALJ with the State Office of Administrative Hearings granted, a joint motion to abate the proceeding to give the parties to the proceeding additional time to finalize a settlement.

Retail Rate Proceedings

See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion.

Filings with the APSC (Entergy Arkansas)

Retail Rates

2025 Formula Rate Plan Filing

In July 2025, Entergy Arkansas filed with the APSC its 2025 formula rate plan filing to set its formula rate for the 2026 calendar year.  The filing contained an evaluation of Entergy Arkansas’s earnings for the 2026 projected year and a netting adjustment for the 2024 historical year.  The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2026 projected year was 8.45% resulting in a revenue deficiency of $68.9 million.  The earned rate of return on common equity for the 2024 historical year was 7.71% resulting in a $48.8 million netting adjustment.  The total proposed revenue change for the 2026 projected year and 2024 historical year netting adjustment is $117.7 million.   By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint.  Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase was limited to $92.3 million. Entergy Arkansas proposed a procedural schedule that includes a hearing in November 2025 and requests an APSC order in December 2025.
Grand Gulf Credit Rider

As discussed in the Form 10-K, in June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “Complaints Against System Energy - System Energy Settlement with the APSC” in Note 2 to the financial statements in the Form 10-K for discussion of the System Energy settlement with the APSC. In July 2024 the APSC approved the tariff, under which Entergy Arkansas would refund to retail customers a total of $100.6 million. Entergy Arkansas refunded $92.3 million of the total through one-time bill credits under the Grand Gulf credit rider during the August 2024 billing cycle. In March 2025, Entergy Arkansas included the remaining balance as a credit to retail customers in its energy cost recovery rider rate redetermination filing. See further discussion within "Regulatory Assets and Regulatory Liabilities - Fuel and purchased power cost recovery - Entergy Arkansas - Energy Cost Recovery Rider" above. In April 2025 the APSC approved Entergy Arkansas’s proposal to include the remaining balance in its energy cost recovery rider effective with the first billing cycle of April 2025 and the withdrawal of the Grand Gulf credit rider after all credits had been issued. Credits to retail customers were completed in second quarter 2025, and the Grand Gulf credit rider was subsequently withdrawn.

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2023 Formula Rate Plan Filing

As discussed in the Form 10-K, in August 2024, pursuant to the global stipulated settlement agreement approved by the LPSC also in August 2024, Entergy Louisiana filed its formula rate plan evaluation report for its 2023 calendar year operations. Consistent with the global stipulated settlement agreement, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the midpoint. For the 2023 test year, however, the bandwidth provisions of the formula rate plan were temporarily suspended and, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana implemented the September 2024 formula rate plan rate adjustments effective with the first billing cycle of September 2024. In January 2025, Entergy Louisiana and the LPSC filed a joint report indicating that no disputed issues remained in the proceeding and requesting that the LPSC issue an order accepting Entergy Louisiana’s evaluation report and, ultimately, resolving this matter. In March 2025 the LPSC issued an order accepting the evaluation report.

In December 2024, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed an interim rate adjustment for the 2023 test year reflecting the return of $25.1 million of refunds from the System Energy settlement with the LPSC to customers from January through August 2025. In February 2025, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting the divestiture of Entergy Louisiana’s share of Grand Gulf capacity and energy, which was effective as of January 1, 2025. The second interim rate adjustment also reflected a revenue increase of $17.8 million for the recovery of Hurricane Francine costs as approved by the LPSC (on an interim basis). The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the Hurricane Francine proceeding in “Storm Cost Recovery Filings with Retail Regulators – Entergy Louisiana – Hurricane Francine” below. See Note 8 to the financial statements in the Form 10-K for discussion of Entergy Louisiana’s divestiture from the Unit Power Sales Agreement.

2024 Formula Rate Plan Filing

In May 2025, Entergy Louisiana filed its formula rate plan evaluation report for its 2024 calendar year operations. Consistent with the global stipulated settlement agreement approved by the LPSC in August 2024, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the
midpoint. For the test year 2024, however, any earnings above the allowed return on common equity are to be returned to customers through a credit, pursuant to the terms of the global stipulated settlement agreement. The 2024 test year evaluation produced an earned return on common equity of 9.98%, which is within the approved formula rate plan bandwidth, but above the allowed return on common equity, resulting in a customer credit of $31.9 million to be returned to customers during September and October 2025.

Other changes in formula rate plan revenue are driven by higher nuclear depreciation rates, additions to transmission and distribution plant in service reflected through the transmission recovery mechanism and distribution recovery mechanism, and the expiration of customer credits related to the LPSC’s order, offset by increased customer credits resulting from an increase in net MISO revenues reflected through the MISO cost recovery mechanism and the reduction in the Louisiana corporate income tax rate effective January 1, 2025, reflected through the tax adjustment mechanism, as discussed below. Excluding the customer credit for earnings above the authorized return on common equity discussed above, the net result of these changes on an annualized basis is a $2 million increase in formula rate plan revenue.

As noted above, the 2024 evaluation report included the effects of the change in Louisiana state tax law that reduced the corporate income tax rate to a flat 5.5% (from the then-current highest marginal rate of 7.5%) effective January 1, 2025. As such, the 2024 evaluation report reflected the calculation of current and deferred income tax expenses as well as the revaluation of accumulated deferred income taxes based on the income tax laws currently in effect. The 2024 evaluation report proposes that the rate effects associated with the revaluation of accumulated deferred income taxes, including the collection of any net accumulated deferred income tax deficiency and any related effects on rate base, should be reflected in the tax adjustment mechanism consistent with the treatment of similar Tax Cuts and Jobs Act and prior state tax change-related impacts. The effects of the change in tax law on Entergy Louisiana’s authorized return on rate base are also reflected in the 2024 evaluation report consistent with the treatment cited above, including a credit in the extraordinary cost change mechanism for the prospective change in Entergy Louisiana’s authorized return and a credit within the tax adjustment mechanism for over-collection of income tax expense through August 2025.

Additional Generation and Transmission Resources

As discussed in the Form 10-K, in October 2024, Entergy Louisiana filed an application with the LPSC seeking approval of a variety of generation and transmission resources proposed in connection with establishing service to a new data center to be developed by a subsidiary of Meta Platforms, Inc. in north Louisiana, for which an electric service agreement has been executed. The filing requests LPSC certification of three new combined cycle combustion turbine generation resources totaling 2,262 MW, each of which will be enabled for future carbon capture and storage, a new 500 kV transmission line, and 500 kV substation upgrades. The application also requests approval to implement a corporate sustainability rider applicable to the new customer. The corporate sustainability rider contemplates the new customer contributing to the costs of the future addition of 1,500 MW of new solar and energy storage resources, agreements involving carbon capture and storage at Entergy Louisiana’s existing Lake Charles Power Station, and potential future wind and nuclear resources. Entergy Louisiana anticipates funding the incremental cost to serve the customer through direct financial contributions from the customer and the revenues it expects to earn under the electric service agreement. The electric service agreement also contains provisions for termination payments that will help ensure that there is no harm to Entergy Louisiana and its customers in the event of early termination. A directive was issued at the LPSC’s November 2024 meeting for the matter to be decided by October 2025. In February 2025 intervenors filed a motion asking the LPSC to deny Entergy Louisiana’s requested exemption from the LPSC’s order addressing competitive solicitation procedures and further asking the LPSC to dismiss the application. The ALJ issued an order denying the motion to dismiss the application and deferring the LPSC’s consideration of the motion regarding the competitive solicitation procedures until the hearing. In March 2025 the same intervenors filed a motion requesting the LPSC to require the customer and its parent company to be joined as parties to the proceeding or dismiss the application. In April 2025 the ALJ issued an order denying the March 2025 motion, and the moving parties filed a motion asking the LPSC to review and reverse the ALJ’s decision.
In February 2025, Entergy Louisiana filed supplemental testimony with the LPSC stating that the third combined cycle combustion turbine resource presented in the October 2024 application would be sited at Entergy Louisiana’s Waterford site in Killona, Louisiana, alongside existing Entergy Louisiana generation resources. The testimony also notes that Entergy Louisiana is negotiating with the customer in response to the customer’s request to increase the load associated with its project in north Louisiana. The testimony indicates further that the additional load can be served without additional generation capacity beyond what was presented in the October 2024 application, but that additional transmission facilities, which will be funded directly by the customer, are needed to serve this additional load.

In April 2025 and May 2025 the LPSC staff and certain intervenors each filed their direct testimony and cross-answering testimony, respectively. The LPSC staff’s testimony discussed the significant projected benefits associated with the data center project; however, both the LPSC staff and such intervenors also identified purported risks associated with constructing the requested resources based on the terms and conditions under which the customer would be taking service. Both the LPSC staff and such intervenors also recommended that the LPSC impose certain conditions on its approval which, if adopted, would support approval of Entergy Louisiana’s application. The LPSC staff’s recommendations included a condition that would require, under specified circumstances, certain sharing of net revenues from service to the project with Entergy Louisiana’s other customers. The LPSC staff also recommended that the LPSC deny approval of the corporate sustainability rider terms providing for the customer to supply funding toward the cost of installing carbon capture and storage infrastructure at Entergy Louisiana’s Lake Charles Power Station. The Louisiana Energy Users Group and other intervenors recommended that the LPSC require various changes to the terms of the electric service agreement with the customer that would shift additional risk and cost to the customer rather than Entergy Louisiana’s broader customer base. Certain intervenors also challenged approval on the basis that Entergy Louisiana did not conduct a request for proposals to procure the proposed generation resources to serve the customer’s project; these intervenors also advocated that Entergy Louisiana be required to procure more renewable generation and evaluate transmission alternatives rather than proceeding with development of all of the proposed new generation resources. In May 2025, Entergy Louisiana filed its rebuttal testimony responding to the direct and cross-answering testimony of the LPSC staff and intervenors. The rebuttal testimony expressed support for or no opposition to the LPSC’s adoption of certain of the proposed recommendations and identified why other proposed recommendations should not be adopted. In addition, the rebuttal testimony stated that the negotiations related to the increase in the load amount for the customer’s project had concluded and that a rider to the electric service agreement reflecting this increase had been executed. In advance of the July 2025 hearing, Entergy Louisiana reached a settlement agreement with the LPSC staff and three separate intervenors. The hearing concluded and the matter is currently under consideration by the ALJ.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In April 2023, Entergy Louisiana filed an application proposing to utilize approximately $1.6 billion in certain low interest debt to generate earnings to apply toward the reduction of the COVID-19 regulatory asset, as well as to conduct additional outside right-of-way vegetation management activities and fund the minor storm reserve account. In that filing, Entergy Louisiana proposed to delay repayment of certain shorter-term first mortgage bonds that were issued to finance storm restoration costs until the costs could be securitized, and to invest the funds that otherwise would be used to repay those bonds in the money pool to take advantage of the spread between prevailing interest rates on investments in the money pool and the interest rates on the bonds. The LPSC approved Entergy Louisiana’s requested relief in June 2023. In November 2024, Entergy Louisiana submitted a filing to the LPSC requesting that the LPSC review Entergy Louisiana’s computation of the COVID-19 regulatory asset as well as Entergy Louisiana’s proposal to offset the regulatory asset against the net interest earned on the short-term debt funds, resulting in no increased costs to customers. At the time of the filing, Entergy Louisiana had a regulatory asset of $47.8 million for costs associated
with the COVID-19 pandemic. As of June 30, 2025, Entergy Louisiana had a regulatory liability of $48.9 million for the deferred earnings related to the approximately $1.6 billion in low interest debt, which had been fully repaid by August 2024. In granting Entergy Louisiana’s requested relief in June 2023, the LPSC ordered that any amount of earnings exceeding the amount of the COVID-19 regulatory asset be transferred to Entergy Louisiana’s storm reserve escrow account. In May 2025 the LPSC staff filed direct testimony finding that Entergy Louisiana had complied with the relevant orders and recommending approval of the requested treatment. In June 2025, Entergy Louisiana and the LPSC staff filed a joint motion requesting a hearing for the admission of an uncontested stipulated settlement agreement in the matter. A settlement hearing took place in July 2025 and Entergy Louisiana expects the settlement to be considered at an upcoming meeting of the LPSC. The settlement terms provide for LPSC approval of Entergy Louisiana’s calculation of the COVID-19 regulatory assets and Entergy Louisiana’s proposal to offset the regulatory asset as described above and as proposed in Entergy Louisiana’s November 2024 filing.

Filings with the MPSC (Entergy Mississippi)

Retail Rates

2025 Formula Rate Plan Filing

In February 2025, Entergy Mississippi submitted its formula rate plan 2025 test year filing and 2024 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2024 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2025 calendar year also to be within the formula rate plan bandwidth. The 2025 test year filing showed an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2024 look-back filing compared actual 2024 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues, although Entergy Mississippi proposed to adjust interim rates by $135 thousand to reflect two outside-the-bandwidth changes: (1) the completion of Entergy Mississippi’s return to customers of credits under its restructuring credit rider; and (2) a true-up of demand side management costs.

In June 2025, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2025 test year filing, with the exception of immaterial adjustments to certain operation and maintenance expenses. The formula rate plan reflected an earned return on rate base of 7.68% for calendar year 2025, resulting in no change in formula rate plan revenues for 2025. Pursuant to the stipulation, Entergy Mississippi’s 2024 look-back filing reflected an earned return on rate base of 7.55%, which also resulted in no change in formula rate plan revenues for 2024. In addition, the stipulation included the recovery of the two outside-the-bandwidth changes discussed above as well as the ratemaking treatment of customer contributions (deferred revenue and prepaid contributions in aid of construction). In June 2025 the MPSC approved the joint stipulation with rates effective in July 2025.

Interim Facilities Rate Adjustments

In May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with state legislation passed in January 2024. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed the first of its annual interim facilities rate adjustment reports in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Entergy Mississippi filed its second interim facilities rate adjustment report in November 2024 to recover approximately $46.7 million of these costs over a 12-month period with rates effective beginning in January 2025. In February 2025, Entergy Mississippi filed a true-up interim facilities rate adjustment report to the initial annual interim facilities rate adjustment report filed in May 2024, reflecting the recovery of an
additional approximately $1.0 million of costs over a 12-month period with rates effective with the first billing cycle of April 2025.

Filings with the City Council (Entergy New Orleans)

Retail Rates

2025 Formula Rate Plan Filing

In April 2025, Entergy New Orleans submitted to the City Council its formula rate plan 2024 test year filing. The 2024 evaluation report produced an electric earned return on equity of 10.98% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in a decrease in electric rates of $13.8 million. The decrease in electric rates is driven by the realignment of regulatory liabilities into the formula from a separate rate mechanism, partially offset by the cost of known and measurable electric capital additions. The filing also commences the previously authorized recovery of certain regulatory costs and requests a revenue-neutral recovery to offset a proposed reduction in bill payment late fees. Taking into account these proposed adjustments, the filing presents a decrease in authorized electric revenues of $8.6 million. The City Council’s advisors issued their report in July 2025 seeking a reduction in Entergy New Orleans’s requested electric formula rate plan revenues of approximately $7.2 million due to certain proposed cost realignments and disallowances, of which $4.1 million is associated with Entergy New Orleans’s proposed implementation, on a revenue neutral basis, of a proposed reduction in customer late fees. The City Council’s advisors also proposed rate mitigation in the amount of $4.4 million through offsets to the formula rate plan funded by certain regulatory liabilities. The City Council’s advisors’ report began a 35-day period to resolve any disputes among the parties regarding the formula rate plan. For any disputed rate adjustments, the City Council would set a procedural schedule to resolve. Resulting rates will be effective with the first billing cycle of September 2025 pursuant to the formula rate plan tariff.

Filings with the PUCT and Texas Cities (Entergy Texas)

Retail Rates

Distribution Cost Recovery Factor (DCRF) Rider

In April 2025, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $77.8 million annually, or $29.3 million in incremental annual revenues beyond Entergy Texas’s then-effective DCRF rider based on its capital invested in distribution between July 1, 2024 and December 31, 2024, including distribution-related restoration costs associated with Hurricane Beryl. In June 2025 the PUCT approved the DCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective on June 25, 2025.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2024, Entergy Texas filed with the PUCT a request to amend its TCRF rider, which was previously reset to zero in June 2023 as a result of the 2022 base rate case. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $9.7 million annually based on its capital invested in transmission between January 1, 2022 and June 30, 2024 and changes in other transmission charges. In April 2025 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 7, 2025.

Entergy Arkansas Opportunity Sales Proceeding

As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments
to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023.

In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth Circuit and the court granted the motion to expedite. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. In December 2024 the United States Court of Appeals for the Eighth Circuit affirmed the decision of the U.S. District Court for the Eastern District of Arkansas, and Entergy Arkansas filed a petition for rehearing en banc. In January 2025 the United States Court of Appeals for the Eighth Circuit denied Entergy Arkansas’s petition. In April 2025, Entergy Arkansas filed a petition for certiorari with the United States Supreme Court. In June 2025 the United States Supreme Court denied Entergy Arkansas’s petition for certiorari.

MSS-4 Replacement Tariff - Net Operating Loss Carryforward Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the MSS-4 replacement tariff net operating loss carryforward proceeding.

The MSS-4 replacement tariff, a tariff governing the sales of energy and capacity among the Utility operating companies, includes protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In April 2025, pursuant to such protocols, the City Council filed with the FERC a formal challenge relating to Entergy Services’ inclusion and allocation of net operating loss carryforward accumulated deferred income taxes in the MSS-4 replacement tariff rates charged to Entergy New Orleans’s monthly bills for calendar year 2023. In May 2025, Entergy Services filed a response to the formal challenge and is awaiting a response from the FERC.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. The following are updates to that discussion.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in February 2023, System Energy submitted a tariff compliance filing with the FERC to clarify that, consistent with the releases provided in the June 2022 MPSC settlement, Entergy Mississippi would continue to be charged for its allocation of the sale-leaseback renewal costs under the Unit Power Sales Agreement. In March 2023 the MPSC filed a protest to System Energy’s tariff compliance filing. The MPSC argued that the settlement did not specifically address post-settlement sale-leaseback renewal costs and that the sale-leaseback renewal costs may not be recovered under the Unit Power Sales Agreement. In February 2025, System Energy and the MPSC resolved their dispute concerning the sale-leaseback renewal costs. As a result, the MPSC withdrew its protest at the FERC on System Energy’s tariff compliance filing. Entergy Mississippi will continue to pay the allocated sale-leaseback renewal costs of approximately $5.7 million annually and there are no refunds due for prior periods. In March 2025, System Energy filed a status report with the FERC explaining that the dispute is resolved. In April 2025 the FERC accepted System Energy’s tariff compliance filing.
System Energy Settlement with the LPSC

As discussed in the Form 10-K, in 2024, System Energy reached a settlement with the LPSC to globally resolve all of the LPSC’s actual and potential claims in multiple docketed proceedings pending before the FERC (including all docketed proceedings resolved by the MPSC, the APSC, and the City Council settlements) and associated with System Energy’s past implementation of the Unit Power Sales Agreement. In compliance with the settlement, in May 2025, System Energy, Entergy Louisiana, and Entergy Mississippi submitted the following filings with the FERC: (1) a Federal Power Act Section 203 application seeking approval for the permanent divestiture by Entergy Louisiana to Entergy Mississippi of its rights to capacity and energy from Grand Gulf; and (2) a Federal Power Act Section 205 application seeking approval to modify the entitlement percentages of the remaining purchasers under the Unit Power Sales Agreement in connection with the foregoing divestiture. In July 2025, the FERC issued an order accepting the Federal Power Act Section 205 application to remove Entergy Louisiana as a party to the Unit Power Sales Agreement. As a result of the order, the Unit Power Sales Agreement entitlement percentages of the remaining purchasers will be permanently modified to exclude Entergy Louisiana, to be effective beginning October 2025. The FERC also issued an order dismissing the Federal Power Act Section 203 application based on lack of jurisdiction.

Storm Cost Recovery Filings with Retail Regulators

See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following is an update to that discussion.

Entergy Louisiana

Hurricane Francine

In September 2024, Hurricane Francine caused damage to the areas served by Entergy Louisiana. The storm resulted in widespread power outages, primarily due to damage to distribution infrastructure as a result of strong winds and heavy rain, and the loss of sales during the power outages.

In December 2024, and subsequently amended in an errata filed in February 2025, Entergy Louisiana submitted an application to the LPSC seeking a determination that approximately $183.6 million in storm restoration costs associated with Hurricane Francine were reasonable and necessary and, therefore, eligible for recovery from customers, as well as approval to recover approximately $3.6 million in certain carrying costs from customers. In February 2025, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting a revenue increase of $17.8 million from funds approved by the LPSC (on an interim basis) for Hurricane Francine recovery costs. The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the 2023 formula rate plan filing above. Also in February 2025, Entergy Louisiana withdrew $33.5 million from its funded storm reserves. In June 2025 the LPSC staff filed direct testimony. The LPSC staff recommends approval of Entergy Louisiana’s as-requested storm restoration costs with the exception of approximately $10.6 million, comprised primarily of estimates of mutual assistance invoices that have not yet been received at the time of filing and that ultimately exceeded the actual amounts invoiced, as well as certain incentive compensation, and $1.8 million associated with certain carrying costs. Entergy Louisiana’s rebuttal testimony is due in August 2025 and a hearing is scheduled for November 2025.
Entergy Arkansas [Member]  
Public Utilities Disclosure [Text Block] RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Regulatory Assets and Regulatory Liabilities

See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

In March 2025, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.00882 per kWh to $0.01333 per kWh. The annual redetermination included a credit related to the remaining balance due to retail customers from the System Energy settlement with the APSC, plus carrying charges and interest. See “Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - Grand Gulf Credit Rider” below for further discussion. The primary reason for the rate increase is an adjustment to account for projected increases in natural gas prices in 2025. This adjustment is expected to reduce the rate change that will be reflected in its 2026 energy cost rate redetermination. The redetermined rate of $0.01333 per kWh became effective with the first billing cycle in April 2025 through the normal operation of the tariff.
Entergy Louisiana

As discussed in the Form 10-K, in January 2023 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2021 through 2022. In April 2025 the LPSC staff issued its audit report (for Entergy Louisiana’s gas operations), which included several prospective recommendations but no financial disallowances. The LPSC accepted the report in June 2025.

Entergy Texas

As discussed in the Form 10-K, in September 2024, Entergy Texas filed an application with the PUCT to reconcile its fuel and purchased power costs for the period from April 2022 through March 2024. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in eligible fuel and purchased power expenses to generate and purchase electricity to serve its customers, net of certain revenues credited to such expenses and other adjustments. Entergy Texas’s cumulative under-recovery balance for the reconciliation period was approximately $30 million, including interest, which Entergy Texas requested authority to carry over as part of the cumulative fuel balance for the subsequent reconciliation period beginning April 2024. In November 2024 the PUCT referred the proceeding to the State Office of Administrative Hearings. In March 2025, Texas Industrial Energy Consumers, an intervenor, filed testimony regarding the recovery of capacity costs for a certain power purchase agreement, arguing the capacity costs should be imputed and treated as non-reconcilable fuel expense, recovered in Entergy Texas’s base rates. In April 2025 the PUCT staff filed testimony and later in April 2025, Entergy Texas filed rebuttal testimony. In May 2025, Entergy Texas filed, and the ALJ with the State Office of Administrative Hearings granted, a request for a paper hearing and to cancel the oral hearing on the merits previously scheduled for later in May 2025. In June 2025, Entergy Texas filed, and the ALJ with the State Office of Administrative Hearings granted, a joint motion to abate the proceeding to give the parties to the proceeding additional time to finalize a settlement.

Retail Rate Proceedings

See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion.

Filings with the APSC (Entergy Arkansas)

Retail Rates

2025 Formula Rate Plan Filing

In July 2025, Entergy Arkansas filed with the APSC its 2025 formula rate plan filing to set its formula rate for the 2026 calendar year.  The filing contained an evaluation of Entergy Arkansas’s earnings for the 2026 projected year and a netting adjustment for the 2024 historical year.  The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2026 projected year was 8.45% resulting in a revenue deficiency of $68.9 million.  The earned rate of return on common equity for the 2024 historical year was 7.71% resulting in a $48.8 million netting adjustment.  The total proposed revenue change for the 2026 projected year and 2024 historical year netting adjustment is $117.7 million.   By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint.  Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase was limited to $92.3 million. Entergy Arkansas proposed a procedural schedule that includes a hearing in November 2025 and requests an APSC order in December 2025.
Grand Gulf Credit Rider

As discussed in the Form 10-K, in June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “Complaints Against System Energy - System Energy Settlement with the APSC” in Note 2 to the financial statements in the Form 10-K for discussion of the System Energy settlement with the APSC. In July 2024 the APSC approved the tariff, under which Entergy Arkansas would refund to retail customers a total of $100.6 million. Entergy Arkansas refunded $92.3 million of the total through one-time bill credits under the Grand Gulf credit rider during the August 2024 billing cycle. In March 2025, Entergy Arkansas included the remaining balance as a credit to retail customers in its energy cost recovery rider rate redetermination filing. See further discussion within "Regulatory Assets and Regulatory Liabilities - Fuel and purchased power cost recovery - Entergy Arkansas - Energy Cost Recovery Rider" above. In April 2025 the APSC approved Entergy Arkansas’s proposal to include the remaining balance in its energy cost recovery rider effective with the first billing cycle of April 2025 and the withdrawal of the Grand Gulf credit rider after all credits had been issued. Credits to retail customers were completed in second quarter 2025, and the Grand Gulf credit rider was subsequently withdrawn.

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2023 Formula Rate Plan Filing

As discussed in the Form 10-K, in August 2024, pursuant to the global stipulated settlement agreement approved by the LPSC also in August 2024, Entergy Louisiana filed its formula rate plan evaluation report for its 2023 calendar year operations. Consistent with the global stipulated settlement agreement, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the midpoint. For the 2023 test year, however, the bandwidth provisions of the formula rate plan were temporarily suspended and, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana implemented the September 2024 formula rate plan rate adjustments effective with the first billing cycle of September 2024. In January 2025, Entergy Louisiana and the LPSC filed a joint report indicating that no disputed issues remained in the proceeding and requesting that the LPSC issue an order accepting Entergy Louisiana’s evaluation report and, ultimately, resolving this matter. In March 2025 the LPSC issued an order accepting the evaluation report.

In December 2024, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed an interim rate adjustment for the 2023 test year reflecting the return of $25.1 million of refunds from the System Energy settlement with the LPSC to customers from January through August 2025. In February 2025, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting the divestiture of Entergy Louisiana’s share of Grand Gulf capacity and energy, which was effective as of January 1, 2025. The second interim rate adjustment also reflected a revenue increase of $17.8 million for the recovery of Hurricane Francine costs as approved by the LPSC (on an interim basis). The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the Hurricane Francine proceeding in “Storm Cost Recovery Filings with Retail Regulators – Entergy Louisiana – Hurricane Francine” below. See Note 8 to the financial statements in the Form 10-K for discussion of Entergy Louisiana’s divestiture from the Unit Power Sales Agreement.

2024 Formula Rate Plan Filing

In May 2025, Entergy Louisiana filed its formula rate plan evaluation report for its 2024 calendar year operations. Consistent with the global stipulated settlement agreement approved by the LPSC in August 2024, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the
midpoint. For the test year 2024, however, any earnings above the allowed return on common equity are to be returned to customers through a credit, pursuant to the terms of the global stipulated settlement agreement. The 2024 test year evaluation produced an earned return on common equity of 9.98%, which is within the approved formula rate plan bandwidth, but above the allowed return on common equity, resulting in a customer credit of $31.9 million to be returned to customers during September and October 2025.

Other changes in formula rate plan revenue are driven by higher nuclear depreciation rates, additions to transmission and distribution plant in service reflected through the transmission recovery mechanism and distribution recovery mechanism, and the expiration of customer credits related to the LPSC’s order, offset by increased customer credits resulting from an increase in net MISO revenues reflected through the MISO cost recovery mechanism and the reduction in the Louisiana corporate income tax rate effective January 1, 2025, reflected through the tax adjustment mechanism, as discussed below. Excluding the customer credit for earnings above the authorized return on common equity discussed above, the net result of these changes on an annualized basis is a $2 million increase in formula rate plan revenue.

As noted above, the 2024 evaluation report included the effects of the change in Louisiana state tax law that reduced the corporate income tax rate to a flat 5.5% (from the then-current highest marginal rate of 7.5%) effective January 1, 2025. As such, the 2024 evaluation report reflected the calculation of current and deferred income tax expenses as well as the revaluation of accumulated deferred income taxes based on the income tax laws currently in effect. The 2024 evaluation report proposes that the rate effects associated with the revaluation of accumulated deferred income taxes, including the collection of any net accumulated deferred income tax deficiency and any related effects on rate base, should be reflected in the tax adjustment mechanism consistent with the treatment of similar Tax Cuts and Jobs Act and prior state tax change-related impacts. The effects of the change in tax law on Entergy Louisiana’s authorized return on rate base are also reflected in the 2024 evaluation report consistent with the treatment cited above, including a credit in the extraordinary cost change mechanism for the prospective change in Entergy Louisiana’s authorized return and a credit within the tax adjustment mechanism for over-collection of income tax expense through August 2025.

Additional Generation and Transmission Resources

As discussed in the Form 10-K, in October 2024, Entergy Louisiana filed an application with the LPSC seeking approval of a variety of generation and transmission resources proposed in connection with establishing service to a new data center to be developed by a subsidiary of Meta Platforms, Inc. in north Louisiana, for which an electric service agreement has been executed. The filing requests LPSC certification of three new combined cycle combustion turbine generation resources totaling 2,262 MW, each of which will be enabled for future carbon capture and storage, a new 500 kV transmission line, and 500 kV substation upgrades. The application also requests approval to implement a corporate sustainability rider applicable to the new customer. The corporate sustainability rider contemplates the new customer contributing to the costs of the future addition of 1,500 MW of new solar and energy storage resources, agreements involving carbon capture and storage at Entergy Louisiana’s existing Lake Charles Power Station, and potential future wind and nuclear resources. Entergy Louisiana anticipates funding the incremental cost to serve the customer through direct financial contributions from the customer and the revenues it expects to earn under the electric service agreement. The electric service agreement also contains provisions for termination payments that will help ensure that there is no harm to Entergy Louisiana and its customers in the event of early termination. A directive was issued at the LPSC’s November 2024 meeting for the matter to be decided by October 2025. In February 2025 intervenors filed a motion asking the LPSC to deny Entergy Louisiana’s requested exemption from the LPSC’s order addressing competitive solicitation procedures and further asking the LPSC to dismiss the application. The ALJ issued an order denying the motion to dismiss the application and deferring the LPSC’s consideration of the motion regarding the competitive solicitation procedures until the hearing. In March 2025 the same intervenors filed a motion requesting the LPSC to require the customer and its parent company to be joined as parties to the proceeding or dismiss the application. In April 2025 the ALJ issued an order denying the March 2025 motion, and the moving parties filed a motion asking the LPSC to review and reverse the ALJ’s decision.
In February 2025, Entergy Louisiana filed supplemental testimony with the LPSC stating that the third combined cycle combustion turbine resource presented in the October 2024 application would be sited at Entergy Louisiana’s Waterford site in Killona, Louisiana, alongside existing Entergy Louisiana generation resources. The testimony also notes that Entergy Louisiana is negotiating with the customer in response to the customer’s request to increase the load associated with its project in north Louisiana. The testimony indicates further that the additional load can be served without additional generation capacity beyond what was presented in the October 2024 application, but that additional transmission facilities, which will be funded directly by the customer, are needed to serve this additional load.

In April 2025 and May 2025 the LPSC staff and certain intervenors each filed their direct testimony and cross-answering testimony, respectively. The LPSC staff’s testimony discussed the significant projected benefits associated with the data center project; however, both the LPSC staff and such intervenors also identified purported risks associated with constructing the requested resources based on the terms and conditions under which the customer would be taking service. Both the LPSC staff and such intervenors also recommended that the LPSC impose certain conditions on its approval which, if adopted, would support approval of Entergy Louisiana’s application. The LPSC staff’s recommendations included a condition that would require, under specified circumstances, certain sharing of net revenues from service to the project with Entergy Louisiana’s other customers. The LPSC staff also recommended that the LPSC deny approval of the corporate sustainability rider terms providing for the customer to supply funding toward the cost of installing carbon capture and storage infrastructure at Entergy Louisiana’s Lake Charles Power Station. The Louisiana Energy Users Group and other intervenors recommended that the LPSC require various changes to the terms of the electric service agreement with the customer that would shift additional risk and cost to the customer rather than Entergy Louisiana’s broader customer base. Certain intervenors also challenged approval on the basis that Entergy Louisiana did not conduct a request for proposals to procure the proposed generation resources to serve the customer’s project; these intervenors also advocated that Entergy Louisiana be required to procure more renewable generation and evaluate transmission alternatives rather than proceeding with development of all of the proposed new generation resources. In May 2025, Entergy Louisiana filed its rebuttal testimony responding to the direct and cross-answering testimony of the LPSC staff and intervenors. The rebuttal testimony expressed support for or no opposition to the LPSC’s adoption of certain of the proposed recommendations and identified why other proposed recommendations should not be adopted. In addition, the rebuttal testimony stated that the negotiations related to the increase in the load amount for the customer’s project had concluded and that a rider to the electric service agreement reflecting this increase had been executed. In advance of the July 2025 hearing, Entergy Louisiana reached a settlement agreement with the LPSC staff and three separate intervenors. The hearing concluded and the matter is currently under consideration by the ALJ.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In April 2023, Entergy Louisiana filed an application proposing to utilize approximately $1.6 billion in certain low interest debt to generate earnings to apply toward the reduction of the COVID-19 regulatory asset, as well as to conduct additional outside right-of-way vegetation management activities and fund the minor storm reserve account. In that filing, Entergy Louisiana proposed to delay repayment of certain shorter-term first mortgage bonds that were issued to finance storm restoration costs until the costs could be securitized, and to invest the funds that otherwise would be used to repay those bonds in the money pool to take advantage of the spread between prevailing interest rates on investments in the money pool and the interest rates on the bonds. The LPSC approved Entergy Louisiana’s requested relief in June 2023. In November 2024, Entergy Louisiana submitted a filing to the LPSC requesting that the LPSC review Entergy Louisiana’s computation of the COVID-19 regulatory asset as well as Entergy Louisiana’s proposal to offset the regulatory asset against the net interest earned on the short-term debt funds, resulting in no increased costs to customers. At the time of the filing, Entergy Louisiana had a regulatory asset of $47.8 million for costs associated
with the COVID-19 pandemic. As of June 30, 2025, Entergy Louisiana had a regulatory liability of $48.9 million for the deferred earnings related to the approximately $1.6 billion in low interest debt, which had been fully repaid by August 2024. In granting Entergy Louisiana’s requested relief in June 2023, the LPSC ordered that any amount of earnings exceeding the amount of the COVID-19 regulatory asset be transferred to Entergy Louisiana’s storm reserve escrow account. In May 2025 the LPSC staff filed direct testimony finding that Entergy Louisiana had complied with the relevant orders and recommending approval of the requested treatment. In June 2025, Entergy Louisiana and the LPSC staff filed a joint motion requesting a hearing for the admission of an uncontested stipulated settlement agreement in the matter. A settlement hearing took place in July 2025 and Entergy Louisiana expects the settlement to be considered at an upcoming meeting of the LPSC. The settlement terms provide for LPSC approval of Entergy Louisiana’s calculation of the COVID-19 regulatory assets and Entergy Louisiana’s proposal to offset the regulatory asset as described above and as proposed in Entergy Louisiana’s November 2024 filing.

Filings with the MPSC (Entergy Mississippi)

Retail Rates

2025 Formula Rate Plan Filing

In February 2025, Entergy Mississippi submitted its formula rate plan 2025 test year filing and 2024 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2024 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2025 calendar year also to be within the formula rate plan bandwidth. The 2025 test year filing showed an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2024 look-back filing compared actual 2024 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues, although Entergy Mississippi proposed to adjust interim rates by $135 thousand to reflect two outside-the-bandwidth changes: (1) the completion of Entergy Mississippi’s return to customers of credits under its restructuring credit rider; and (2) a true-up of demand side management costs.

In June 2025, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2025 test year filing, with the exception of immaterial adjustments to certain operation and maintenance expenses. The formula rate plan reflected an earned return on rate base of 7.68% for calendar year 2025, resulting in no change in formula rate plan revenues for 2025. Pursuant to the stipulation, Entergy Mississippi’s 2024 look-back filing reflected an earned return on rate base of 7.55%, which also resulted in no change in formula rate plan revenues for 2024. In addition, the stipulation included the recovery of the two outside-the-bandwidth changes discussed above as well as the ratemaking treatment of customer contributions (deferred revenue and prepaid contributions in aid of construction). In June 2025 the MPSC approved the joint stipulation with rates effective in July 2025.

Interim Facilities Rate Adjustments

In May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with state legislation passed in January 2024. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed the first of its annual interim facilities rate adjustment reports in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Entergy Mississippi filed its second interim facilities rate adjustment report in November 2024 to recover approximately $46.7 million of these costs over a 12-month period with rates effective beginning in January 2025. In February 2025, Entergy Mississippi filed a true-up interim facilities rate adjustment report to the initial annual interim facilities rate adjustment report filed in May 2024, reflecting the recovery of an
additional approximately $1.0 million of costs over a 12-month period with rates effective with the first billing cycle of April 2025.

Filings with the City Council (Entergy New Orleans)

Retail Rates

2025 Formula Rate Plan Filing

In April 2025, Entergy New Orleans submitted to the City Council its formula rate plan 2024 test year filing. The 2024 evaluation report produced an electric earned return on equity of 10.98% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in a decrease in electric rates of $13.8 million. The decrease in electric rates is driven by the realignment of regulatory liabilities into the formula from a separate rate mechanism, partially offset by the cost of known and measurable electric capital additions. The filing also commences the previously authorized recovery of certain regulatory costs and requests a revenue-neutral recovery to offset a proposed reduction in bill payment late fees. Taking into account these proposed adjustments, the filing presents a decrease in authorized electric revenues of $8.6 million. The City Council’s advisors issued their report in July 2025 seeking a reduction in Entergy New Orleans’s requested electric formula rate plan revenues of approximately $7.2 million due to certain proposed cost realignments and disallowances, of which $4.1 million is associated with Entergy New Orleans’s proposed implementation, on a revenue neutral basis, of a proposed reduction in customer late fees. The City Council’s advisors also proposed rate mitigation in the amount of $4.4 million through offsets to the formula rate plan funded by certain regulatory liabilities. The City Council’s advisors’ report began a 35-day period to resolve any disputes among the parties regarding the formula rate plan. For any disputed rate adjustments, the City Council would set a procedural schedule to resolve. Resulting rates will be effective with the first billing cycle of September 2025 pursuant to the formula rate plan tariff.

Filings with the PUCT and Texas Cities (Entergy Texas)

Retail Rates

Distribution Cost Recovery Factor (DCRF) Rider

In April 2025, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $77.8 million annually, or $29.3 million in incremental annual revenues beyond Entergy Texas’s then-effective DCRF rider based on its capital invested in distribution between July 1, 2024 and December 31, 2024, including distribution-related restoration costs associated with Hurricane Beryl. In June 2025 the PUCT approved the DCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective on June 25, 2025.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2024, Entergy Texas filed with the PUCT a request to amend its TCRF rider, which was previously reset to zero in June 2023 as a result of the 2022 base rate case. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $9.7 million annually based on its capital invested in transmission between January 1, 2022 and June 30, 2024 and changes in other transmission charges. In April 2025 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 7, 2025.

Entergy Arkansas Opportunity Sales Proceeding

As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments
to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023.

In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth Circuit and the court granted the motion to expedite. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. In December 2024 the United States Court of Appeals for the Eighth Circuit affirmed the decision of the U.S. District Court for the Eastern District of Arkansas, and Entergy Arkansas filed a petition for rehearing en banc. In January 2025 the United States Court of Appeals for the Eighth Circuit denied Entergy Arkansas’s petition. In April 2025, Entergy Arkansas filed a petition for certiorari with the United States Supreme Court. In June 2025 the United States Supreme Court denied Entergy Arkansas’s petition for certiorari.

MSS-4 Replacement Tariff - Net Operating Loss Carryforward Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the MSS-4 replacement tariff net operating loss carryforward proceeding.

The MSS-4 replacement tariff, a tariff governing the sales of energy and capacity among the Utility operating companies, includes protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In April 2025, pursuant to such protocols, the City Council filed with the FERC a formal challenge relating to Entergy Services’ inclusion and allocation of net operating loss carryforward accumulated deferred income taxes in the MSS-4 replacement tariff rates charged to Entergy New Orleans’s monthly bills for calendar year 2023. In May 2025, Entergy Services filed a response to the formal challenge and is awaiting a response from the FERC.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. The following are updates to that discussion.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in February 2023, System Energy submitted a tariff compliance filing with the FERC to clarify that, consistent with the releases provided in the June 2022 MPSC settlement, Entergy Mississippi would continue to be charged for its allocation of the sale-leaseback renewal costs under the Unit Power Sales Agreement. In March 2023 the MPSC filed a protest to System Energy’s tariff compliance filing. The MPSC argued that the settlement did not specifically address post-settlement sale-leaseback renewal costs and that the sale-leaseback renewal costs may not be recovered under the Unit Power Sales Agreement. In February 2025, System Energy and the MPSC resolved their dispute concerning the sale-leaseback renewal costs. As a result, the MPSC withdrew its protest at the FERC on System Energy’s tariff compliance filing. Entergy Mississippi will continue to pay the allocated sale-leaseback renewal costs of approximately $5.7 million annually and there are no refunds due for prior periods. In March 2025, System Energy filed a status report with the FERC explaining that the dispute is resolved. In April 2025 the FERC accepted System Energy’s tariff compliance filing.
System Energy Settlement with the LPSC

As discussed in the Form 10-K, in 2024, System Energy reached a settlement with the LPSC to globally resolve all of the LPSC’s actual and potential claims in multiple docketed proceedings pending before the FERC (including all docketed proceedings resolved by the MPSC, the APSC, and the City Council settlements) and associated with System Energy’s past implementation of the Unit Power Sales Agreement. In compliance with the settlement, in May 2025, System Energy, Entergy Louisiana, and Entergy Mississippi submitted the following filings with the FERC: (1) a Federal Power Act Section 203 application seeking approval for the permanent divestiture by Entergy Louisiana to Entergy Mississippi of its rights to capacity and energy from Grand Gulf; and (2) a Federal Power Act Section 205 application seeking approval to modify the entitlement percentages of the remaining purchasers under the Unit Power Sales Agreement in connection with the foregoing divestiture. In July 2025, the FERC issued an order accepting the Federal Power Act Section 205 application to remove Entergy Louisiana as a party to the Unit Power Sales Agreement. As a result of the order, the Unit Power Sales Agreement entitlement percentages of the remaining purchasers will be permanently modified to exclude Entergy Louisiana, to be effective beginning October 2025. The FERC also issued an order dismissing the Federal Power Act Section 203 application based on lack of jurisdiction.

Storm Cost Recovery Filings with Retail Regulators

See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following is an update to that discussion.

Entergy Louisiana

Hurricane Francine

In September 2024, Hurricane Francine caused damage to the areas served by Entergy Louisiana. The storm resulted in widespread power outages, primarily due to damage to distribution infrastructure as a result of strong winds and heavy rain, and the loss of sales during the power outages.

In December 2024, and subsequently amended in an errata filed in February 2025, Entergy Louisiana submitted an application to the LPSC seeking a determination that approximately $183.6 million in storm restoration costs associated with Hurricane Francine were reasonable and necessary and, therefore, eligible for recovery from customers, as well as approval to recover approximately $3.6 million in certain carrying costs from customers. In February 2025, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting a revenue increase of $17.8 million from funds approved by the LPSC (on an interim basis) for Hurricane Francine recovery costs. The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the 2023 formula rate plan filing above. Also in February 2025, Entergy Louisiana withdrew $33.5 million from its funded storm reserves. In June 2025 the LPSC staff filed direct testimony. The LPSC staff recommends approval of Entergy Louisiana’s as-requested storm restoration costs with the exception of approximately $10.6 million, comprised primarily of estimates of mutual assistance invoices that have not yet been received at the time of filing and that ultimately exceeded the actual amounts invoiced, as well as certain incentive compensation, and $1.8 million associated with certain carrying costs. Entergy Louisiana’s rebuttal testimony is due in August 2025 and a hearing is scheduled for November 2025.
Entergy Louisiana [Member]  
Public Utilities Disclosure [Text Block] RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Regulatory Assets and Regulatory Liabilities

See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

In March 2025, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.00882 per kWh to $0.01333 per kWh. The annual redetermination included a credit related to the remaining balance due to retail customers from the System Energy settlement with the APSC, plus carrying charges and interest. See “Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - Grand Gulf Credit Rider” below for further discussion. The primary reason for the rate increase is an adjustment to account for projected increases in natural gas prices in 2025. This adjustment is expected to reduce the rate change that will be reflected in its 2026 energy cost rate redetermination. The redetermined rate of $0.01333 per kWh became effective with the first billing cycle in April 2025 through the normal operation of the tariff.
Entergy Louisiana

As discussed in the Form 10-K, in January 2023 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2021 through 2022. In April 2025 the LPSC staff issued its audit report (for Entergy Louisiana’s gas operations), which included several prospective recommendations but no financial disallowances. The LPSC accepted the report in June 2025.

Entergy Texas

As discussed in the Form 10-K, in September 2024, Entergy Texas filed an application with the PUCT to reconcile its fuel and purchased power costs for the period from April 2022 through March 2024. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in eligible fuel and purchased power expenses to generate and purchase electricity to serve its customers, net of certain revenues credited to such expenses and other adjustments. Entergy Texas’s cumulative under-recovery balance for the reconciliation period was approximately $30 million, including interest, which Entergy Texas requested authority to carry over as part of the cumulative fuel balance for the subsequent reconciliation period beginning April 2024. In November 2024 the PUCT referred the proceeding to the State Office of Administrative Hearings. In March 2025, Texas Industrial Energy Consumers, an intervenor, filed testimony regarding the recovery of capacity costs for a certain power purchase agreement, arguing the capacity costs should be imputed and treated as non-reconcilable fuel expense, recovered in Entergy Texas’s base rates. In April 2025 the PUCT staff filed testimony and later in April 2025, Entergy Texas filed rebuttal testimony. In May 2025, Entergy Texas filed, and the ALJ with the State Office of Administrative Hearings granted, a request for a paper hearing and to cancel the oral hearing on the merits previously scheduled for later in May 2025. In June 2025, Entergy Texas filed, and the ALJ with the State Office of Administrative Hearings granted, a joint motion to abate the proceeding to give the parties to the proceeding additional time to finalize a settlement.

Retail Rate Proceedings

See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion.

Filings with the APSC (Entergy Arkansas)

Retail Rates

2025 Formula Rate Plan Filing

In July 2025, Entergy Arkansas filed with the APSC its 2025 formula rate plan filing to set its formula rate for the 2026 calendar year.  The filing contained an evaluation of Entergy Arkansas’s earnings for the 2026 projected year and a netting adjustment for the 2024 historical year.  The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2026 projected year was 8.45% resulting in a revenue deficiency of $68.9 million.  The earned rate of return on common equity for the 2024 historical year was 7.71% resulting in a $48.8 million netting adjustment.  The total proposed revenue change for the 2026 projected year and 2024 historical year netting adjustment is $117.7 million.   By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint.  Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase was limited to $92.3 million. Entergy Arkansas proposed a procedural schedule that includes a hearing in November 2025 and requests an APSC order in December 2025.
Grand Gulf Credit Rider

As discussed in the Form 10-K, in June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “Complaints Against System Energy - System Energy Settlement with the APSC” in Note 2 to the financial statements in the Form 10-K for discussion of the System Energy settlement with the APSC. In July 2024 the APSC approved the tariff, under which Entergy Arkansas would refund to retail customers a total of $100.6 million. Entergy Arkansas refunded $92.3 million of the total through one-time bill credits under the Grand Gulf credit rider during the August 2024 billing cycle. In March 2025, Entergy Arkansas included the remaining balance as a credit to retail customers in its energy cost recovery rider rate redetermination filing. See further discussion within "Regulatory Assets and Regulatory Liabilities - Fuel and purchased power cost recovery - Entergy Arkansas - Energy Cost Recovery Rider" above. In April 2025 the APSC approved Entergy Arkansas’s proposal to include the remaining balance in its energy cost recovery rider effective with the first billing cycle of April 2025 and the withdrawal of the Grand Gulf credit rider after all credits had been issued. Credits to retail customers were completed in second quarter 2025, and the Grand Gulf credit rider was subsequently withdrawn.

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2023 Formula Rate Plan Filing

As discussed in the Form 10-K, in August 2024, pursuant to the global stipulated settlement agreement approved by the LPSC also in August 2024, Entergy Louisiana filed its formula rate plan evaluation report for its 2023 calendar year operations. Consistent with the global stipulated settlement agreement, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the midpoint. For the 2023 test year, however, the bandwidth provisions of the formula rate plan were temporarily suspended and, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana implemented the September 2024 formula rate plan rate adjustments effective with the first billing cycle of September 2024. In January 2025, Entergy Louisiana and the LPSC filed a joint report indicating that no disputed issues remained in the proceeding and requesting that the LPSC issue an order accepting Entergy Louisiana’s evaluation report and, ultimately, resolving this matter. In March 2025 the LPSC issued an order accepting the evaluation report.

In December 2024, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed an interim rate adjustment for the 2023 test year reflecting the return of $25.1 million of refunds from the System Energy settlement with the LPSC to customers from January through August 2025. In February 2025, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting the divestiture of Entergy Louisiana’s share of Grand Gulf capacity and energy, which was effective as of January 1, 2025. The second interim rate adjustment also reflected a revenue increase of $17.8 million for the recovery of Hurricane Francine costs as approved by the LPSC (on an interim basis). The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the Hurricane Francine proceeding in “Storm Cost Recovery Filings with Retail Regulators – Entergy Louisiana – Hurricane Francine” below. See Note 8 to the financial statements in the Form 10-K for discussion of Entergy Louisiana’s divestiture from the Unit Power Sales Agreement.

2024 Formula Rate Plan Filing

In May 2025, Entergy Louisiana filed its formula rate plan evaluation report for its 2024 calendar year operations. Consistent with the global stipulated settlement agreement approved by the LPSC in August 2024, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the
midpoint. For the test year 2024, however, any earnings above the allowed return on common equity are to be returned to customers through a credit, pursuant to the terms of the global stipulated settlement agreement. The 2024 test year evaluation produced an earned return on common equity of 9.98%, which is within the approved formula rate plan bandwidth, but above the allowed return on common equity, resulting in a customer credit of $31.9 million to be returned to customers during September and October 2025.

Other changes in formula rate plan revenue are driven by higher nuclear depreciation rates, additions to transmission and distribution plant in service reflected through the transmission recovery mechanism and distribution recovery mechanism, and the expiration of customer credits related to the LPSC’s order, offset by increased customer credits resulting from an increase in net MISO revenues reflected through the MISO cost recovery mechanism and the reduction in the Louisiana corporate income tax rate effective January 1, 2025, reflected through the tax adjustment mechanism, as discussed below. Excluding the customer credit for earnings above the authorized return on common equity discussed above, the net result of these changes on an annualized basis is a $2 million increase in formula rate plan revenue.

As noted above, the 2024 evaluation report included the effects of the change in Louisiana state tax law that reduced the corporate income tax rate to a flat 5.5% (from the then-current highest marginal rate of 7.5%) effective January 1, 2025. As such, the 2024 evaluation report reflected the calculation of current and deferred income tax expenses as well as the revaluation of accumulated deferred income taxes based on the income tax laws currently in effect. The 2024 evaluation report proposes that the rate effects associated with the revaluation of accumulated deferred income taxes, including the collection of any net accumulated deferred income tax deficiency and any related effects on rate base, should be reflected in the tax adjustment mechanism consistent with the treatment of similar Tax Cuts and Jobs Act and prior state tax change-related impacts. The effects of the change in tax law on Entergy Louisiana’s authorized return on rate base are also reflected in the 2024 evaluation report consistent with the treatment cited above, including a credit in the extraordinary cost change mechanism for the prospective change in Entergy Louisiana’s authorized return and a credit within the tax adjustment mechanism for over-collection of income tax expense through August 2025.

Additional Generation and Transmission Resources

As discussed in the Form 10-K, in October 2024, Entergy Louisiana filed an application with the LPSC seeking approval of a variety of generation and transmission resources proposed in connection with establishing service to a new data center to be developed by a subsidiary of Meta Platforms, Inc. in north Louisiana, for which an electric service agreement has been executed. The filing requests LPSC certification of three new combined cycle combustion turbine generation resources totaling 2,262 MW, each of which will be enabled for future carbon capture and storage, a new 500 kV transmission line, and 500 kV substation upgrades. The application also requests approval to implement a corporate sustainability rider applicable to the new customer. The corporate sustainability rider contemplates the new customer contributing to the costs of the future addition of 1,500 MW of new solar and energy storage resources, agreements involving carbon capture and storage at Entergy Louisiana’s existing Lake Charles Power Station, and potential future wind and nuclear resources. Entergy Louisiana anticipates funding the incremental cost to serve the customer through direct financial contributions from the customer and the revenues it expects to earn under the electric service agreement. The electric service agreement also contains provisions for termination payments that will help ensure that there is no harm to Entergy Louisiana and its customers in the event of early termination. A directive was issued at the LPSC’s November 2024 meeting for the matter to be decided by October 2025. In February 2025 intervenors filed a motion asking the LPSC to deny Entergy Louisiana’s requested exemption from the LPSC’s order addressing competitive solicitation procedures and further asking the LPSC to dismiss the application. The ALJ issued an order denying the motion to dismiss the application and deferring the LPSC’s consideration of the motion regarding the competitive solicitation procedures until the hearing. In March 2025 the same intervenors filed a motion requesting the LPSC to require the customer and its parent company to be joined as parties to the proceeding or dismiss the application. In April 2025 the ALJ issued an order denying the March 2025 motion, and the moving parties filed a motion asking the LPSC to review and reverse the ALJ’s decision.
In February 2025, Entergy Louisiana filed supplemental testimony with the LPSC stating that the third combined cycle combustion turbine resource presented in the October 2024 application would be sited at Entergy Louisiana’s Waterford site in Killona, Louisiana, alongside existing Entergy Louisiana generation resources. The testimony also notes that Entergy Louisiana is negotiating with the customer in response to the customer’s request to increase the load associated with its project in north Louisiana. The testimony indicates further that the additional load can be served without additional generation capacity beyond what was presented in the October 2024 application, but that additional transmission facilities, which will be funded directly by the customer, are needed to serve this additional load.

In April 2025 and May 2025 the LPSC staff and certain intervenors each filed their direct testimony and cross-answering testimony, respectively. The LPSC staff’s testimony discussed the significant projected benefits associated with the data center project; however, both the LPSC staff and such intervenors also identified purported risks associated with constructing the requested resources based on the terms and conditions under which the customer would be taking service. Both the LPSC staff and such intervenors also recommended that the LPSC impose certain conditions on its approval which, if adopted, would support approval of Entergy Louisiana’s application. The LPSC staff’s recommendations included a condition that would require, under specified circumstances, certain sharing of net revenues from service to the project with Entergy Louisiana’s other customers. The LPSC staff also recommended that the LPSC deny approval of the corporate sustainability rider terms providing for the customer to supply funding toward the cost of installing carbon capture and storage infrastructure at Entergy Louisiana’s Lake Charles Power Station. The Louisiana Energy Users Group and other intervenors recommended that the LPSC require various changes to the terms of the electric service agreement with the customer that would shift additional risk and cost to the customer rather than Entergy Louisiana’s broader customer base. Certain intervenors also challenged approval on the basis that Entergy Louisiana did not conduct a request for proposals to procure the proposed generation resources to serve the customer’s project; these intervenors also advocated that Entergy Louisiana be required to procure more renewable generation and evaluate transmission alternatives rather than proceeding with development of all of the proposed new generation resources. In May 2025, Entergy Louisiana filed its rebuttal testimony responding to the direct and cross-answering testimony of the LPSC staff and intervenors. The rebuttal testimony expressed support for or no opposition to the LPSC’s adoption of certain of the proposed recommendations and identified why other proposed recommendations should not be adopted. In addition, the rebuttal testimony stated that the negotiations related to the increase in the load amount for the customer’s project had concluded and that a rider to the electric service agreement reflecting this increase had been executed. In advance of the July 2025 hearing, Entergy Louisiana reached a settlement agreement with the LPSC staff and three separate intervenors. The hearing concluded and the matter is currently under consideration by the ALJ.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In April 2023, Entergy Louisiana filed an application proposing to utilize approximately $1.6 billion in certain low interest debt to generate earnings to apply toward the reduction of the COVID-19 regulatory asset, as well as to conduct additional outside right-of-way vegetation management activities and fund the minor storm reserve account. In that filing, Entergy Louisiana proposed to delay repayment of certain shorter-term first mortgage bonds that were issued to finance storm restoration costs until the costs could be securitized, and to invest the funds that otherwise would be used to repay those bonds in the money pool to take advantage of the spread between prevailing interest rates on investments in the money pool and the interest rates on the bonds. The LPSC approved Entergy Louisiana’s requested relief in June 2023. In November 2024, Entergy Louisiana submitted a filing to the LPSC requesting that the LPSC review Entergy Louisiana’s computation of the COVID-19 regulatory asset as well as Entergy Louisiana’s proposal to offset the regulatory asset against the net interest earned on the short-term debt funds, resulting in no increased costs to customers. At the time of the filing, Entergy Louisiana had a regulatory asset of $47.8 million for costs associated
with the COVID-19 pandemic. As of June 30, 2025, Entergy Louisiana had a regulatory liability of $48.9 million for the deferred earnings related to the approximately $1.6 billion in low interest debt, which had been fully repaid by August 2024. In granting Entergy Louisiana’s requested relief in June 2023, the LPSC ordered that any amount of earnings exceeding the amount of the COVID-19 regulatory asset be transferred to Entergy Louisiana’s storm reserve escrow account. In May 2025 the LPSC staff filed direct testimony finding that Entergy Louisiana had complied with the relevant orders and recommending approval of the requested treatment. In June 2025, Entergy Louisiana and the LPSC staff filed a joint motion requesting a hearing for the admission of an uncontested stipulated settlement agreement in the matter. A settlement hearing took place in July 2025 and Entergy Louisiana expects the settlement to be considered at an upcoming meeting of the LPSC. The settlement terms provide for LPSC approval of Entergy Louisiana’s calculation of the COVID-19 regulatory assets and Entergy Louisiana’s proposal to offset the regulatory asset as described above and as proposed in Entergy Louisiana’s November 2024 filing.

Filings with the MPSC (Entergy Mississippi)

Retail Rates

2025 Formula Rate Plan Filing

In February 2025, Entergy Mississippi submitted its formula rate plan 2025 test year filing and 2024 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2024 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2025 calendar year also to be within the formula rate plan bandwidth. The 2025 test year filing showed an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2024 look-back filing compared actual 2024 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues, although Entergy Mississippi proposed to adjust interim rates by $135 thousand to reflect two outside-the-bandwidth changes: (1) the completion of Entergy Mississippi’s return to customers of credits under its restructuring credit rider; and (2) a true-up of demand side management costs.

In June 2025, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2025 test year filing, with the exception of immaterial adjustments to certain operation and maintenance expenses. The formula rate plan reflected an earned return on rate base of 7.68% for calendar year 2025, resulting in no change in formula rate plan revenues for 2025. Pursuant to the stipulation, Entergy Mississippi’s 2024 look-back filing reflected an earned return on rate base of 7.55%, which also resulted in no change in formula rate plan revenues for 2024. In addition, the stipulation included the recovery of the two outside-the-bandwidth changes discussed above as well as the ratemaking treatment of customer contributions (deferred revenue and prepaid contributions in aid of construction). In June 2025 the MPSC approved the joint stipulation with rates effective in July 2025.

Interim Facilities Rate Adjustments

In May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with state legislation passed in January 2024. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed the first of its annual interim facilities rate adjustment reports in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Entergy Mississippi filed its second interim facilities rate adjustment report in November 2024 to recover approximately $46.7 million of these costs over a 12-month period with rates effective beginning in January 2025. In February 2025, Entergy Mississippi filed a true-up interim facilities rate adjustment report to the initial annual interim facilities rate adjustment report filed in May 2024, reflecting the recovery of an
additional approximately $1.0 million of costs over a 12-month period with rates effective with the first billing cycle of April 2025.

Filings with the City Council (Entergy New Orleans)

Retail Rates

2025 Formula Rate Plan Filing

In April 2025, Entergy New Orleans submitted to the City Council its formula rate plan 2024 test year filing. The 2024 evaluation report produced an electric earned return on equity of 10.98% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in a decrease in electric rates of $13.8 million. The decrease in electric rates is driven by the realignment of regulatory liabilities into the formula from a separate rate mechanism, partially offset by the cost of known and measurable electric capital additions. The filing also commences the previously authorized recovery of certain regulatory costs and requests a revenue-neutral recovery to offset a proposed reduction in bill payment late fees. Taking into account these proposed adjustments, the filing presents a decrease in authorized electric revenues of $8.6 million. The City Council’s advisors issued their report in July 2025 seeking a reduction in Entergy New Orleans’s requested electric formula rate plan revenues of approximately $7.2 million due to certain proposed cost realignments and disallowances, of which $4.1 million is associated with Entergy New Orleans’s proposed implementation, on a revenue neutral basis, of a proposed reduction in customer late fees. The City Council’s advisors also proposed rate mitigation in the amount of $4.4 million through offsets to the formula rate plan funded by certain regulatory liabilities. The City Council’s advisors’ report began a 35-day period to resolve any disputes among the parties regarding the formula rate plan. For any disputed rate adjustments, the City Council would set a procedural schedule to resolve. Resulting rates will be effective with the first billing cycle of September 2025 pursuant to the formula rate plan tariff.

Filings with the PUCT and Texas Cities (Entergy Texas)

Retail Rates

Distribution Cost Recovery Factor (DCRF) Rider

In April 2025, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $77.8 million annually, or $29.3 million in incremental annual revenues beyond Entergy Texas’s then-effective DCRF rider based on its capital invested in distribution between July 1, 2024 and December 31, 2024, including distribution-related restoration costs associated with Hurricane Beryl. In June 2025 the PUCT approved the DCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective on June 25, 2025.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2024, Entergy Texas filed with the PUCT a request to amend its TCRF rider, which was previously reset to zero in June 2023 as a result of the 2022 base rate case. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $9.7 million annually based on its capital invested in transmission between January 1, 2022 and June 30, 2024 and changes in other transmission charges. In April 2025 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 7, 2025.

Entergy Arkansas Opportunity Sales Proceeding

As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments
to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023.

In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth Circuit and the court granted the motion to expedite. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. In December 2024 the United States Court of Appeals for the Eighth Circuit affirmed the decision of the U.S. District Court for the Eastern District of Arkansas, and Entergy Arkansas filed a petition for rehearing en banc. In January 2025 the United States Court of Appeals for the Eighth Circuit denied Entergy Arkansas’s petition. In April 2025, Entergy Arkansas filed a petition for certiorari with the United States Supreme Court. In June 2025 the United States Supreme Court denied Entergy Arkansas’s petition for certiorari.

MSS-4 Replacement Tariff - Net Operating Loss Carryforward Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the MSS-4 replacement tariff net operating loss carryforward proceeding.

The MSS-4 replacement tariff, a tariff governing the sales of energy and capacity among the Utility operating companies, includes protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In April 2025, pursuant to such protocols, the City Council filed with the FERC a formal challenge relating to Entergy Services’ inclusion and allocation of net operating loss carryforward accumulated deferred income taxes in the MSS-4 replacement tariff rates charged to Entergy New Orleans’s monthly bills for calendar year 2023. In May 2025, Entergy Services filed a response to the formal challenge and is awaiting a response from the FERC.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. The following are updates to that discussion.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in February 2023, System Energy submitted a tariff compliance filing with the FERC to clarify that, consistent with the releases provided in the June 2022 MPSC settlement, Entergy Mississippi would continue to be charged for its allocation of the sale-leaseback renewal costs under the Unit Power Sales Agreement. In March 2023 the MPSC filed a protest to System Energy’s tariff compliance filing. The MPSC argued that the settlement did not specifically address post-settlement sale-leaseback renewal costs and that the sale-leaseback renewal costs may not be recovered under the Unit Power Sales Agreement. In February 2025, System Energy and the MPSC resolved their dispute concerning the sale-leaseback renewal costs. As a result, the MPSC withdrew its protest at the FERC on System Energy’s tariff compliance filing. Entergy Mississippi will continue to pay the allocated sale-leaseback renewal costs of approximately $5.7 million annually and there are no refunds due for prior periods. In March 2025, System Energy filed a status report with the FERC explaining that the dispute is resolved. In April 2025 the FERC accepted System Energy’s tariff compliance filing.
System Energy Settlement with the LPSC

As discussed in the Form 10-K, in 2024, System Energy reached a settlement with the LPSC to globally resolve all of the LPSC’s actual and potential claims in multiple docketed proceedings pending before the FERC (including all docketed proceedings resolved by the MPSC, the APSC, and the City Council settlements) and associated with System Energy’s past implementation of the Unit Power Sales Agreement. In compliance with the settlement, in May 2025, System Energy, Entergy Louisiana, and Entergy Mississippi submitted the following filings with the FERC: (1) a Federal Power Act Section 203 application seeking approval for the permanent divestiture by Entergy Louisiana to Entergy Mississippi of its rights to capacity and energy from Grand Gulf; and (2) a Federal Power Act Section 205 application seeking approval to modify the entitlement percentages of the remaining purchasers under the Unit Power Sales Agreement in connection with the foregoing divestiture. In July 2025, the FERC issued an order accepting the Federal Power Act Section 205 application to remove Entergy Louisiana as a party to the Unit Power Sales Agreement. As a result of the order, the Unit Power Sales Agreement entitlement percentages of the remaining purchasers will be permanently modified to exclude Entergy Louisiana, to be effective beginning October 2025. The FERC also issued an order dismissing the Federal Power Act Section 203 application based on lack of jurisdiction.

Storm Cost Recovery Filings with Retail Regulators

See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following is an update to that discussion.

Entergy Louisiana

Hurricane Francine

In September 2024, Hurricane Francine caused damage to the areas served by Entergy Louisiana. The storm resulted in widespread power outages, primarily due to damage to distribution infrastructure as a result of strong winds and heavy rain, and the loss of sales during the power outages.

In December 2024, and subsequently amended in an errata filed in February 2025, Entergy Louisiana submitted an application to the LPSC seeking a determination that approximately $183.6 million in storm restoration costs associated with Hurricane Francine were reasonable and necessary and, therefore, eligible for recovery from customers, as well as approval to recover approximately $3.6 million in certain carrying costs from customers. In February 2025, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting a revenue increase of $17.8 million from funds approved by the LPSC (on an interim basis) for Hurricane Francine recovery costs. The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the 2023 formula rate plan filing above. Also in February 2025, Entergy Louisiana withdrew $33.5 million from its funded storm reserves. In June 2025 the LPSC staff filed direct testimony. The LPSC staff recommends approval of Entergy Louisiana’s as-requested storm restoration costs with the exception of approximately $10.6 million, comprised primarily of estimates of mutual assistance invoices that have not yet been received at the time of filing and that ultimately exceeded the actual amounts invoiced, as well as certain incentive compensation, and $1.8 million associated with certain carrying costs. Entergy Louisiana’s rebuttal testimony is due in August 2025 and a hearing is scheduled for November 2025.
Entergy Mississippi [Member]  
Public Utilities Disclosure [Text Block] RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Regulatory Assets and Regulatory Liabilities

See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

In March 2025, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.00882 per kWh to $0.01333 per kWh. The annual redetermination included a credit related to the remaining balance due to retail customers from the System Energy settlement with the APSC, plus carrying charges and interest. See “Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - Grand Gulf Credit Rider” below for further discussion. The primary reason for the rate increase is an adjustment to account for projected increases in natural gas prices in 2025. This adjustment is expected to reduce the rate change that will be reflected in its 2026 energy cost rate redetermination. The redetermined rate of $0.01333 per kWh became effective with the first billing cycle in April 2025 through the normal operation of the tariff.
Entergy Louisiana

As discussed in the Form 10-K, in January 2023 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2021 through 2022. In April 2025 the LPSC staff issued its audit report (for Entergy Louisiana’s gas operations), which included several prospective recommendations but no financial disallowances. The LPSC accepted the report in June 2025.

Entergy Texas

As discussed in the Form 10-K, in September 2024, Entergy Texas filed an application with the PUCT to reconcile its fuel and purchased power costs for the period from April 2022 through March 2024. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in eligible fuel and purchased power expenses to generate and purchase electricity to serve its customers, net of certain revenues credited to such expenses and other adjustments. Entergy Texas’s cumulative under-recovery balance for the reconciliation period was approximately $30 million, including interest, which Entergy Texas requested authority to carry over as part of the cumulative fuel balance for the subsequent reconciliation period beginning April 2024. In November 2024 the PUCT referred the proceeding to the State Office of Administrative Hearings. In March 2025, Texas Industrial Energy Consumers, an intervenor, filed testimony regarding the recovery of capacity costs for a certain power purchase agreement, arguing the capacity costs should be imputed and treated as non-reconcilable fuel expense, recovered in Entergy Texas’s base rates. In April 2025 the PUCT staff filed testimony and later in April 2025, Entergy Texas filed rebuttal testimony. In May 2025, Entergy Texas filed, and the ALJ with the State Office of Administrative Hearings granted, a request for a paper hearing and to cancel the oral hearing on the merits previously scheduled for later in May 2025. In June 2025, Entergy Texas filed, and the ALJ with the State Office of Administrative Hearings granted, a joint motion to abate the proceeding to give the parties to the proceeding additional time to finalize a settlement.

Retail Rate Proceedings

See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion.

Filings with the APSC (Entergy Arkansas)

Retail Rates

2025 Formula Rate Plan Filing

In July 2025, Entergy Arkansas filed with the APSC its 2025 formula rate plan filing to set its formula rate for the 2026 calendar year.  The filing contained an evaluation of Entergy Arkansas’s earnings for the 2026 projected year and a netting adjustment for the 2024 historical year.  The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2026 projected year was 8.45% resulting in a revenue deficiency of $68.9 million.  The earned rate of return on common equity for the 2024 historical year was 7.71% resulting in a $48.8 million netting adjustment.  The total proposed revenue change for the 2026 projected year and 2024 historical year netting adjustment is $117.7 million.   By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint.  Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase was limited to $92.3 million. Entergy Arkansas proposed a procedural schedule that includes a hearing in November 2025 and requests an APSC order in December 2025.
Grand Gulf Credit Rider

As discussed in the Form 10-K, in June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “Complaints Against System Energy - System Energy Settlement with the APSC” in Note 2 to the financial statements in the Form 10-K for discussion of the System Energy settlement with the APSC. In July 2024 the APSC approved the tariff, under which Entergy Arkansas would refund to retail customers a total of $100.6 million. Entergy Arkansas refunded $92.3 million of the total through one-time bill credits under the Grand Gulf credit rider during the August 2024 billing cycle. In March 2025, Entergy Arkansas included the remaining balance as a credit to retail customers in its energy cost recovery rider rate redetermination filing. See further discussion within "Regulatory Assets and Regulatory Liabilities - Fuel and purchased power cost recovery - Entergy Arkansas - Energy Cost Recovery Rider" above. In April 2025 the APSC approved Entergy Arkansas’s proposal to include the remaining balance in its energy cost recovery rider effective with the first billing cycle of April 2025 and the withdrawal of the Grand Gulf credit rider after all credits had been issued. Credits to retail customers were completed in second quarter 2025, and the Grand Gulf credit rider was subsequently withdrawn.

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2023 Formula Rate Plan Filing

As discussed in the Form 10-K, in August 2024, pursuant to the global stipulated settlement agreement approved by the LPSC also in August 2024, Entergy Louisiana filed its formula rate plan evaluation report for its 2023 calendar year operations. Consistent with the global stipulated settlement agreement, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the midpoint. For the 2023 test year, however, the bandwidth provisions of the formula rate plan were temporarily suspended and, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana implemented the September 2024 formula rate plan rate adjustments effective with the first billing cycle of September 2024. In January 2025, Entergy Louisiana and the LPSC filed a joint report indicating that no disputed issues remained in the proceeding and requesting that the LPSC issue an order accepting Entergy Louisiana’s evaluation report and, ultimately, resolving this matter. In March 2025 the LPSC issued an order accepting the evaluation report.

In December 2024, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed an interim rate adjustment for the 2023 test year reflecting the return of $25.1 million of refunds from the System Energy settlement with the LPSC to customers from January through August 2025. In February 2025, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting the divestiture of Entergy Louisiana’s share of Grand Gulf capacity and energy, which was effective as of January 1, 2025. The second interim rate adjustment also reflected a revenue increase of $17.8 million for the recovery of Hurricane Francine costs as approved by the LPSC (on an interim basis). The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the Hurricane Francine proceeding in “Storm Cost Recovery Filings with Retail Regulators – Entergy Louisiana – Hurricane Francine” below. See Note 8 to the financial statements in the Form 10-K for discussion of Entergy Louisiana’s divestiture from the Unit Power Sales Agreement.

2024 Formula Rate Plan Filing

In May 2025, Entergy Louisiana filed its formula rate plan evaluation report for its 2024 calendar year operations. Consistent with the global stipulated settlement agreement approved by the LPSC in August 2024, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the
midpoint. For the test year 2024, however, any earnings above the allowed return on common equity are to be returned to customers through a credit, pursuant to the terms of the global stipulated settlement agreement. The 2024 test year evaluation produced an earned return on common equity of 9.98%, which is within the approved formula rate plan bandwidth, but above the allowed return on common equity, resulting in a customer credit of $31.9 million to be returned to customers during September and October 2025.

Other changes in formula rate plan revenue are driven by higher nuclear depreciation rates, additions to transmission and distribution plant in service reflected through the transmission recovery mechanism and distribution recovery mechanism, and the expiration of customer credits related to the LPSC’s order, offset by increased customer credits resulting from an increase in net MISO revenues reflected through the MISO cost recovery mechanism and the reduction in the Louisiana corporate income tax rate effective January 1, 2025, reflected through the tax adjustment mechanism, as discussed below. Excluding the customer credit for earnings above the authorized return on common equity discussed above, the net result of these changes on an annualized basis is a $2 million increase in formula rate plan revenue.

As noted above, the 2024 evaluation report included the effects of the change in Louisiana state tax law that reduced the corporate income tax rate to a flat 5.5% (from the then-current highest marginal rate of 7.5%) effective January 1, 2025. As such, the 2024 evaluation report reflected the calculation of current and deferred income tax expenses as well as the revaluation of accumulated deferred income taxes based on the income tax laws currently in effect. The 2024 evaluation report proposes that the rate effects associated with the revaluation of accumulated deferred income taxes, including the collection of any net accumulated deferred income tax deficiency and any related effects on rate base, should be reflected in the tax adjustment mechanism consistent with the treatment of similar Tax Cuts and Jobs Act and prior state tax change-related impacts. The effects of the change in tax law on Entergy Louisiana’s authorized return on rate base are also reflected in the 2024 evaluation report consistent with the treatment cited above, including a credit in the extraordinary cost change mechanism for the prospective change in Entergy Louisiana’s authorized return and a credit within the tax adjustment mechanism for over-collection of income tax expense through August 2025.

Additional Generation and Transmission Resources

As discussed in the Form 10-K, in October 2024, Entergy Louisiana filed an application with the LPSC seeking approval of a variety of generation and transmission resources proposed in connection with establishing service to a new data center to be developed by a subsidiary of Meta Platforms, Inc. in north Louisiana, for which an electric service agreement has been executed. The filing requests LPSC certification of three new combined cycle combustion turbine generation resources totaling 2,262 MW, each of which will be enabled for future carbon capture and storage, a new 500 kV transmission line, and 500 kV substation upgrades. The application also requests approval to implement a corporate sustainability rider applicable to the new customer. The corporate sustainability rider contemplates the new customer contributing to the costs of the future addition of 1,500 MW of new solar and energy storage resources, agreements involving carbon capture and storage at Entergy Louisiana’s existing Lake Charles Power Station, and potential future wind and nuclear resources. Entergy Louisiana anticipates funding the incremental cost to serve the customer through direct financial contributions from the customer and the revenues it expects to earn under the electric service agreement. The electric service agreement also contains provisions for termination payments that will help ensure that there is no harm to Entergy Louisiana and its customers in the event of early termination. A directive was issued at the LPSC’s November 2024 meeting for the matter to be decided by October 2025. In February 2025 intervenors filed a motion asking the LPSC to deny Entergy Louisiana’s requested exemption from the LPSC’s order addressing competitive solicitation procedures and further asking the LPSC to dismiss the application. The ALJ issued an order denying the motion to dismiss the application and deferring the LPSC’s consideration of the motion regarding the competitive solicitation procedures until the hearing. In March 2025 the same intervenors filed a motion requesting the LPSC to require the customer and its parent company to be joined as parties to the proceeding or dismiss the application. In April 2025 the ALJ issued an order denying the March 2025 motion, and the moving parties filed a motion asking the LPSC to review and reverse the ALJ’s decision.
In February 2025, Entergy Louisiana filed supplemental testimony with the LPSC stating that the third combined cycle combustion turbine resource presented in the October 2024 application would be sited at Entergy Louisiana’s Waterford site in Killona, Louisiana, alongside existing Entergy Louisiana generation resources. The testimony also notes that Entergy Louisiana is negotiating with the customer in response to the customer’s request to increase the load associated with its project in north Louisiana. The testimony indicates further that the additional load can be served without additional generation capacity beyond what was presented in the October 2024 application, but that additional transmission facilities, which will be funded directly by the customer, are needed to serve this additional load.

In April 2025 and May 2025 the LPSC staff and certain intervenors each filed their direct testimony and cross-answering testimony, respectively. The LPSC staff’s testimony discussed the significant projected benefits associated with the data center project; however, both the LPSC staff and such intervenors also identified purported risks associated with constructing the requested resources based on the terms and conditions under which the customer would be taking service. Both the LPSC staff and such intervenors also recommended that the LPSC impose certain conditions on its approval which, if adopted, would support approval of Entergy Louisiana’s application. The LPSC staff’s recommendations included a condition that would require, under specified circumstances, certain sharing of net revenues from service to the project with Entergy Louisiana’s other customers. The LPSC staff also recommended that the LPSC deny approval of the corporate sustainability rider terms providing for the customer to supply funding toward the cost of installing carbon capture and storage infrastructure at Entergy Louisiana’s Lake Charles Power Station. The Louisiana Energy Users Group and other intervenors recommended that the LPSC require various changes to the terms of the electric service agreement with the customer that would shift additional risk and cost to the customer rather than Entergy Louisiana’s broader customer base. Certain intervenors also challenged approval on the basis that Entergy Louisiana did not conduct a request for proposals to procure the proposed generation resources to serve the customer’s project; these intervenors also advocated that Entergy Louisiana be required to procure more renewable generation and evaluate transmission alternatives rather than proceeding with development of all of the proposed new generation resources. In May 2025, Entergy Louisiana filed its rebuttal testimony responding to the direct and cross-answering testimony of the LPSC staff and intervenors. The rebuttal testimony expressed support for or no opposition to the LPSC’s adoption of certain of the proposed recommendations and identified why other proposed recommendations should not be adopted. In addition, the rebuttal testimony stated that the negotiations related to the increase in the load amount for the customer’s project had concluded and that a rider to the electric service agreement reflecting this increase had been executed. In advance of the July 2025 hearing, Entergy Louisiana reached a settlement agreement with the LPSC staff and three separate intervenors. The hearing concluded and the matter is currently under consideration by the ALJ.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In April 2023, Entergy Louisiana filed an application proposing to utilize approximately $1.6 billion in certain low interest debt to generate earnings to apply toward the reduction of the COVID-19 regulatory asset, as well as to conduct additional outside right-of-way vegetation management activities and fund the minor storm reserve account. In that filing, Entergy Louisiana proposed to delay repayment of certain shorter-term first mortgage bonds that were issued to finance storm restoration costs until the costs could be securitized, and to invest the funds that otherwise would be used to repay those bonds in the money pool to take advantage of the spread between prevailing interest rates on investments in the money pool and the interest rates on the bonds. The LPSC approved Entergy Louisiana’s requested relief in June 2023. In November 2024, Entergy Louisiana submitted a filing to the LPSC requesting that the LPSC review Entergy Louisiana’s computation of the COVID-19 regulatory asset as well as Entergy Louisiana’s proposal to offset the regulatory asset against the net interest earned on the short-term debt funds, resulting in no increased costs to customers. At the time of the filing, Entergy Louisiana had a regulatory asset of $47.8 million for costs associated
with the COVID-19 pandemic. As of June 30, 2025, Entergy Louisiana had a regulatory liability of $48.9 million for the deferred earnings related to the approximately $1.6 billion in low interest debt, which had been fully repaid by August 2024. In granting Entergy Louisiana’s requested relief in June 2023, the LPSC ordered that any amount of earnings exceeding the amount of the COVID-19 regulatory asset be transferred to Entergy Louisiana’s storm reserve escrow account. In May 2025 the LPSC staff filed direct testimony finding that Entergy Louisiana had complied with the relevant orders and recommending approval of the requested treatment. In June 2025, Entergy Louisiana and the LPSC staff filed a joint motion requesting a hearing for the admission of an uncontested stipulated settlement agreement in the matter. A settlement hearing took place in July 2025 and Entergy Louisiana expects the settlement to be considered at an upcoming meeting of the LPSC. The settlement terms provide for LPSC approval of Entergy Louisiana’s calculation of the COVID-19 regulatory assets and Entergy Louisiana’s proposal to offset the regulatory asset as described above and as proposed in Entergy Louisiana’s November 2024 filing.

Filings with the MPSC (Entergy Mississippi)

Retail Rates

2025 Formula Rate Plan Filing

In February 2025, Entergy Mississippi submitted its formula rate plan 2025 test year filing and 2024 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2024 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2025 calendar year also to be within the formula rate plan bandwidth. The 2025 test year filing showed an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2024 look-back filing compared actual 2024 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues, although Entergy Mississippi proposed to adjust interim rates by $135 thousand to reflect two outside-the-bandwidth changes: (1) the completion of Entergy Mississippi’s return to customers of credits under its restructuring credit rider; and (2) a true-up of demand side management costs.

In June 2025, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2025 test year filing, with the exception of immaterial adjustments to certain operation and maintenance expenses. The formula rate plan reflected an earned return on rate base of 7.68% for calendar year 2025, resulting in no change in formula rate plan revenues for 2025. Pursuant to the stipulation, Entergy Mississippi’s 2024 look-back filing reflected an earned return on rate base of 7.55%, which also resulted in no change in formula rate plan revenues for 2024. In addition, the stipulation included the recovery of the two outside-the-bandwidth changes discussed above as well as the ratemaking treatment of customer contributions (deferred revenue and prepaid contributions in aid of construction). In June 2025 the MPSC approved the joint stipulation with rates effective in July 2025.

Interim Facilities Rate Adjustments

In May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with state legislation passed in January 2024. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed the first of its annual interim facilities rate adjustment reports in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Entergy Mississippi filed its second interim facilities rate adjustment report in November 2024 to recover approximately $46.7 million of these costs over a 12-month period with rates effective beginning in January 2025. In February 2025, Entergy Mississippi filed a true-up interim facilities rate adjustment report to the initial annual interim facilities rate adjustment report filed in May 2024, reflecting the recovery of an
additional approximately $1.0 million of costs over a 12-month period with rates effective with the first billing cycle of April 2025.

Filings with the City Council (Entergy New Orleans)

Retail Rates

2025 Formula Rate Plan Filing

In April 2025, Entergy New Orleans submitted to the City Council its formula rate plan 2024 test year filing. The 2024 evaluation report produced an electric earned return on equity of 10.98% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in a decrease in electric rates of $13.8 million. The decrease in electric rates is driven by the realignment of regulatory liabilities into the formula from a separate rate mechanism, partially offset by the cost of known and measurable electric capital additions. The filing also commences the previously authorized recovery of certain regulatory costs and requests a revenue-neutral recovery to offset a proposed reduction in bill payment late fees. Taking into account these proposed adjustments, the filing presents a decrease in authorized electric revenues of $8.6 million. The City Council’s advisors issued their report in July 2025 seeking a reduction in Entergy New Orleans’s requested electric formula rate plan revenues of approximately $7.2 million due to certain proposed cost realignments and disallowances, of which $4.1 million is associated with Entergy New Orleans’s proposed implementation, on a revenue neutral basis, of a proposed reduction in customer late fees. The City Council’s advisors also proposed rate mitigation in the amount of $4.4 million through offsets to the formula rate plan funded by certain regulatory liabilities. The City Council’s advisors’ report began a 35-day period to resolve any disputes among the parties regarding the formula rate plan. For any disputed rate adjustments, the City Council would set a procedural schedule to resolve. Resulting rates will be effective with the first billing cycle of September 2025 pursuant to the formula rate plan tariff.

Filings with the PUCT and Texas Cities (Entergy Texas)

Retail Rates

Distribution Cost Recovery Factor (DCRF) Rider

In April 2025, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $77.8 million annually, or $29.3 million in incremental annual revenues beyond Entergy Texas’s then-effective DCRF rider based on its capital invested in distribution between July 1, 2024 and December 31, 2024, including distribution-related restoration costs associated with Hurricane Beryl. In June 2025 the PUCT approved the DCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective on June 25, 2025.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2024, Entergy Texas filed with the PUCT a request to amend its TCRF rider, which was previously reset to zero in June 2023 as a result of the 2022 base rate case. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $9.7 million annually based on its capital invested in transmission between January 1, 2022 and June 30, 2024 and changes in other transmission charges. In April 2025 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 7, 2025.

Entergy Arkansas Opportunity Sales Proceeding

As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments
to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023.

In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth Circuit and the court granted the motion to expedite. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. In December 2024 the United States Court of Appeals for the Eighth Circuit affirmed the decision of the U.S. District Court for the Eastern District of Arkansas, and Entergy Arkansas filed a petition for rehearing en banc. In January 2025 the United States Court of Appeals for the Eighth Circuit denied Entergy Arkansas’s petition. In April 2025, Entergy Arkansas filed a petition for certiorari with the United States Supreme Court. In June 2025 the United States Supreme Court denied Entergy Arkansas’s petition for certiorari.

MSS-4 Replacement Tariff - Net Operating Loss Carryforward Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the MSS-4 replacement tariff net operating loss carryforward proceeding.

The MSS-4 replacement tariff, a tariff governing the sales of energy and capacity among the Utility operating companies, includes protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In April 2025, pursuant to such protocols, the City Council filed with the FERC a formal challenge relating to Entergy Services’ inclusion and allocation of net operating loss carryforward accumulated deferred income taxes in the MSS-4 replacement tariff rates charged to Entergy New Orleans’s monthly bills for calendar year 2023. In May 2025, Entergy Services filed a response to the formal challenge and is awaiting a response from the FERC.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. The following are updates to that discussion.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in February 2023, System Energy submitted a tariff compliance filing with the FERC to clarify that, consistent with the releases provided in the June 2022 MPSC settlement, Entergy Mississippi would continue to be charged for its allocation of the sale-leaseback renewal costs under the Unit Power Sales Agreement. In March 2023 the MPSC filed a protest to System Energy’s tariff compliance filing. The MPSC argued that the settlement did not specifically address post-settlement sale-leaseback renewal costs and that the sale-leaseback renewal costs may not be recovered under the Unit Power Sales Agreement. In February 2025, System Energy and the MPSC resolved their dispute concerning the sale-leaseback renewal costs. As a result, the MPSC withdrew its protest at the FERC on System Energy’s tariff compliance filing. Entergy Mississippi will continue to pay the allocated sale-leaseback renewal costs of approximately $5.7 million annually and there are no refunds due for prior periods. In March 2025, System Energy filed a status report with the FERC explaining that the dispute is resolved. In April 2025 the FERC accepted System Energy’s tariff compliance filing.
System Energy Settlement with the LPSC

As discussed in the Form 10-K, in 2024, System Energy reached a settlement with the LPSC to globally resolve all of the LPSC’s actual and potential claims in multiple docketed proceedings pending before the FERC (including all docketed proceedings resolved by the MPSC, the APSC, and the City Council settlements) and associated with System Energy’s past implementation of the Unit Power Sales Agreement. In compliance with the settlement, in May 2025, System Energy, Entergy Louisiana, and Entergy Mississippi submitted the following filings with the FERC: (1) a Federal Power Act Section 203 application seeking approval for the permanent divestiture by Entergy Louisiana to Entergy Mississippi of its rights to capacity and energy from Grand Gulf; and (2) a Federal Power Act Section 205 application seeking approval to modify the entitlement percentages of the remaining purchasers under the Unit Power Sales Agreement in connection with the foregoing divestiture. In July 2025, the FERC issued an order accepting the Federal Power Act Section 205 application to remove Entergy Louisiana as a party to the Unit Power Sales Agreement. As a result of the order, the Unit Power Sales Agreement entitlement percentages of the remaining purchasers will be permanently modified to exclude Entergy Louisiana, to be effective beginning October 2025. The FERC also issued an order dismissing the Federal Power Act Section 203 application based on lack of jurisdiction.

Storm Cost Recovery Filings with Retail Regulators

See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following is an update to that discussion.

Entergy Louisiana

Hurricane Francine

In September 2024, Hurricane Francine caused damage to the areas served by Entergy Louisiana. The storm resulted in widespread power outages, primarily due to damage to distribution infrastructure as a result of strong winds and heavy rain, and the loss of sales during the power outages.

In December 2024, and subsequently amended in an errata filed in February 2025, Entergy Louisiana submitted an application to the LPSC seeking a determination that approximately $183.6 million in storm restoration costs associated with Hurricane Francine were reasonable and necessary and, therefore, eligible for recovery from customers, as well as approval to recover approximately $3.6 million in certain carrying costs from customers. In February 2025, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting a revenue increase of $17.8 million from funds approved by the LPSC (on an interim basis) for Hurricane Francine recovery costs. The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the 2023 formula rate plan filing above. Also in February 2025, Entergy Louisiana withdrew $33.5 million from its funded storm reserves. In June 2025 the LPSC staff filed direct testimony. The LPSC staff recommends approval of Entergy Louisiana’s as-requested storm restoration costs with the exception of approximately $10.6 million, comprised primarily of estimates of mutual assistance invoices that have not yet been received at the time of filing and that ultimately exceeded the actual amounts invoiced, as well as certain incentive compensation, and $1.8 million associated with certain carrying costs. Entergy Louisiana’s rebuttal testimony is due in August 2025 and a hearing is scheduled for November 2025.
Entergy New Orleans [Member]  
Public Utilities Disclosure [Text Block] RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Regulatory Assets and Regulatory Liabilities

See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

In March 2025, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.00882 per kWh to $0.01333 per kWh. The annual redetermination included a credit related to the remaining balance due to retail customers from the System Energy settlement with the APSC, plus carrying charges and interest. See “Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - Grand Gulf Credit Rider” below for further discussion. The primary reason for the rate increase is an adjustment to account for projected increases in natural gas prices in 2025. This adjustment is expected to reduce the rate change that will be reflected in its 2026 energy cost rate redetermination. The redetermined rate of $0.01333 per kWh became effective with the first billing cycle in April 2025 through the normal operation of the tariff.
Entergy Louisiana

As discussed in the Form 10-K, in January 2023 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2021 through 2022. In April 2025 the LPSC staff issued its audit report (for Entergy Louisiana’s gas operations), which included several prospective recommendations but no financial disallowances. The LPSC accepted the report in June 2025.

Entergy Texas

As discussed in the Form 10-K, in September 2024, Entergy Texas filed an application with the PUCT to reconcile its fuel and purchased power costs for the period from April 2022 through March 2024. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in eligible fuel and purchased power expenses to generate and purchase electricity to serve its customers, net of certain revenues credited to such expenses and other adjustments. Entergy Texas’s cumulative under-recovery balance for the reconciliation period was approximately $30 million, including interest, which Entergy Texas requested authority to carry over as part of the cumulative fuel balance for the subsequent reconciliation period beginning April 2024. In November 2024 the PUCT referred the proceeding to the State Office of Administrative Hearings. In March 2025, Texas Industrial Energy Consumers, an intervenor, filed testimony regarding the recovery of capacity costs for a certain power purchase agreement, arguing the capacity costs should be imputed and treated as non-reconcilable fuel expense, recovered in Entergy Texas’s base rates. In April 2025 the PUCT staff filed testimony and later in April 2025, Entergy Texas filed rebuttal testimony. In May 2025, Entergy Texas filed, and the ALJ with the State Office of Administrative Hearings granted, a request for a paper hearing and to cancel the oral hearing on the merits previously scheduled for later in May 2025. In June 2025, Entergy Texas filed, and the ALJ with the State Office of Administrative Hearings granted, a joint motion to abate the proceeding to give the parties to the proceeding additional time to finalize a settlement.

Retail Rate Proceedings

See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion.

Filings with the APSC (Entergy Arkansas)

Retail Rates

2025 Formula Rate Plan Filing

In July 2025, Entergy Arkansas filed with the APSC its 2025 formula rate plan filing to set its formula rate for the 2026 calendar year.  The filing contained an evaluation of Entergy Arkansas’s earnings for the 2026 projected year and a netting adjustment for the 2024 historical year.  The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2026 projected year was 8.45% resulting in a revenue deficiency of $68.9 million.  The earned rate of return on common equity for the 2024 historical year was 7.71% resulting in a $48.8 million netting adjustment.  The total proposed revenue change for the 2026 projected year and 2024 historical year netting adjustment is $117.7 million.   By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint.  Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase was limited to $92.3 million. Entergy Arkansas proposed a procedural schedule that includes a hearing in November 2025 and requests an APSC order in December 2025.
Grand Gulf Credit Rider

As discussed in the Form 10-K, in June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “Complaints Against System Energy - System Energy Settlement with the APSC” in Note 2 to the financial statements in the Form 10-K for discussion of the System Energy settlement with the APSC. In July 2024 the APSC approved the tariff, under which Entergy Arkansas would refund to retail customers a total of $100.6 million. Entergy Arkansas refunded $92.3 million of the total through one-time bill credits under the Grand Gulf credit rider during the August 2024 billing cycle. In March 2025, Entergy Arkansas included the remaining balance as a credit to retail customers in its energy cost recovery rider rate redetermination filing. See further discussion within "Regulatory Assets and Regulatory Liabilities - Fuel and purchased power cost recovery - Entergy Arkansas - Energy Cost Recovery Rider" above. In April 2025 the APSC approved Entergy Arkansas’s proposal to include the remaining balance in its energy cost recovery rider effective with the first billing cycle of April 2025 and the withdrawal of the Grand Gulf credit rider after all credits had been issued. Credits to retail customers were completed in second quarter 2025, and the Grand Gulf credit rider was subsequently withdrawn.

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2023 Formula Rate Plan Filing

As discussed in the Form 10-K, in August 2024, pursuant to the global stipulated settlement agreement approved by the LPSC also in August 2024, Entergy Louisiana filed its formula rate plan evaluation report for its 2023 calendar year operations. Consistent with the global stipulated settlement agreement, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the midpoint. For the 2023 test year, however, the bandwidth provisions of the formula rate plan were temporarily suspended and, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana implemented the September 2024 formula rate plan rate adjustments effective with the first billing cycle of September 2024. In January 2025, Entergy Louisiana and the LPSC filed a joint report indicating that no disputed issues remained in the proceeding and requesting that the LPSC issue an order accepting Entergy Louisiana’s evaluation report and, ultimately, resolving this matter. In March 2025 the LPSC issued an order accepting the evaluation report.

In December 2024, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed an interim rate adjustment for the 2023 test year reflecting the return of $25.1 million of refunds from the System Energy settlement with the LPSC to customers from January through August 2025. In February 2025, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting the divestiture of Entergy Louisiana’s share of Grand Gulf capacity and energy, which was effective as of January 1, 2025. The second interim rate adjustment also reflected a revenue increase of $17.8 million for the recovery of Hurricane Francine costs as approved by the LPSC (on an interim basis). The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the Hurricane Francine proceeding in “Storm Cost Recovery Filings with Retail Regulators – Entergy Louisiana – Hurricane Francine” below. See Note 8 to the financial statements in the Form 10-K for discussion of Entergy Louisiana’s divestiture from the Unit Power Sales Agreement.

2024 Formula Rate Plan Filing

In May 2025, Entergy Louisiana filed its formula rate plan evaluation report for its 2024 calendar year operations. Consistent with the global stipulated settlement agreement approved by the LPSC in August 2024, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the
midpoint. For the test year 2024, however, any earnings above the allowed return on common equity are to be returned to customers through a credit, pursuant to the terms of the global stipulated settlement agreement. The 2024 test year evaluation produced an earned return on common equity of 9.98%, which is within the approved formula rate plan bandwidth, but above the allowed return on common equity, resulting in a customer credit of $31.9 million to be returned to customers during September and October 2025.

Other changes in formula rate plan revenue are driven by higher nuclear depreciation rates, additions to transmission and distribution plant in service reflected through the transmission recovery mechanism and distribution recovery mechanism, and the expiration of customer credits related to the LPSC’s order, offset by increased customer credits resulting from an increase in net MISO revenues reflected through the MISO cost recovery mechanism and the reduction in the Louisiana corporate income tax rate effective January 1, 2025, reflected through the tax adjustment mechanism, as discussed below. Excluding the customer credit for earnings above the authorized return on common equity discussed above, the net result of these changes on an annualized basis is a $2 million increase in formula rate plan revenue.

As noted above, the 2024 evaluation report included the effects of the change in Louisiana state tax law that reduced the corporate income tax rate to a flat 5.5% (from the then-current highest marginal rate of 7.5%) effective January 1, 2025. As such, the 2024 evaluation report reflected the calculation of current and deferred income tax expenses as well as the revaluation of accumulated deferred income taxes based on the income tax laws currently in effect. The 2024 evaluation report proposes that the rate effects associated with the revaluation of accumulated deferred income taxes, including the collection of any net accumulated deferred income tax deficiency and any related effects on rate base, should be reflected in the tax adjustment mechanism consistent with the treatment of similar Tax Cuts and Jobs Act and prior state tax change-related impacts. The effects of the change in tax law on Entergy Louisiana’s authorized return on rate base are also reflected in the 2024 evaluation report consistent with the treatment cited above, including a credit in the extraordinary cost change mechanism for the prospective change in Entergy Louisiana’s authorized return and a credit within the tax adjustment mechanism for over-collection of income tax expense through August 2025.

Additional Generation and Transmission Resources

As discussed in the Form 10-K, in October 2024, Entergy Louisiana filed an application with the LPSC seeking approval of a variety of generation and transmission resources proposed in connection with establishing service to a new data center to be developed by a subsidiary of Meta Platforms, Inc. in north Louisiana, for which an electric service agreement has been executed. The filing requests LPSC certification of three new combined cycle combustion turbine generation resources totaling 2,262 MW, each of which will be enabled for future carbon capture and storage, a new 500 kV transmission line, and 500 kV substation upgrades. The application also requests approval to implement a corporate sustainability rider applicable to the new customer. The corporate sustainability rider contemplates the new customer contributing to the costs of the future addition of 1,500 MW of new solar and energy storage resources, agreements involving carbon capture and storage at Entergy Louisiana’s existing Lake Charles Power Station, and potential future wind and nuclear resources. Entergy Louisiana anticipates funding the incremental cost to serve the customer through direct financial contributions from the customer and the revenues it expects to earn under the electric service agreement. The electric service agreement also contains provisions for termination payments that will help ensure that there is no harm to Entergy Louisiana and its customers in the event of early termination. A directive was issued at the LPSC’s November 2024 meeting for the matter to be decided by October 2025. In February 2025 intervenors filed a motion asking the LPSC to deny Entergy Louisiana’s requested exemption from the LPSC’s order addressing competitive solicitation procedures and further asking the LPSC to dismiss the application. The ALJ issued an order denying the motion to dismiss the application and deferring the LPSC’s consideration of the motion regarding the competitive solicitation procedures until the hearing. In March 2025 the same intervenors filed a motion requesting the LPSC to require the customer and its parent company to be joined as parties to the proceeding or dismiss the application. In April 2025 the ALJ issued an order denying the March 2025 motion, and the moving parties filed a motion asking the LPSC to review and reverse the ALJ’s decision.
In February 2025, Entergy Louisiana filed supplemental testimony with the LPSC stating that the third combined cycle combustion turbine resource presented in the October 2024 application would be sited at Entergy Louisiana’s Waterford site in Killona, Louisiana, alongside existing Entergy Louisiana generation resources. The testimony also notes that Entergy Louisiana is negotiating with the customer in response to the customer’s request to increase the load associated with its project in north Louisiana. The testimony indicates further that the additional load can be served without additional generation capacity beyond what was presented in the October 2024 application, but that additional transmission facilities, which will be funded directly by the customer, are needed to serve this additional load.

In April 2025 and May 2025 the LPSC staff and certain intervenors each filed their direct testimony and cross-answering testimony, respectively. The LPSC staff’s testimony discussed the significant projected benefits associated with the data center project; however, both the LPSC staff and such intervenors also identified purported risks associated with constructing the requested resources based on the terms and conditions under which the customer would be taking service. Both the LPSC staff and such intervenors also recommended that the LPSC impose certain conditions on its approval which, if adopted, would support approval of Entergy Louisiana’s application. The LPSC staff’s recommendations included a condition that would require, under specified circumstances, certain sharing of net revenues from service to the project with Entergy Louisiana’s other customers. The LPSC staff also recommended that the LPSC deny approval of the corporate sustainability rider terms providing for the customer to supply funding toward the cost of installing carbon capture and storage infrastructure at Entergy Louisiana’s Lake Charles Power Station. The Louisiana Energy Users Group and other intervenors recommended that the LPSC require various changes to the terms of the electric service agreement with the customer that would shift additional risk and cost to the customer rather than Entergy Louisiana’s broader customer base. Certain intervenors also challenged approval on the basis that Entergy Louisiana did not conduct a request for proposals to procure the proposed generation resources to serve the customer’s project; these intervenors also advocated that Entergy Louisiana be required to procure more renewable generation and evaluate transmission alternatives rather than proceeding with development of all of the proposed new generation resources. In May 2025, Entergy Louisiana filed its rebuttal testimony responding to the direct and cross-answering testimony of the LPSC staff and intervenors. The rebuttal testimony expressed support for or no opposition to the LPSC’s adoption of certain of the proposed recommendations and identified why other proposed recommendations should not be adopted. In addition, the rebuttal testimony stated that the negotiations related to the increase in the load amount for the customer’s project had concluded and that a rider to the electric service agreement reflecting this increase had been executed. In advance of the July 2025 hearing, Entergy Louisiana reached a settlement agreement with the LPSC staff and three separate intervenors. The hearing concluded and the matter is currently under consideration by the ALJ.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In April 2023, Entergy Louisiana filed an application proposing to utilize approximately $1.6 billion in certain low interest debt to generate earnings to apply toward the reduction of the COVID-19 regulatory asset, as well as to conduct additional outside right-of-way vegetation management activities and fund the minor storm reserve account. In that filing, Entergy Louisiana proposed to delay repayment of certain shorter-term first mortgage bonds that were issued to finance storm restoration costs until the costs could be securitized, and to invest the funds that otherwise would be used to repay those bonds in the money pool to take advantage of the spread between prevailing interest rates on investments in the money pool and the interest rates on the bonds. The LPSC approved Entergy Louisiana’s requested relief in June 2023. In November 2024, Entergy Louisiana submitted a filing to the LPSC requesting that the LPSC review Entergy Louisiana’s computation of the COVID-19 regulatory asset as well as Entergy Louisiana’s proposal to offset the regulatory asset against the net interest earned on the short-term debt funds, resulting in no increased costs to customers. At the time of the filing, Entergy Louisiana had a regulatory asset of $47.8 million for costs associated
with the COVID-19 pandemic. As of June 30, 2025, Entergy Louisiana had a regulatory liability of $48.9 million for the deferred earnings related to the approximately $1.6 billion in low interest debt, which had been fully repaid by August 2024. In granting Entergy Louisiana’s requested relief in June 2023, the LPSC ordered that any amount of earnings exceeding the amount of the COVID-19 regulatory asset be transferred to Entergy Louisiana’s storm reserve escrow account. In May 2025 the LPSC staff filed direct testimony finding that Entergy Louisiana had complied with the relevant orders and recommending approval of the requested treatment. In June 2025, Entergy Louisiana and the LPSC staff filed a joint motion requesting a hearing for the admission of an uncontested stipulated settlement agreement in the matter. A settlement hearing took place in July 2025 and Entergy Louisiana expects the settlement to be considered at an upcoming meeting of the LPSC. The settlement terms provide for LPSC approval of Entergy Louisiana’s calculation of the COVID-19 regulatory assets and Entergy Louisiana’s proposal to offset the regulatory asset as described above and as proposed in Entergy Louisiana’s November 2024 filing.

Filings with the MPSC (Entergy Mississippi)

Retail Rates

2025 Formula Rate Plan Filing

In February 2025, Entergy Mississippi submitted its formula rate plan 2025 test year filing and 2024 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2024 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2025 calendar year also to be within the formula rate plan bandwidth. The 2025 test year filing showed an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2024 look-back filing compared actual 2024 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues, although Entergy Mississippi proposed to adjust interim rates by $135 thousand to reflect two outside-the-bandwidth changes: (1) the completion of Entergy Mississippi’s return to customers of credits under its restructuring credit rider; and (2) a true-up of demand side management costs.

In June 2025, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2025 test year filing, with the exception of immaterial adjustments to certain operation and maintenance expenses. The formula rate plan reflected an earned return on rate base of 7.68% for calendar year 2025, resulting in no change in formula rate plan revenues for 2025. Pursuant to the stipulation, Entergy Mississippi’s 2024 look-back filing reflected an earned return on rate base of 7.55%, which also resulted in no change in formula rate plan revenues for 2024. In addition, the stipulation included the recovery of the two outside-the-bandwidth changes discussed above as well as the ratemaking treatment of customer contributions (deferred revenue and prepaid contributions in aid of construction). In June 2025 the MPSC approved the joint stipulation with rates effective in July 2025.

Interim Facilities Rate Adjustments

In May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with state legislation passed in January 2024. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed the first of its annual interim facilities rate adjustment reports in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Entergy Mississippi filed its second interim facilities rate adjustment report in November 2024 to recover approximately $46.7 million of these costs over a 12-month period with rates effective beginning in January 2025. In February 2025, Entergy Mississippi filed a true-up interim facilities rate adjustment report to the initial annual interim facilities rate adjustment report filed in May 2024, reflecting the recovery of an
additional approximately $1.0 million of costs over a 12-month period with rates effective with the first billing cycle of April 2025.

Filings with the City Council (Entergy New Orleans)

Retail Rates

2025 Formula Rate Plan Filing

In April 2025, Entergy New Orleans submitted to the City Council its formula rate plan 2024 test year filing. The 2024 evaluation report produced an electric earned return on equity of 10.98% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in a decrease in electric rates of $13.8 million. The decrease in electric rates is driven by the realignment of regulatory liabilities into the formula from a separate rate mechanism, partially offset by the cost of known and measurable electric capital additions. The filing also commences the previously authorized recovery of certain regulatory costs and requests a revenue-neutral recovery to offset a proposed reduction in bill payment late fees. Taking into account these proposed adjustments, the filing presents a decrease in authorized electric revenues of $8.6 million. The City Council’s advisors issued their report in July 2025 seeking a reduction in Entergy New Orleans’s requested electric formula rate plan revenues of approximately $7.2 million due to certain proposed cost realignments and disallowances, of which $4.1 million is associated with Entergy New Orleans’s proposed implementation, on a revenue neutral basis, of a proposed reduction in customer late fees. The City Council’s advisors also proposed rate mitigation in the amount of $4.4 million through offsets to the formula rate plan funded by certain regulatory liabilities. The City Council’s advisors’ report began a 35-day period to resolve any disputes among the parties regarding the formula rate plan. For any disputed rate adjustments, the City Council would set a procedural schedule to resolve. Resulting rates will be effective with the first billing cycle of September 2025 pursuant to the formula rate plan tariff.

Filings with the PUCT and Texas Cities (Entergy Texas)

Retail Rates

Distribution Cost Recovery Factor (DCRF) Rider

In April 2025, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $77.8 million annually, or $29.3 million in incremental annual revenues beyond Entergy Texas’s then-effective DCRF rider based on its capital invested in distribution between July 1, 2024 and December 31, 2024, including distribution-related restoration costs associated with Hurricane Beryl. In June 2025 the PUCT approved the DCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective on June 25, 2025.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2024, Entergy Texas filed with the PUCT a request to amend its TCRF rider, which was previously reset to zero in June 2023 as a result of the 2022 base rate case. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $9.7 million annually based on its capital invested in transmission between January 1, 2022 and June 30, 2024 and changes in other transmission charges. In April 2025 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 7, 2025.

Entergy Arkansas Opportunity Sales Proceeding

As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments
to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023.

In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth Circuit and the court granted the motion to expedite. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. In December 2024 the United States Court of Appeals for the Eighth Circuit affirmed the decision of the U.S. District Court for the Eastern District of Arkansas, and Entergy Arkansas filed a petition for rehearing en banc. In January 2025 the United States Court of Appeals for the Eighth Circuit denied Entergy Arkansas’s petition. In April 2025, Entergy Arkansas filed a petition for certiorari with the United States Supreme Court. In June 2025 the United States Supreme Court denied Entergy Arkansas’s petition for certiorari.

MSS-4 Replacement Tariff - Net Operating Loss Carryforward Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the MSS-4 replacement tariff net operating loss carryforward proceeding.

The MSS-4 replacement tariff, a tariff governing the sales of energy and capacity among the Utility operating companies, includes protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In April 2025, pursuant to such protocols, the City Council filed with the FERC a formal challenge relating to Entergy Services’ inclusion and allocation of net operating loss carryforward accumulated deferred income taxes in the MSS-4 replacement tariff rates charged to Entergy New Orleans’s monthly bills for calendar year 2023. In May 2025, Entergy Services filed a response to the formal challenge and is awaiting a response from the FERC.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. The following are updates to that discussion.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in February 2023, System Energy submitted a tariff compliance filing with the FERC to clarify that, consistent with the releases provided in the June 2022 MPSC settlement, Entergy Mississippi would continue to be charged for its allocation of the sale-leaseback renewal costs under the Unit Power Sales Agreement. In March 2023 the MPSC filed a protest to System Energy’s tariff compliance filing. The MPSC argued that the settlement did not specifically address post-settlement sale-leaseback renewal costs and that the sale-leaseback renewal costs may not be recovered under the Unit Power Sales Agreement. In February 2025, System Energy and the MPSC resolved their dispute concerning the sale-leaseback renewal costs. As a result, the MPSC withdrew its protest at the FERC on System Energy’s tariff compliance filing. Entergy Mississippi will continue to pay the allocated sale-leaseback renewal costs of approximately $5.7 million annually and there are no refunds due for prior periods. In March 2025, System Energy filed a status report with the FERC explaining that the dispute is resolved. In April 2025 the FERC accepted System Energy’s tariff compliance filing.
System Energy Settlement with the LPSC

As discussed in the Form 10-K, in 2024, System Energy reached a settlement with the LPSC to globally resolve all of the LPSC’s actual and potential claims in multiple docketed proceedings pending before the FERC (including all docketed proceedings resolved by the MPSC, the APSC, and the City Council settlements) and associated with System Energy’s past implementation of the Unit Power Sales Agreement. In compliance with the settlement, in May 2025, System Energy, Entergy Louisiana, and Entergy Mississippi submitted the following filings with the FERC: (1) a Federal Power Act Section 203 application seeking approval for the permanent divestiture by Entergy Louisiana to Entergy Mississippi of its rights to capacity and energy from Grand Gulf; and (2) a Federal Power Act Section 205 application seeking approval to modify the entitlement percentages of the remaining purchasers under the Unit Power Sales Agreement in connection with the foregoing divestiture. In July 2025, the FERC issued an order accepting the Federal Power Act Section 205 application to remove Entergy Louisiana as a party to the Unit Power Sales Agreement. As a result of the order, the Unit Power Sales Agreement entitlement percentages of the remaining purchasers will be permanently modified to exclude Entergy Louisiana, to be effective beginning October 2025. The FERC also issued an order dismissing the Federal Power Act Section 203 application based on lack of jurisdiction.

Storm Cost Recovery Filings with Retail Regulators

See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following is an update to that discussion.

Entergy Louisiana

Hurricane Francine

In September 2024, Hurricane Francine caused damage to the areas served by Entergy Louisiana. The storm resulted in widespread power outages, primarily due to damage to distribution infrastructure as a result of strong winds and heavy rain, and the loss of sales during the power outages.

In December 2024, and subsequently amended in an errata filed in February 2025, Entergy Louisiana submitted an application to the LPSC seeking a determination that approximately $183.6 million in storm restoration costs associated with Hurricane Francine were reasonable and necessary and, therefore, eligible for recovery from customers, as well as approval to recover approximately $3.6 million in certain carrying costs from customers. In February 2025, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting a revenue increase of $17.8 million from funds approved by the LPSC (on an interim basis) for Hurricane Francine recovery costs. The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the 2023 formula rate plan filing above. Also in February 2025, Entergy Louisiana withdrew $33.5 million from its funded storm reserves. In June 2025 the LPSC staff filed direct testimony. The LPSC staff recommends approval of Entergy Louisiana’s as-requested storm restoration costs with the exception of approximately $10.6 million, comprised primarily of estimates of mutual assistance invoices that have not yet been received at the time of filing and that ultimately exceeded the actual amounts invoiced, as well as certain incentive compensation, and $1.8 million associated with certain carrying costs. Entergy Louisiana’s rebuttal testimony is due in August 2025 and a hearing is scheduled for November 2025.
Entergy Texas [Member]  
Public Utilities Disclosure [Text Block] RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Regulatory Assets and Regulatory Liabilities

See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

In March 2025, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.00882 per kWh to $0.01333 per kWh. The annual redetermination included a credit related to the remaining balance due to retail customers from the System Energy settlement with the APSC, plus carrying charges and interest. See “Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - Grand Gulf Credit Rider” below for further discussion. The primary reason for the rate increase is an adjustment to account for projected increases in natural gas prices in 2025. This adjustment is expected to reduce the rate change that will be reflected in its 2026 energy cost rate redetermination. The redetermined rate of $0.01333 per kWh became effective with the first billing cycle in April 2025 through the normal operation of the tariff.
Entergy Louisiana

As discussed in the Form 10-K, in January 2023 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2021 through 2022. In April 2025 the LPSC staff issued its audit report (for Entergy Louisiana’s gas operations), which included several prospective recommendations but no financial disallowances. The LPSC accepted the report in June 2025.

Entergy Texas

As discussed in the Form 10-K, in September 2024, Entergy Texas filed an application with the PUCT to reconcile its fuel and purchased power costs for the period from April 2022 through March 2024. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in eligible fuel and purchased power expenses to generate and purchase electricity to serve its customers, net of certain revenues credited to such expenses and other adjustments. Entergy Texas’s cumulative under-recovery balance for the reconciliation period was approximately $30 million, including interest, which Entergy Texas requested authority to carry over as part of the cumulative fuel balance for the subsequent reconciliation period beginning April 2024. In November 2024 the PUCT referred the proceeding to the State Office of Administrative Hearings. In March 2025, Texas Industrial Energy Consumers, an intervenor, filed testimony regarding the recovery of capacity costs for a certain power purchase agreement, arguing the capacity costs should be imputed and treated as non-reconcilable fuel expense, recovered in Entergy Texas’s base rates. In April 2025 the PUCT staff filed testimony and later in April 2025, Entergy Texas filed rebuttal testimony. In May 2025, Entergy Texas filed, and the ALJ with the State Office of Administrative Hearings granted, a request for a paper hearing and to cancel the oral hearing on the merits previously scheduled for later in May 2025. In June 2025, Entergy Texas filed, and the ALJ with the State Office of Administrative Hearings granted, a joint motion to abate the proceeding to give the parties to the proceeding additional time to finalize a settlement.

Retail Rate Proceedings

See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion.

Filings with the APSC (Entergy Arkansas)

Retail Rates

2025 Formula Rate Plan Filing

In July 2025, Entergy Arkansas filed with the APSC its 2025 formula rate plan filing to set its formula rate for the 2026 calendar year.  The filing contained an evaluation of Entergy Arkansas’s earnings for the 2026 projected year and a netting adjustment for the 2024 historical year.  The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2026 projected year was 8.45% resulting in a revenue deficiency of $68.9 million.  The earned rate of return on common equity for the 2024 historical year was 7.71% resulting in a $48.8 million netting adjustment.  The total proposed revenue change for the 2026 projected year and 2024 historical year netting adjustment is $117.7 million.   By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint.  Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase was limited to $92.3 million. Entergy Arkansas proposed a procedural schedule that includes a hearing in November 2025 and requests an APSC order in December 2025.
Grand Gulf Credit Rider

As discussed in the Form 10-K, in June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “Complaints Against System Energy - System Energy Settlement with the APSC” in Note 2 to the financial statements in the Form 10-K for discussion of the System Energy settlement with the APSC. In July 2024 the APSC approved the tariff, under which Entergy Arkansas would refund to retail customers a total of $100.6 million. Entergy Arkansas refunded $92.3 million of the total through one-time bill credits under the Grand Gulf credit rider during the August 2024 billing cycle. In March 2025, Entergy Arkansas included the remaining balance as a credit to retail customers in its energy cost recovery rider rate redetermination filing. See further discussion within "Regulatory Assets and Regulatory Liabilities - Fuel and purchased power cost recovery - Entergy Arkansas - Energy Cost Recovery Rider" above. In April 2025 the APSC approved Entergy Arkansas’s proposal to include the remaining balance in its energy cost recovery rider effective with the first billing cycle of April 2025 and the withdrawal of the Grand Gulf credit rider after all credits had been issued. Credits to retail customers were completed in second quarter 2025, and the Grand Gulf credit rider was subsequently withdrawn.

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2023 Formula Rate Plan Filing

As discussed in the Form 10-K, in August 2024, pursuant to the global stipulated settlement agreement approved by the LPSC also in August 2024, Entergy Louisiana filed its formula rate plan evaluation report for its 2023 calendar year operations. Consistent with the global stipulated settlement agreement, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the midpoint. For the 2023 test year, however, the bandwidth provisions of the formula rate plan were temporarily suspended and, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana implemented the September 2024 formula rate plan rate adjustments effective with the first billing cycle of September 2024. In January 2025, Entergy Louisiana and the LPSC filed a joint report indicating that no disputed issues remained in the proceeding and requesting that the LPSC issue an order accepting Entergy Louisiana’s evaluation report and, ultimately, resolving this matter. In March 2025 the LPSC issued an order accepting the evaluation report.

In December 2024, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed an interim rate adjustment for the 2023 test year reflecting the return of $25.1 million of refunds from the System Energy settlement with the LPSC to customers from January through August 2025. In February 2025, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting the divestiture of Entergy Louisiana’s share of Grand Gulf capacity and energy, which was effective as of January 1, 2025. The second interim rate adjustment also reflected a revenue increase of $17.8 million for the recovery of Hurricane Francine costs as approved by the LPSC (on an interim basis). The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the Hurricane Francine proceeding in “Storm Cost Recovery Filings with Retail Regulators – Entergy Louisiana – Hurricane Francine” below. See Note 8 to the financial statements in the Form 10-K for discussion of Entergy Louisiana’s divestiture from the Unit Power Sales Agreement.

2024 Formula Rate Plan Filing

In May 2025, Entergy Louisiana filed its formula rate plan evaluation report for its 2024 calendar year operations. Consistent with the global stipulated settlement agreement approved by the LPSC in August 2024, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the
midpoint. For the test year 2024, however, any earnings above the allowed return on common equity are to be returned to customers through a credit, pursuant to the terms of the global stipulated settlement agreement. The 2024 test year evaluation produced an earned return on common equity of 9.98%, which is within the approved formula rate plan bandwidth, but above the allowed return on common equity, resulting in a customer credit of $31.9 million to be returned to customers during September and October 2025.

Other changes in formula rate plan revenue are driven by higher nuclear depreciation rates, additions to transmission and distribution plant in service reflected through the transmission recovery mechanism and distribution recovery mechanism, and the expiration of customer credits related to the LPSC’s order, offset by increased customer credits resulting from an increase in net MISO revenues reflected through the MISO cost recovery mechanism and the reduction in the Louisiana corporate income tax rate effective January 1, 2025, reflected through the tax adjustment mechanism, as discussed below. Excluding the customer credit for earnings above the authorized return on common equity discussed above, the net result of these changes on an annualized basis is a $2 million increase in formula rate plan revenue.

As noted above, the 2024 evaluation report included the effects of the change in Louisiana state tax law that reduced the corporate income tax rate to a flat 5.5% (from the then-current highest marginal rate of 7.5%) effective January 1, 2025. As such, the 2024 evaluation report reflected the calculation of current and deferred income tax expenses as well as the revaluation of accumulated deferred income taxes based on the income tax laws currently in effect. The 2024 evaluation report proposes that the rate effects associated with the revaluation of accumulated deferred income taxes, including the collection of any net accumulated deferred income tax deficiency and any related effects on rate base, should be reflected in the tax adjustment mechanism consistent with the treatment of similar Tax Cuts and Jobs Act and prior state tax change-related impacts. The effects of the change in tax law on Entergy Louisiana’s authorized return on rate base are also reflected in the 2024 evaluation report consistent with the treatment cited above, including a credit in the extraordinary cost change mechanism for the prospective change in Entergy Louisiana’s authorized return and a credit within the tax adjustment mechanism for over-collection of income tax expense through August 2025.

Additional Generation and Transmission Resources

As discussed in the Form 10-K, in October 2024, Entergy Louisiana filed an application with the LPSC seeking approval of a variety of generation and transmission resources proposed in connection with establishing service to a new data center to be developed by a subsidiary of Meta Platforms, Inc. in north Louisiana, for which an electric service agreement has been executed. The filing requests LPSC certification of three new combined cycle combustion turbine generation resources totaling 2,262 MW, each of which will be enabled for future carbon capture and storage, a new 500 kV transmission line, and 500 kV substation upgrades. The application also requests approval to implement a corporate sustainability rider applicable to the new customer. The corporate sustainability rider contemplates the new customer contributing to the costs of the future addition of 1,500 MW of new solar and energy storage resources, agreements involving carbon capture and storage at Entergy Louisiana’s existing Lake Charles Power Station, and potential future wind and nuclear resources. Entergy Louisiana anticipates funding the incremental cost to serve the customer through direct financial contributions from the customer and the revenues it expects to earn under the electric service agreement. The electric service agreement also contains provisions for termination payments that will help ensure that there is no harm to Entergy Louisiana and its customers in the event of early termination. A directive was issued at the LPSC’s November 2024 meeting for the matter to be decided by October 2025. In February 2025 intervenors filed a motion asking the LPSC to deny Entergy Louisiana’s requested exemption from the LPSC’s order addressing competitive solicitation procedures and further asking the LPSC to dismiss the application. The ALJ issued an order denying the motion to dismiss the application and deferring the LPSC’s consideration of the motion regarding the competitive solicitation procedures until the hearing. In March 2025 the same intervenors filed a motion requesting the LPSC to require the customer and its parent company to be joined as parties to the proceeding or dismiss the application. In April 2025 the ALJ issued an order denying the March 2025 motion, and the moving parties filed a motion asking the LPSC to review and reverse the ALJ’s decision.
In February 2025, Entergy Louisiana filed supplemental testimony with the LPSC stating that the third combined cycle combustion turbine resource presented in the October 2024 application would be sited at Entergy Louisiana’s Waterford site in Killona, Louisiana, alongside existing Entergy Louisiana generation resources. The testimony also notes that Entergy Louisiana is negotiating with the customer in response to the customer’s request to increase the load associated with its project in north Louisiana. The testimony indicates further that the additional load can be served without additional generation capacity beyond what was presented in the October 2024 application, but that additional transmission facilities, which will be funded directly by the customer, are needed to serve this additional load.

In April 2025 and May 2025 the LPSC staff and certain intervenors each filed their direct testimony and cross-answering testimony, respectively. The LPSC staff’s testimony discussed the significant projected benefits associated with the data center project; however, both the LPSC staff and such intervenors also identified purported risks associated with constructing the requested resources based on the terms and conditions under which the customer would be taking service. Both the LPSC staff and such intervenors also recommended that the LPSC impose certain conditions on its approval which, if adopted, would support approval of Entergy Louisiana’s application. The LPSC staff’s recommendations included a condition that would require, under specified circumstances, certain sharing of net revenues from service to the project with Entergy Louisiana’s other customers. The LPSC staff also recommended that the LPSC deny approval of the corporate sustainability rider terms providing for the customer to supply funding toward the cost of installing carbon capture and storage infrastructure at Entergy Louisiana’s Lake Charles Power Station. The Louisiana Energy Users Group and other intervenors recommended that the LPSC require various changes to the terms of the electric service agreement with the customer that would shift additional risk and cost to the customer rather than Entergy Louisiana’s broader customer base. Certain intervenors also challenged approval on the basis that Entergy Louisiana did not conduct a request for proposals to procure the proposed generation resources to serve the customer’s project; these intervenors also advocated that Entergy Louisiana be required to procure more renewable generation and evaluate transmission alternatives rather than proceeding with development of all of the proposed new generation resources. In May 2025, Entergy Louisiana filed its rebuttal testimony responding to the direct and cross-answering testimony of the LPSC staff and intervenors. The rebuttal testimony expressed support for or no opposition to the LPSC’s adoption of certain of the proposed recommendations and identified why other proposed recommendations should not be adopted. In addition, the rebuttal testimony stated that the negotiations related to the increase in the load amount for the customer’s project had concluded and that a rider to the electric service agreement reflecting this increase had been executed. In advance of the July 2025 hearing, Entergy Louisiana reached a settlement agreement with the LPSC staff and three separate intervenors. The hearing concluded and the matter is currently under consideration by the ALJ.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In April 2023, Entergy Louisiana filed an application proposing to utilize approximately $1.6 billion in certain low interest debt to generate earnings to apply toward the reduction of the COVID-19 regulatory asset, as well as to conduct additional outside right-of-way vegetation management activities and fund the minor storm reserve account. In that filing, Entergy Louisiana proposed to delay repayment of certain shorter-term first mortgage bonds that were issued to finance storm restoration costs until the costs could be securitized, and to invest the funds that otherwise would be used to repay those bonds in the money pool to take advantage of the spread between prevailing interest rates on investments in the money pool and the interest rates on the bonds. The LPSC approved Entergy Louisiana’s requested relief in June 2023. In November 2024, Entergy Louisiana submitted a filing to the LPSC requesting that the LPSC review Entergy Louisiana’s computation of the COVID-19 regulatory asset as well as Entergy Louisiana’s proposal to offset the regulatory asset against the net interest earned on the short-term debt funds, resulting in no increased costs to customers. At the time of the filing, Entergy Louisiana had a regulatory asset of $47.8 million for costs associated
with the COVID-19 pandemic. As of June 30, 2025, Entergy Louisiana had a regulatory liability of $48.9 million for the deferred earnings related to the approximately $1.6 billion in low interest debt, which had been fully repaid by August 2024. In granting Entergy Louisiana’s requested relief in June 2023, the LPSC ordered that any amount of earnings exceeding the amount of the COVID-19 regulatory asset be transferred to Entergy Louisiana’s storm reserve escrow account. In May 2025 the LPSC staff filed direct testimony finding that Entergy Louisiana had complied with the relevant orders and recommending approval of the requested treatment. In June 2025, Entergy Louisiana and the LPSC staff filed a joint motion requesting a hearing for the admission of an uncontested stipulated settlement agreement in the matter. A settlement hearing took place in July 2025 and Entergy Louisiana expects the settlement to be considered at an upcoming meeting of the LPSC. The settlement terms provide for LPSC approval of Entergy Louisiana’s calculation of the COVID-19 regulatory assets and Entergy Louisiana’s proposal to offset the regulatory asset as described above and as proposed in Entergy Louisiana’s November 2024 filing.

Filings with the MPSC (Entergy Mississippi)

Retail Rates

2025 Formula Rate Plan Filing

In February 2025, Entergy Mississippi submitted its formula rate plan 2025 test year filing and 2024 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2024 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2025 calendar year also to be within the formula rate plan bandwidth. The 2025 test year filing showed an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2024 look-back filing compared actual 2024 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues, although Entergy Mississippi proposed to adjust interim rates by $135 thousand to reflect two outside-the-bandwidth changes: (1) the completion of Entergy Mississippi’s return to customers of credits under its restructuring credit rider; and (2) a true-up of demand side management costs.

In June 2025, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2025 test year filing, with the exception of immaterial adjustments to certain operation and maintenance expenses. The formula rate plan reflected an earned return on rate base of 7.68% for calendar year 2025, resulting in no change in formula rate plan revenues for 2025. Pursuant to the stipulation, Entergy Mississippi’s 2024 look-back filing reflected an earned return on rate base of 7.55%, which also resulted in no change in formula rate plan revenues for 2024. In addition, the stipulation included the recovery of the two outside-the-bandwidth changes discussed above as well as the ratemaking treatment of customer contributions (deferred revenue and prepaid contributions in aid of construction). In June 2025 the MPSC approved the joint stipulation with rates effective in July 2025.

Interim Facilities Rate Adjustments

In May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with state legislation passed in January 2024. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed the first of its annual interim facilities rate adjustment reports in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Entergy Mississippi filed its second interim facilities rate adjustment report in November 2024 to recover approximately $46.7 million of these costs over a 12-month period with rates effective beginning in January 2025. In February 2025, Entergy Mississippi filed a true-up interim facilities rate adjustment report to the initial annual interim facilities rate adjustment report filed in May 2024, reflecting the recovery of an
additional approximately $1.0 million of costs over a 12-month period with rates effective with the first billing cycle of April 2025.

Filings with the City Council (Entergy New Orleans)

Retail Rates

2025 Formula Rate Plan Filing

In April 2025, Entergy New Orleans submitted to the City Council its formula rate plan 2024 test year filing. The 2024 evaluation report produced an electric earned return on equity of 10.98% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in a decrease in electric rates of $13.8 million. The decrease in electric rates is driven by the realignment of regulatory liabilities into the formula from a separate rate mechanism, partially offset by the cost of known and measurable electric capital additions. The filing also commences the previously authorized recovery of certain regulatory costs and requests a revenue-neutral recovery to offset a proposed reduction in bill payment late fees. Taking into account these proposed adjustments, the filing presents a decrease in authorized electric revenues of $8.6 million. The City Council’s advisors issued their report in July 2025 seeking a reduction in Entergy New Orleans’s requested electric formula rate plan revenues of approximately $7.2 million due to certain proposed cost realignments and disallowances, of which $4.1 million is associated with Entergy New Orleans’s proposed implementation, on a revenue neutral basis, of a proposed reduction in customer late fees. The City Council’s advisors also proposed rate mitigation in the amount of $4.4 million through offsets to the formula rate plan funded by certain regulatory liabilities. The City Council’s advisors’ report began a 35-day period to resolve any disputes among the parties regarding the formula rate plan. For any disputed rate adjustments, the City Council would set a procedural schedule to resolve. Resulting rates will be effective with the first billing cycle of September 2025 pursuant to the formula rate plan tariff.

Filings with the PUCT and Texas Cities (Entergy Texas)

Retail Rates

Distribution Cost Recovery Factor (DCRF) Rider

In April 2025, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $77.8 million annually, or $29.3 million in incremental annual revenues beyond Entergy Texas’s then-effective DCRF rider based on its capital invested in distribution between July 1, 2024 and December 31, 2024, including distribution-related restoration costs associated with Hurricane Beryl. In June 2025 the PUCT approved the DCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective on June 25, 2025.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2024, Entergy Texas filed with the PUCT a request to amend its TCRF rider, which was previously reset to zero in June 2023 as a result of the 2022 base rate case. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $9.7 million annually based on its capital invested in transmission between January 1, 2022 and June 30, 2024 and changes in other transmission charges. In April 2025 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 7, 2025.

Entergy Arkansas Opportunity Sales Proceeding

As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments
to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023.

In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth Circuit and the court granted the motion to expedite. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. In December 2024 the United States Court of Appeals for the Eighth Circuit affirmed the decision of the U.S. District Court for the Eastern District of Arkansas, and Entergy Arkansas filed a petition for rehearing en banc. In January 2025 the United States Court of Appeals for the Eighth Circuit denied Entergy Arkansas’s petition. In April 2025, Entergy Arkansas filed a petition for certiorari with the United States Supreme Court. In June 2025 the United States Supreme Court denied Entergy Arkansas’s petition for certiorari.

MSS-4 Replacement Tariff - Net Operating Loss Carryforward Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the MSS-4 replacement tariff net operating loss carryforward proceeding.

The MSS-4 replacement tariff, a tariff governing the sales of energy and capacity among the Utility operating companies, includes protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In April 2025, pursuant to such protocols, the City Council filed with the FERC a formal challenge relating to Entergy Services’ inclusion and allocation of net operating loss carryforward accumulated deferred income taxes in the MSS-4 replacement tariff rates charged to Entergy New Orleans’s monthly bills for calendar year 2023. In May 2025, Entergy Services filed a response to the formal challenge and is awaiting a response from the FERC.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. The following are updates to that discussion.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in February 2023, System Energy submitted a tariff compliance filing with the FERC to clarify that, consistent with the releases provided in the June 2022 MPSC settlement, Entergy Mississippi would continue to be charged for its allocation of the sale-leaseback renewal costs under the Unit Power Sales Agreement. In March 2023 the MPSC filed a protest to System Energy’s tariff compliance filing. The MPSC argued that the settlement did not specifically address post-settlement sale-leaseback renewal costs and that the sale-leaseback renewal costs may not be recovered under the Unit Power Sales Agreement. In February 2025, System Energy and the MPSC resolved their dispute concerning the sale-leaseback renewal costs. As a result, the MPSC withdrew its protest at the FERC on System Energy’s tariff compliance filing. Entergy Mississippi will continue to pay the allocated sale-leaseback renewal costs of approximately $5.7 million annually and there are no refunds due for prior periods. In March 2025, System Energy filed a status report with the FERC explaining that the dispute is resolved. In April 2025 the FERC accepted System Energy’s tariff compliance filing.
System Energy Settlement with the LPSC

As discussed in the Form 10-K, in 2024, System Energy reached a settlement with the LPSC to globally resolve all of the LPSC’s actual and potential claims in multiple docketed proceedings pending before the FERC (including all docketed proceedings resolved by the MPSC, the APSC, and the City Council settlements) and associated with System Energy’s past implementation of the Unit Power Sales Agreement. In compliance with the settlement, in May 2025, System Energy, Entergy Louisiana, and Entergy Mississippi submitted the following filings with the FERC: (1) a Federal Power Act Section 203 application seeking approval for the permanent divestiture by Entergy Louisiana to Entergy Mississippi of its rights to capacity and energy from Grand Gulf; and (2) a Federal Power Act Section 205 application seeking approval to modify the entitlement percentages of the remaining purchasers under the Unit Power Sales Agreement in connection with the foregoing divestiture. In July 2025, the FERC issued an order accepting the Federal Power Act Section 205 application to remove Entergy Louisiana as a party to the Unit Power Sales Agreement. As a result of the order, the Unit Power Sales Agreement entitlement percentages of the remaining purchasers will be permanently modified to exclude Entergy Louisiana, to be effective beginning October 2025. The FERC also issued an order dismissing the Federal Power Act Section 203 application based on lack of jurisdiction.

Storm Cost Recovery Filings with Retail Regulators

See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following is an update to that discussion.

Entergy Louisiana

Hurricane Francine

In September 2024, Hurricane Francine caused damage to the areas served by Entergy Louisiana. The storm resulted in widespread power outages, primarily due to damage to distribution infrastructure as a result of strong winds and heavy rain, and the loss of sales during the power outages.

In December 2024, and subsequently amended in an errata filed in February 2025, Entergy Louisiana submitted an application to the LPSC seeking a determination that approximately $183.6 million in storm restoration costs associated with Hurricane Francine were reasonable and necessary and, therefore, eligible for recovery from customers, as well as approval to recover approximately $3.6 million in certain carrying costs from customers. In February 2025, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting a revenue increase of $17.8 million from funds approved by the LPSC (on an interim basis) for Hurricane Francine recovery costs. The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the 2023 formula rate plan filing above. Also in February 2025, Entergy Louisiana withdrew $33.5 million from its funded storm reserves. In June 2025 the LPSC staff filed direct testimony. The LPSC staff recommends approval of Entergy Louisiana’s as-requested storm restoration costs with the exception of approximately $10.6 million, comprised primarily of estimates of mutual assistance invoices that have not yet been received at the time of filing and that ultimately exceeded the actual amounts invoiced, as well as certain incentive compensation, and $1.8 million associated with certain carrying costs. Entergy Louisiana’s rebuttal testimony is due in August 2025 and a hearing is scheduled for November 2025.
System Energy [Member]  
Public Utilities Disclosure [Text Block] RATE AND REGULATORY MATTERS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Regulatory Assets and Regulatory Liabilities

See Note 2 to the financial statements in the Form 10-K for information regarding regulatory assets and regulatory liabilities in the Utility business presented on the balance sheets of Entergy and the Registrant Subsidiaries.  The following are updates to that discussion.

Fuel and purchased power cost recovery

Entergy Arkansas

Energy Cost Recovery Rider

In March 2025, Entergy Arkansas filed its annual redetermination of its energy cost rate pursuant to the energy cost recovery rider, which reflected an increase in the rate from $0.00882 per kWh to $0.01333 per kWh. The annual redetermination included a credit related to the remaining balance due to retail customers from the System Energy settlement with the APSC, plus carrying charges and interest. See “Retail Rate Proceedings - Filings with the APSC (Entergy Arkansas) - Retail Rates - Grand Gulf Credit Rider” below for further discussion. The primary reason for the rate increase is an adjustment to account for projected increases in natural gas prices in 2025. This adjustment is expected to reduce the rate change that will be reflected in its 2026 energy cost rate redetermination. The redetermined rate of $0.01333 per kWh became effective with the first billing cycle in April 2025 through the normal operation of the tariff.
Entergy Louisiana

As discussed in the Form 10-K, in January 2023 the LPSC staff provided notice of an audit of Entergy Louisiana’s purchased gas adjustment clause filings. The audit includes a review of the reasonableness of charges flowed through Entergy Louisiana’s purchased gas adjustment clause for the period from 2021 through 2022. In April 2025 the LPSC staff issued its audit report (for Entergy Louisiana’s gas operations), which included several prospective recommendations but no financial disallowances. The LPSC accepted the report in June 2025.

Entergy Texas

As discussed in the Form 10-K, in September 2024, Entergy Texas filed an application with the PUCT to reconcile its fuel and purchased power costs for the period from April 2022 through March 2024. During the reconciliation period, Entergy Texas incurred approximately $1.6 billion in eligible fuel and purchased power expenses to generate and purchase electricity to serve its customers, net of certain revenues credited to such expenses and other adjustments. Entergy Texas’s cumulative under-recovery balance for the reconciliation period was approximately $30 million, including interest, which Entergy Texas requested authority to carry over as part of the cumulative fuel balance for the subsequent reconciliation period beginning April 2024. In November 2024 the PUCT referred the proceeding to the State Office of Administrative Hearings. In March 2025, Texas Industrial Energy Consumers, an intervenor, filed testimony regarding the recovery of capacity costs for a certain power purchase agreement, arguing the capacity costs should be imputed and treated as non-reconcilable fuel expense, recovered in Entergy Texas’s base rates. In April 2025 the PUCT staff filed testimony and later in April 2025, Entergy Texas filed rebuttal testimony. In May 2025, Entergy Texas filed, and the ALJ with the State Office of Administrative Hearings granted, a request for a paper hearing and to cancel the oral hearing on the merits previously scheduled for later in May 2025. In June 2025, Entergy Texas filed, and the ALJ with the State Office of Administrative Hearings granted, a joint motion to abate the proceeding to give the parties to the proceeding additional time to finalize a settlement.

Retail Rate Proceedings

See Note 2 to the financial statements in the Form 10-K for information regarding retail rate proceedings involving the Utility operating companies. The following are updates to that discussion.

Filings with the APSC (Entergy Arkansas)

Retail Rates

2025 Formula Rate Plan Filing

In July 2025, Entergy Arkansas filed with the APSC its 2025 formula rate plan filing to set its formula rate for the 2026 calendar year.  The filing contained an evaluation of Entergy Arkansas’s earnings for the 2026 projected year and a netting adjustment for the 2024 historical year.  The filing showed that Entergy Arkansas’s earned rate of return on common equity for the 2026 projected year was 8.45% resulting in a revenue deficiency of $68.9 million.  The earned rate of return on common equity for the 2024 historical year was 7.71% resulting in a $48.8 million netting adjustment.  The total proposed revenue change for the 2026 projected year and 2024 historical year netting adjustment is $117.7 million.   By operation of the formula rate plan, Entergy Arkansas’s recovery of the revenue requirement is subject to a four percent annual revenue constraint.  Because Entergy Arkansas’s revenue requirement in this filing exceeded the constraint, the resulting increase was limited to $92.3 million. Entergy Arkansas proposed a procedural schedule that includes a hearing in November 2025 and requests an APSC order in December 2025.
Grand Gulf Credit Rider

As discussed in the Form 10-K, in June 2024, Entergy Arkansas filed with the APSC a tariff to provide retail customers a credit resulting from the terms of the settlement agreement between Entergy Arkansas, System Energy, additional named Entergy parties, and the APSC pertaining to System Energy’s billings for wholesale sales of energy and capacity from the Grand Gulf nuclear plant. See “Complaints Against System Energy - System Energy Settlement with the APSC” in Note 2 to the financial statements in the Form 10-K for discussion of the System Energy settlement with the APSC. In July 2024 the APSC approved the tariff, under which Entergy Arkansas would refund to retail customers a total of $100.6 million. Entergy Arkansas refunded $92.3 million of the total through one-time bill credits under the Grand Gulf credit rider during the August 2024 billing cycle. In March 2025, Entergy Arkansas included the remaining balance as a credit to retail customers in its energy cost recovery rider rate redetermination filing. See further discussion within "Regulatory Assets and Regulatory Liabilities - Fuel and purchased power cost recovery - Entergy Arkansas - Energy Cost Recovery Rider" above. In April 2025 the APSC approved Entergy Arkansas’s proposal to include the remaining balance in its energy cost recovery rider effective with the first billing cycle of April 2025 and the withdrawal of the Grand Gulf credit rider after all credits had been issued. Credits to retail customers were completed in second quarter 2025, and the Grand Gulf credit rider was subsequently withdrawn.

Filings with the LPSC (Entergy Louisiana)

Retail Rates - Electric

2023 Formula Rate Plan Filing

As discussed in the Form 10-K, in August 2024, pursuant to the global stipulated settlement agreement approved by the LPSC also in August 2024, Entergy Louisiana filed its formula rate plan evaluation report for its 2023 calendar year operations. Consistent with the global stipulated settlement agreement, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the midpoint. For the 2023 test year, however, the bandwidth provisions of the formula rate plan were temporarily suspended and, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana implemented the September 2024 formula rate plan rate adjustments effective with the first billing cycle of September 2024. In January 2025, Entergy Louisiana and the LPSC filed a joint report indicating that no disputed issues remained in the proceeding and requesting that the LPSC issue an order accepting Entergy Louisiana’s evaluation report and, ultimately, resolving this matter. In March 2025 the LPSC issued an order accepting the evaluation report.

In December 2024, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed an interim rate adjustment for the 2023 test year reflecting the return of $25.1 million of refunds from the System Energy settlement with the LPSC to customers from January through August 2025. In February 2025, pursuant to the terms of the global stipulated settlement agreement, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting the divestiture of Entergy Louisiana’s share of Grand Gulf capacity and energy, which was effective as of January 1, 2025. The second interim rate adjustment also reflected a revenue increase of $17.8 million for the recovery of Hurricane Francine costs as approved by the LPSC (on an interim basis). The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the Hurricane Francine proceeding in “Storm Cost Recovery Filings with Retail Regulators – Entergy Louisiana – Hurricane Francine” below. See Note 8 to the financial statements in the Form 10-K for discussion of Entergy Louisiana’s divestiture from the Unit Power Sales Agreement.

2024 Formula Rate Plan Filing

In May 2025, Entergy Louisiana filed its formula rate plan evaluation report for its 2024 calendar year operations. Consistent with the global stipulated settlement agreement approved by the LPSC in August 2024, the filing reflected a 9.7% allowed return on common equity with a bandwidth of 40 basis points above and below the
midpoint. For the test year 2024, however, any earnings above the allowed return on common equity are to be returned to customers through a credit, pursuant to the terms of the global stipulated settlement agreement. The 2024 test year evaluation produced an earned return on common equity of 9.98%, which is within the approved formula rate plan bandwidth, but above the allowed return on common equity, resulting in a customer credit of $31.9 million to be returned to customers during September and October 2025.

Other changes in formula rate plan revenue are driven by higher nuclear depreciation rates, additions to transmission and distribution plant in service reflected through the transmission recovery mechanism and distribution recovery mechanism, and the expiration of customer credits related to the LPSC’s order, offset by increased customer credits resulting from an increase in net MISO revenues reflected through the MISO cost recovery mechanism and the reduction in the Louisiana corporate income tax rate effective January 1, 2025, reflected through the tax adjustment mechanism, as discussed below. Excluding the customer credit for earnings above the authorized return on common equity discussed above, the net result of these changes on an annualized basis is a $2 million increase in formula rate plan revenue.

As noted above, the 2024 evaluation report included the effects of the change in Louisiana state tax law that reduced the corporate income tax rate to a flat 5.5% (from the then-current highest marginal rate of 7.5%) effective January 1, 2025. As such, the 2024 evaluation report reflected the calculation of current and deferred income tax expenses as well as the revaluation of accumulated deferred income taxes based on the income tax laws currently in effect. The 2024 evaluation report proposes that the rate effects associated with the revaluation of accumulated deferred income taxes, including the collection of any net accumulated deferred income tax deficiency and any related effects on rate base, should be reflected in the tax adjustment mechanism consistent with the treatment of similar Tax Cuts and Jobs Act and prior state tax change-related impacts. The effects of the change in tax law on Entergy Louisiana’s authorized return on rate base are also reflected in the 2024 evaluation report consistent with the treatment cited above, including a credit in the extraordinary cost change mechanism for the prospective change in Entergy Louisiana’s authorized return and a credit within the tax adjustment mechanism for over-collection of income tax expense through August 2025.

Additional Generation and Transmission Resources

As discussed in the Form 10-K, in October 2024, Entergy Louisiana filed an application with the LPSC seeking approval of a variety of generation and transmission resources proposed in connection with establishing service to a new data center to be developed by a subsidiary of Meta Platforms, Inc. in north Louisiana, for which an electric service agreement has been executed. The filing requests LPSC certification of three new combined cycle combustion turbine generation resources totaling 2,262 MW, each of which will be enabled for future carbon capture and storage, a new 500 kV transmission line, and 500 kV substation upgrades. The application also requests approval to implement a corporate sustainability rider applicable to the new customer. The corporate sustainability rider contemplates the new customer contributing to the costs of the future addition of 1,500 MW of new solar and energy storage resources, agreements involving carbon capture and storage at Entergy Louisiana’s existing Lake Charles Power Station, and potential future wind and nuclear resources. Entergy Louisiana anticipates funding the incremental cost to serve the customer through direct financial contributions from the customer and the revenues it expects to earn under the electric service agreement. The electric service agreement also contains provisions for termination payments that will help ensure that there is no harm to Entergy Louisiana and its customers in the event of early termination. A directive was issued at the LPSC’s November 2024 meeting for the matter to be decided by October 2025. In February 2025 intervenors filed a motion asking the LPSC to deny Entergy Louisiana’s requested exemption from the LPSC’s order addressing competitive solicitation procedures and further asking the LPSC to dismiss the application. The ALJ issued an order denying the motion to dismiss the application and deferring the LPSC’s consideration of the motion regarding the competitive solicitation procedures until the hearing. In March 2025 the same intervenors filed a motion requesting the LPSC to require the customer and its parent company to be joined as parties to the proceeding or dismiss the application. In April 2025 the ALJ issued an order denying the March 2025 motion, and the moving parties filed a motion asking the LPSC to review and reverse the ALJ’s decision.
In February 2025, Entergy Louisiana filed supplemental testimony with the LPSC stating that the third combined cycle combustion turbine resource presented in the October 2024 application would be sited at Entergy Louisiana’s Waterford site in Killona, Louisiana, alongside existing Entergy Louisiana generation resources. The testimony also notes that Entergy Louisiana is negotiating with the customer in response to the customer’s request to increase the load associated with its project in north Louisiana. The testimony indicates further that the additional load can be served without additional generation capacity beyond what was presented in the October 2024 application, but that additional transmission facilities, which will be funded directly by the customer, are needed to serve this additional load.

In April 2025 and May 2025 the LPSC staff and certain intervenors each filed their direct testimony and cross-answering testimony, respectively. The LPSC staff’s testimony discussed the significant projected benefits associated with the data center project; however, both the LPSC staff and such intervenors also identified purported risks associated with constructing the requested resources based on the terms and conditions under which the customer would be taking service. Both the LPSC staff and such intervenors also recommended that the LPSC impose certain conditions on its approval which, if adopted, would support approval of Entergy Louisiana’s application. The LPSC staff’s recommendations included a condition that would require, under specified circumstances, certain sharing of net revenues from service to the project with Entergy Louisiana’s other customers. The LPSC staff also recommended that the LPSC deny approval of the corporate sustainability rider terms providing for the customer to supply funding toward the cost of installing carbon capture and storage infrastructure at Entergy Louisiana’s Lake Charles Power Station. The Louisiana Energy Users Group and other intervenors recommended that the LPSC require various changes to the terms of the electric service agreement with the customer that would shift additional risk and cost to the customer rather than Entergy Louisiana’s broader customer base. Certain intervenors also challenged approval on the basis that Entergy Louisiana did not conduct a request for proposals to procure the proposed generation resources to serve the customer’s project; these intervenors also advocated that Entergy Louisiana be required to procure more renewable generation and evaluate transmission alternatives rather than proceeding with development of all of the proposed new generation resources. In May 2025, Entergy Louisiana filed its rebuttal testimony responding to the direct and cross-answering testimony of the LPSC staff and intervenors. The rebuttal testimony expressed support for or no opposition to the LPSC’s adoption of certain of the proposed recommendations and identified why other proposed recommendations should not be adopted. In addition, the rebuttal testimony stated that the negotiations related to the increase in the load amount for the customer’s project had concluded and that a rider to the electric service agreement reflecting this increase had been executed. In advance of the July 2025 hearing, Entergy Louisiana reached a settlement agreement with the LPSC staff and three separate intervenors. The hearing concluded and the matter is currently under consideration by the ALJ.

COVID-19 Orders

As discussed in the Form 10-K, in April 2020 the LPSC issued an order authorizing utilities to record as a regulatory asset expenses incurred from the suspension of disconnections and collection of late fees imposed by LPSC orders associated with the COVID-19 pandemic. In April 2023, Entergy Louisiana filed an application proposing to utilize approximately $1.6 billion in certain low interest debt to generate earnings to apply toward the reduction of the COVID-19 regulatory asset, as well as to conduct additional outside right-of-way vegetation management activities and fund the minor storm reserve account. In that filing, Entergy Louisiana proposed to delay repayment of certain shorter-term first mortgage bonds that were issued to finance storm restoration costs until the costs could be securitized, and to invest the funds that otherwise would be used to repay those bonds in the money pool to take advantage of the spread between prevailing interest rates on investments in the money pool and the interest rates on the bonds. The LPSC approved Entergy Louisiana’s requested relief in June 2023. In November 2024, Entergy Louisiana submitted a filing to the LPSC requesting that the LPSC review Entergy Louisiana’s computation of the COVID-19 regulatory asset as well as Entergy Louisiana’s proposal to offset the regulatory asset against the net interest earned on the short-term debt funds, resulting in no increased costs to customers. At the time of the filing, Entergy Louisiana had a regulatory asset of $47.8 million for costs associated
with the COVID-19 pandemic. As of June 30, 2025, Entergy Louisiana had a regulatory liability of $48.9 million for the deferred earnings related to the approximately $1.6 billion in low interest debt, which had been fully repaid by August 2024. In granting Entergy Louisiana’s requested relief in June 2023, the LPSC ordered that any amount of earnings exceeding the amount of the COVID-19 regulatory asset be transferred to Entergy Louisiana’s storm reserve escrow account. In May 2025 the LPSC staff filed direct testimony finding that Entergy Louisiana had complied with the relevant orders and recommending approval of the requested treatment. In June 2025, Entergy Louisiana and the LPSC staff filed a joint motion requesting a hearing for the admission of an uncontested stipulated settlement agreement in the matter. A settlement hearing took place in July 2025 and Entergy Louisiana expects the settlement to be considered at an upcoming meeting of the LPSC. The settlement terms provide for LPSC approval of Entergy Louisiana’s calculation of the COVID-19 regulatory assets and Entergy Louisiana’s proposal to offset the regulatory asset as described above and as proposed in Entergy Louisiana’s November 2024 filing.

Filings with the MPSC (Entergy Mississippi)

Retail Rates

2025 Formula Rate Plan Filing

In February 2025, Entergy Mississippi submitted its formula rate plan 2025 test year filing and 2024 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2024 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2025 calendar year also to be within the formula rate plan bandwidth. The 2025 test year filing showed an earned return on rate base of 7.64% and reflected no change in formula rate plan revenues. The 2024 look-back filing compared actual 2024 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues, although Entergy Mississippi proposed to adjust interim rates by $135 thousand to reflect two outside-the-bandwidth changes: (1) the completion of Entergy Mississippi’s return to customers of credits under its restructuring credit rider; and (2) a true-up of demand side management costs.

In June 2025, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2025 test year filing, with the exception of immaterial adjustments to certain operation and maintenance expenses. The formula rate plan reflected an earned return on rate base of 7.68% for calendar year 2025, resulting in no change in formula rate plan revenues for 2025. Pursuant to the stipulation, Entergy Mississippi’s 2024 look-back filing reflected an earned return on rate base of 7.55%, which also resulted in no change in formula rate plan revenues for 2024. In addition, the stipulation included the recovery of the two outside-the-bandwidth changes discussed above as well as the ratemaking treatment of customer contributions (deferred revenue and prepaid contributions in aid of construction). In June 2025 the MPSC approved the joint stipulation with rates effective in July 2025.

Interim Facilities Rate Adjustments

In May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with state legislation passed in January 2024. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed the first of its annual interim facilities rate adjustment reports in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Entergy Mississippi filed its second interim facilities rate adjustment report in November 2024 to recover approximately $46.7 million of these costs over a 12-month period with rates effective beginning in January 2025. In February 2025, Entergy Mississippi filed a true-up interim facilities rate adjustment report to the initial annual interim facilities rate adjustment report filed in May 2024, reflecting the recovery of an
additional approximately $1.0 million of costs over a 12-month period with rates effective with the first billing cycle of April 2025.

Filings with the City Council (Entergy New Orleans)

Retail Rates

2025 Formula Rate Plan Filing

In April 2025, Entergy New Orleans submitted to the City Council its formula rate plan 2024 test year filing. The 2024 evaluation report produced an electric earned return on equity of 10.98% compared to the authorized return on equity of 9.35%. Without adjustments, this would result in a decrease in electric rates of $13.8 million. The decrease in electric rates is driven by the realignment of regulatory liabilities into the formula from a separate rate mechanism, partially offset by the cost of known and measurable electric capital additions. The filing also commences the previously authorized recovery of certain regulatory costs and requests a revenue-neutral recovery to offset a proposed reduction in bill payment late fees. Taking into account these proposed adjustments, the filing presents a decrease in authorized electric revenues of $8.6 million. The City Council’s advisors issued their report in July 2025 seeking a reduction in Entergy New Orleans’s requested electric formula rate plan revenues of approximately $7.2 million due to certain proposed cost realignments and disallowances, of which $4.1 million is associated with Entergy New Orleans’s proposed implementation, on a revenue neutral basis, of a proposed reduction in customer late fees. The City Council’s advisors also proposed rate mitigation in the amount of $4.4 million through offsets to the formula rate plan funded by certain regulatory liabilities. The City Council’s advisors’ report began a 35-day period to resolve any disputes among the parties regarding the formula rate plan. For any disputed rate adjustments, the City Council would set a procedural schedule to resolve. Resulting rates will be effective with the first billing cycle of September 2025 pursuant to the formula rate plan tariff.

Filings with the PUCT and Texas Cities (Entergy Texas)

Retail Rates

Distribution Cost Recovery Factor (DCRF) Rider

In April 2025, Entergy Texas filed with the PUCT a request to amend its DCRF rider. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $77.8 million annually, or $29.3 million in incremental annual revenues beyond Entergy Texas’s then-effective DCRF rider based on its capital invested in distribution between July 1, 2024 and December 31, 2024, including distribution-related restoration costs associated with Hurricane Beryl. In June 2025 the PUCT approved the DCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective on June 25, 2025.

Transmission Cost Recovery Factor (TCRF) Rider

As discussed in the Form 10-K, in October 2024, Entergy Texas filed with the PUCT a request to amend its TCRF rider, which was previously reset to zero in June 2023 as a result of the 2022 base rate case. The amended rider was designed to collect from Entergy Texas’s retail customers approximately $9.7 million annually based on its capital invested in transmission between January 1, 2022 and June 30, 2024 and changes in other transmission charges. In April 2025 the PUCT approved the TCRF rider, consistent with Entergy Texas’s as-filed request, and rates became effective for usage on and after April 7, 2025.

Entergy Arkansas Opportunity Sales Proceeding

As discussed in the Form 10-K, in September 2020, Entergy Arkansas filed a complaint in the U.S. District Court for the Eastern District of Arkansas challenging the APSC’s denial of recovery of $135 million of payments
to other Utility operating companies in December 2018 relating to off-system sales of electricity from 2002-2009, as ordered by the FERC. The complaint also involved a challenge to the $13.7 million, plus interest, of related refunds ordered by the APSC and paid by Entergy Arkansas in August 2020. The trial was held in February 2023.

In March 2024 the U.S. District Court for the Eastern District of Arkansas issued a judgment in favor of the APSC and against Entergy Arkansas. In March 2024 Entergy Arkansas filed a notice of appeal and a motion to expedite oral arguments with the United States Court of Appeals for the Eighth Circuit and the court granted the motion to expedite. As a result of the adverse decision by the U.S. District Court for the Eastern District of Arkansas, Entergy Arkansas concluded that it could no longer support the recognition of its $131.8 million regulatory asset reflecting the previously-expected recovery of a portion of the costs at issue in the opportunity sales proceeding and recorded a $131.8 million ($99.1 million net-of-tax) charge to earnings in first quarter 2024. In December 2024 the United States Court of Appeals for the Eighth Circuit affirmed the decision of the U.S. District Court for the Eastern District of Arkansas, and Entergy Arkansas filed a petition for rehearing en banc. In January 2025 the United States Court of Appeals for the Eighth Circuit denied Entergy Arkansas’s petition. In April 2025, Entergy Arkansas filed a petition for certiorari with the United States Supreme Court. In June 2025 the United States Supreme Court denied Entergy Arkansas’s petition for certiorari.

MSS-4 Replacement Tariff - Net Operating Loss Carryforward Proceeding

See Note 2 to the financial statements in the Form 10-K for discussion of the MSS-4 replacement tariff net operating loss carryforward proceeding.

The MSS-4 replacement tariff, a tariff governing the sales of energy and capacity among the Utility operating companies, includes protocols that provide for the disclosure of cost inputs, an opportunity for informal discovery procedures, and a challenge process. In April 2025, pursuant to such protocols, the City Council filed with the FERC a formal challenge relating to Entergy Services’ inclusion and allocation of net operating loss carryforward accumulated deferred income taxes in the MSS-4 replacement tariff rates charged to Entergy New Orleans’s monthly bills for calendar year 2023. In May 2025, Entergy Services filed a response to the formal challenge and is awaiting a response from the FERC.

Complaints Against System Energy

See Note 2 to the financial statements in the Form 10-K for information regarding pending complaints against System Energy and the settlements approved by the FERC that resolved all significant aspects of these complaints. The following are updates to that discussion.

Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue

As discussed in the Form 10-K, in February 2023, System Energy submitted a tariff compliance filing with the FERC to clarify that, consistent with the releases provided in the June 2022 MPSC settlement, Entergy Mississippi would continue to be charged for its allocation of the sale-leaseback renewal costs under the Unit Power Sales Agreement. In March 2023 the MPSC filed a protest to System Energy’s tariff compliance filing. The MPSC argued that the settlement did not specifically address post-settlement sale-leaseback renewal costs and that the sale-leaseback renewal costs may not be recovered under the Unit Power Sales Agreement. In February 2025, System Energy and the MPSC resolved their dispute concerning the sale-leaseback renewal costs. As a result, the MPSC withdrew its protest at the FERC on System Energy’s tariff compliance filing. Entergy Mississippi will continue to pay the allocated sale-leaseback renewal costs of approximately $5.7 million annually and there are no refunds due for prior periods. In March 2025, System Energy filed a status report with the FERC explaining that the dispute is resolved. In April 2025 the FERC accepted System Energy’s tariff compliance filing.
System Energy Settlement with the LPSC

As discussed in the Form 10-K, in 2024, System Energy reached a settlement with the LPSC to globally resolve all of the LPSC’s actual and potential claims in multiple docketed proceedings pending before the FERC (including all docketed proceedings resolved by the MPSC, the APSC, and the City Council settlements) and associated with System Energy’s past implementation of the Unit Power Sales Agreement. In compliance with the settlement, in May 2025, System Energy, Entergy Louisiana, and Entergy Mississippi submitted the following filings with the FERC: (1) a Federal Power Act Section 203 application seeking approval for the permanent divestiture by Entergy Louisiana to Entergy Mississippi of its rights to capacity and energy from Grand Gulf; and (2) a Federal Power Act Section 205 application seeking approval to modify the entitlement percentages of the remaining purchasers under the Unit Power Sales Agreement in connection with the foregoing divestiture. In July 2025, the FERC issued an order accepting the Federal Power Act Section 205 application to remove Entergy Louisiana as a party to the Unit Power Sales Agreement. As a result of the order, the Unit Power Sales Agreement entitlement percentages of the remaining purchasers will be permanently modified to exclude Entergy Louisiana, to be effective beginning October 2025. The FERC also issued an order dismissing the Federal Power Act Section 203 application based on lack of jurisdiction.

Storm Cost Recovery Filings with Retail Regulators

See Note 2 to the financial statements in the Form 10-K for discussion regarding storm cost recovery filings. The following is an update to that discussion.

Entergy Louisiana

Hurricane Francine

In September 2024, Hurricane Francine caused damage to the areas served by Entergy Louisiana. The storm resulted in widespread power outages, primarily due to damage to distribution infrastructure as a result of strong winds and heavy rain, and the loss of sales during the power outages.

In December 2024, and subsequently amended in an errata filed in February 2025, Entergy Louisiana submitted an application to the LPSC seeking a determination that approximately $183.6 million in storm restoration costs associated with Hurricane Francine were reasonable and necessary and, therefore, eligible for recovery from customers, as well as approval to recover approximately $3.6 million in certain carrying costs from customers. In February 2025, Entergy Louisiana filed a second interim rate adjustment for the 2023 test year reflecting a revenue increase of $17.8 million from funds approved by the LPSC (on an interim basis) for Hurricane Francine recovery costs. The second interim rate adjustment was implemented with the first billing cycle of March 2025. See further discussion of the 2023 formula rate plan filing above. Also in February 2025, Entergy Louisiana withdrew $33.5 million from its funded storm reserves. In June 2025 the LPSC staff filed direct testimony. The LPSC staff recommends approval of Entergy Louisiana’s as-requested storm restoration costs with the exception of approximately $10.6 million, comprised primarily of estimates of mutual assistance invoices that have not yet been received at the time of filing and that ultimately exceeded the actual amounts invoiced, as well as certain incentive compensation, and $1.8 million associated with certain carrying costs. Entergy Louisiana’s rebuttal testimony is due in August 2025 and a hearing is scheduled for November 2025.
v3.25.2
Equity
 6 Months Ended
Jun. 30, 2025
Equity [Text Block] EQUITY (Entergy Corporation and Entergy Louisiana)
Common Stock

Earnings per Share

Historical share and share-based data presented in the accompanying financial statements has been retroactively adjusted to reflect the two-for-one forward stock split of Entergy Corporation common stock effective December 12, 2024. See Note 7 to the financial statements in the Form 10-K for discussion of the stock split.

The following tables present Entergy’s basic and diluted earnings per share calculations for the three and six months ended June 30, 2025 and 2024, included on the consolidated income statements:
For the Three Months Ended June 30,
20252024
(Dollars In Thousands, Except Per Share Data; Shares in Millions)
$/share$/share
Consolidated net income$471,954 $51,732 
Less: Preferred dividend requirements of subsidiaries and noncontrolling interests4,024 2,810 
Net income attributable to Entergy Corporation$467,930 $48,922 
Basic shares and earnings per average common share439.2 $1.07 427.2 $0.11 
Average dilutive effect of:
Stock options0.9 — 0.6 — 
Other equity plans1.2 — 1.0 — 
Equity forwards4.4 (0.02)— — 
Diluted shares and earnings per average common share445.7 $1.05 428.8 $0.11 

For the Six Months Ended June 30,
20252024
(Dollars In Thousands, Except Per Share Data; Shares in Millions)
$/share$/share
Consolidated net income$834,376 $128,268 
Less: Preferred dividend requirements of subsidiaries and noncontrolling interests5,686 4,065 
Net income attributable to Entergy Corporation$828,690 $124,203 
Basic shares and earnings per average common share434.8 $1.91 426.8 $0.29 
Average dilutive effect of:
Stock options1.0 — 0.5 — 
Other equity plans1.3 (0.01)1.0 — 
Equity forwards6.3 (0.03)— — 
Diluted shares and earnings per average common share443.4 $1.87 428.3 $0.29 

Earnings per share dilution resulting from stock options outstanding and other equity plans is determined under the treasury stock method. The calculation of diluted earnings per share excluded 366,136 stock options
outstanding for the three months ended June 30, 2025 and 1,448,982 stock options outstanding for the three months ended June 30, 2024 because their effect would have been antidilutive. The calculation of diluted earnings per share excluded 305,113 stock options outstanding for the six months ended June 30, 2025 and 1,471,220 stock options outstanding for the six months ended June 30, 2024 because their effect would have been antidilutive. Until settlement of the forward sale agreements discussed below in “Equity Distribution Program” and “Equity Forward Sale Agreements,” earnings per share dilution resulting from the agreements, if any, is determined under the treasury stock method. Share dilution occurs when the average market price of Entergy Corporation’s common stock is higher than the average forward sales price. The calculation of diluted earnings per share excluded 2,423,880 shares for the three months ended June 30, 2025 and 2,897,964 shares for the three months ended June 30, 2024 under forward sale agreements outstanding because their effect would have been antidilutive. The calculation of diluted earnings per share excluded 1,304,889 shares for the six months ended June 30, 2025 and 2,942,440 shares for the six months ended June 30, 2024 under forward sale agreements outstanding because their effect would have been antidilutive.

Entergy’s stock options and other equity compensation plans are discussed in Note 5 to the financial statements herein and in Note 12 to the financial statements in the Form 10-K.

Dividends declared per common share were $0.60 for the three months ended June 30, 2025 and $0.57 for the three months ended June 30, 2024. Dividends declared per common share were $1.20 for the six months ended June 30, 2025 and $1.13 for the six months ended June 30, 2024.

(System Energy)

In February 2025, System Energy paid its parent, Entergy Corporation, a $20 million distribution out of its common stock.

In May 2025, System Energy paid its parent, Entergy Corporation, a $30 million distribution out of its common stock.

Equity Distribution Program

See Note 7 to the financial statements in the Form 10-K for discussion of Entergy Corporation’s at the market equity distribution program. The following are updates to that discussion.

In February 2025, Entergy Corporation increased by an additional $1.5 billion the aggregate gross sales price authorized under its at the market equity distribution program pursuant to the terms of the equity distribution sales agreement for such program. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $4.5 billion. As of June 30, 2025, an aggregate gross sales price of approximately $2.8 billion has been sold under the at the market equity distribution program.

During the six months ended June 30, 2025 and 2024, there were no shares of common stock directly issued under the at the market equity distribution program.
The following forward sale agreements were entered into by Entergy Corporation under its at the market equity distribution program during the six months ended June 30, 2025:
Effective DateShares of Common Stock per Forward Sale AgreementMaturity DateForward Sale Price per ShareGross Sales PriceForward Sellers Fees
(Dollars In Thousands, Except Per Share Data)
March 20252,713,790 August 2026$84.77 $232,216 $2,322 

During the six months ended June 30, 2025, Entergy Corporation physically settled its obligations under the following forward sale agreements:
Effective Date of Forward Sale Agreements
Shares of Common Stock Issued
Gross Sales PriceForward Sellers FeesForward Sale Price per ShareCash Proceeds at Settlement
(Dollars In Thousands, Except Per Share Data)
Forward sale agreements settled in May 2025:
December 20235,506,492 $280,459 $2,805 
March 2024569,844 $29,318 $293 
March 20242,320,830 $119,153 $1,192 
May 20242,556,832 $142,387 $1,424 
May 20242,466,470 $134,396 $1,344 
June 20242,140,006 $114,540 $1,145 
Total15,560,474 $51.78 $805,669 

Entergy Corporation incurred an aggregate amount of approximately $1.0 million of general issuance costs associated with the May 2025 settlement. Entergy Corporation used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy Corporation’s revolving credit facility, and other debt.

Equity Forward Sale Agreements

In March 2025, Entergy marketed an equity offering of 17.8 million shares of Entergy Corporation common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with several forward counterparties. No amounts have been or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlements of the forward sale agreements occur. The forward sale agreements require Entergy to, at its election on or prior to September 30, 2026, either (1) physically settle the transactions by issuing the total of 17.8 million shares of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially $81.87 per share) or (2) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreements.

Until settlement of the forward sale agreements, earnings per share dilution resulting from the agreements, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Entergy’s common stock is higher than the average forward sales price. If Entergy had elected to net share settle the forward sale agreements as of June 30, 2025, Entergy would have been required to deliver 0.2 million shares.
Treasury Stock

During the six months ended June 30, 2025, Entergy Corporation reissued 1,268,179 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards.  Entergy Corporation did not repurchase any of its common stock during the six months ended June 30, 2025.

Retained Earnings

On July 25, 2025, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.60 per share, payable on September 2, 2025 to holders of record as of August 13, 2025.

Comprehensive Income

Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 30, 2025 and 2024:
Pension and Other Postretirement Plan Changes
20252024
(In Thousands)
Beginning balance, April 1,$39,040 ($166,128)
Amounts reclassified from accumulated other comprehensive income (loss)(4,602)246,489 
Net other comprehensive income (loss) for the period(4,602)246,489 
Ending balance, June 30,$34,438 $80,361 

The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2025 and 2024:
Pension and Other Postretirement Plan Changes
20252024
(In Thousands)
Beginning balance, January 1,$42,769 ($162,460)
Amounts reclassified from accumulated other comprehensive income (loss)
(8,331)242,821 
Net other comprehensive income (loss) for the period(8,331)242,821 
Ending balance, June 30,$34,438 $80,361 
The following table presents changes in accumulated other comprehensive income for Entergy Louisiana for the three months ended June 30, 2025 and 2024:
Pension and Other Postretirement Plan Changes
20252024
(In Thousands)
Beginning balance, April 1,$52,687 $52,774 
Amounts reclassified from accumulated other comprehensive income(2,132)(2,023)
Net other comprehensive loss for the period(2,132)(2,023)
Ending balance, June 30,$50,555 $50,751 

The following table presents changes in accumulated other comprehensive income for Entergy Louisiana for the six months ended June 30, 2025 and 2024:
Pension and Other Postretirement Plan Changes
20252024
(In Thousands)
Beginning balance, January 1,$53,658 $54,798 
Amounts reclassified from accumulated other comprehensive income(3,103)(4,047)
Net other comprehensive loss for the period(3,103)(4,047)
Ending balance, June 30,$50,555 $50,751 

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended June 30, 2025 and 2024 are as follows:
Amounts reclassified from AOCIIncome Statement Location
20252024
(In Thousands)
Pension and other postretirement plan changes
   Amortization of prior service credit$3,462 $3,473 (a)
   Amortization of net gain2,551 1,641 (a)
   Settlement loss— (316,974)(a)
Total amortization and settlement loss6,013 (311,860)
Income taxes(1,411)65,371 Income taxes
Total amortization and settlement loss (net of tax)$4,602 ($246,489)
Total reclassifications for the period (net of tax)$4,602 ($246,489)

(a)These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.
Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the six months ended June 30, 2025 and 2024 are as follows:
Amounts reclassified from AOCIIncome Statement Location
20252024
(In Thousands)
Pension and other postretirement plan changes
   Amortization of prior service credit$6,924 $6,946 (a)
   Amortization of net gain5,102 3,037 (a)
   Settlement loss— (316,974)(a)
Total amortization and settlement loss12,026 (306,991)
Income taxes(3,695)64,170 Income taxes
Total amortization and settlement loss (net of tax)
$8,331 ($242,821)
Total reclassifications for the period (net of tax)$8,331 ($242,821)

(a)These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.

Total reclassifications out of accumulated other comprehensive income (AOCI) for Entergy Louisiana for the three months ended June 30, 2025 and 2024 are as follows:
Amounts reclassified from AOCIIncome Statement Location
20252024
(In Thousands)
Pension and other postretirement plan changes
   Amortization of prior service credit$1,136 $1,136 (a)
   Amortization of net gain1,719 1,632 (a)
Total amortization2,855 2,768 
Income taxes(723)(745)Income taxes
Total amortization (net of tax)
2,132 2,023 
Total reclassifications for the period (net of tax)$2,132 $2,023 

(a)These accumulated other comprehensive income components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.
Total reclassifications out of accumulated other comprehensive income (AOCI) for Entergy Louisiana for the six months ended June 30, 2025 and 2024 are as follows:
Amounts reclassified from AOCIIncome Statement Location
20252024
(In Thousands)
Pension and other postretirement plan changes
   Amortization of prior service credit$2,272 $2,272 (a)
   Amortization of net gain3,438 3,266 (a)
Total amortization
5,710 5,538 
Income taxes(2,607)(1,491)Income taxes
Total amortization (net of tax)
$3,103 $4,047 
Total reclassifications for the period (net of tax)$3,103 $4,047 

(a)These accumulated other comprehensive income components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.
Entergy Louisiana [Member]  
Equity [Text Block] EQUITY (Entergy Corporation and Entergy Louisiana)
Common Stock

Earnings per Share

Historical share and share-based data presented in the accompanying financial statements has been retroactively adjusted to reflect the two-for-one forward stock split of Entergy Corporation common stock effective December 12, 2024. See Note 7 to the financial statements in the Form 10-K for discussion of the stock split.

The following tables present Entergy’s basic and diluted earnings per share calculations for the three and six months ended June 30, 2025 and 2024, included on the consolidated income statements:
For the Three Months Ended June 30,
20252024
(Dollars In Thousands, Except Per Share Data; Shares in Millions)
$/share$/share
Consolidated net income$471,954 $51,732 
Less: Preferred dividend requirements of subsidiaries and noncontrolling interests4,024 2,810 
Net income attributable to Entergy Corporation$467,930 $48,922 
Basic shares and earnings per average common share439.2 $1.07 427.2 $0.11 
Average dilutive effect of:
Stock options0.9 — 0.6 — 
Other equity plans1.2 — 1.0 — 
Equity forwards4.4 (0.02)— — 
Diluted shares and earnings per average common share445.7 $1.05 428.8 $0.11 

For the Six Months Ended June 30,
20252024
(Dollars In Thousands, Except Per Share Data; Shares in Millions)
$/share$/share
Consolidated net income$834,376 $128,268 
Less: Preferred dividend requirements of subsidiaries and noncontrolling interests5,686 4,065 
Net income attributable to Entergy Corporation$828,690 $124,203 
Basic shares and earnings per average common share434.8 $1.91 426.8 $0.29 
Average dilutive effect of:
Stock options1.0 — 0.5 — 
Other equity plans1.3 (0.01)1.0 — 
Equity forwards6.3 (0.03)— — 
Diluted shares and earnings per average common share443.4 $1.87 428.3 $0.29 

Earnings per share dilution resulting from stock options outstanding and other equity plans is determined under the treasury stock method. The calculation of diluted earnings per share excluded 366,136 stock options
outstanding for the three months ended June 30, 2025 and 1,448,982 stock options outstanding for the three months ended June 30, 2024 because their effect would have been antidilutive. The calculation of diluted earnings per share excluded 305,113 stock options outstanding for the six months ended June 30, 2025 and 1,471,220 stock options outstanding for the six months ended June 30, 2024 because their effect would have been antidilutive. Until settlement of the forward sale agreements discussed below in “Equity Distribution Program” and “Equity Forward Sale Agreements,” earnings per share dilution resulting from the agreements, if any, is determined under the treasury stock method. Share dilution occurs when the average market price of Entergy Corporation’s common stock is higher than the average forward sales price. The calculation of diluted earnings per share excluded 2,423,880 shares for the three months ended June 30, 2025 and 2,897,964 shares for the three months ended June 30, 2024 under forward sale agreements outstanding because their effect would have been antidilutive. The calculation of diluted earnings per share excluded 1,304,889 shares for the six months ended June 30, 2025 and 2,942,440 shares for the six months ended June 30, 2024 under forward sale agreements outstanding because their effect would have been antidilutive.

Entergy’s stock options and other equity compensation plans are discussed in Note 5 to the financial statements herein and in Note 12 to the financial statements in the Form 10-K.

Dividends declared per common share were $0.60 for the three months ended June 30, 2025 and $0.57 for the three months ended June 30, 2024. Dividends declared per common share were $1.20 for the six months ended June 30, 2025 and $1.13 for the six months ended June 30, 2024.

(System Energy)

In February 2025, System Energy paid its parent, Entergy Corporation, a $20 million distribution out of its common stock.

In May 2025, System Energy paid its parent, Entergy Corporation, a $30 million distribution out of its common stock.

Equity Distribution Program

See Note 7 to the financial statements in the Form 10-K for discussion of Entergy Corporation’s at the market equity distribution program. The following are updates to that discussion.

In February 2025, Entergy Corporation increased by an additional $1.5 billion the aggregate gross sales price authorized under its at the market equity distribution program pursuant to the terms of the equity distribution sales agreement for such program. The aggregate number of shares of common stock sold under this sales agreement and under any forward sale agreement may not exceed an aggregate gross sales price of $4.5 billion. As of June 30, 2025, an aggregate gross sales price of approximately $2.8 billion has been sold under the at the market equity distribution program.

During the six months ended June 30, 2025 and 2024, there were no shares of common stock directly issued under the at the market equity distribution program.
The following forward sale agreements were entered into by Entergy Corporation under its at the market equity distribution program during the six months ended June 30, 2025:
Effective DateShares of Common Stock per Forward Sale AgreementMaturity DateForward Sale Price per ShareGross Sales PriceForward Sellers Fees
(Dollars In Thousands, Except Per Share Data)
March 20252,713,790 August 2026$84.77 $232,216 $2,322 

During the six months ended June 30, 2025, Entergy Corporation physically settled its obligations under the following forward sale agreements:
Effective Date of Forward Sale Agreements
Shares of Common Stock Issued
Gross Sales PriceForward Sellers FeesForward Sale Price per ShareCash Proceeds at Settlement
(Dollars In Thousands, Except Per Share Data)
Forward sale agreements settled in May 2025:
December 20235,506,492 $280,459 $2,805 
March 2024569,844 $29,318 $293 
March 20242,320,830 $119,153 $1,192 
May 20242,556,832 $142,387 $1,424 
May 20242,466,470 $134,396 $1,344 
June 20242,140,006 $114,540 $1,145 
Total15,560,474 $51.78 $805,669 

Entergy Corporation incurred an aggregate amount of approximately $1.0 million of general issuance costs associated with the May 2025 settlement. Entergy Corporation used the net proceeds for general corporate purposes, which included repayment of commercial paper, outstanding loans under Entergy Corporation’s revolving credit facility, and other debt.

Equity Forward Sale Agreements

In March 2025, Entergy marketed an equity offering of 17.8 million shares of Entergy Corporation common stock. In lieu of issuing equity at the time of the offering, Entergy entered into forward sale agreements with several forward counterparties. No amounts have been or will be recorded on Entergy’s balance sheet with respect to the equity offering until settlements of the forward sale agreements occur. The forward sale agreements require Entergy to, at its election on or prior to September 30, 2026, either (1) physically settle the transactions by issuing the total of 17.8 million shares of its common stock to the forward counterparties in exchange for net proceeds at the then-applicable forward sale price specified by the agreements (initially $81.87 per share) or (2) net settle the transactions in whole or in part through the delivery or receipt of cash or shares. The forward sale price is subject to adjustment on a daily basis based on a floating interest rate factor and will decrease by other fixed amounts specified in the agreements.

Until settlement of the forward sale agreements, earnings per share dilution resulting from the agreements, if any, will be determined under the treasury stock method. Share dilution occurs when the average market price of Entergy’s common stock is higher than the average forward sales price. If Entergy had elected to net share settle the forward sale agreements as of June 30, 2025, Entergy would have been required to deliver 0.2 million shares.
Treasury Stock

During the six months ended June 30, 2025, Entergy Corporation reissued 1,268,179 shares of its previously repurchased common stock to satisfy stock option exercises, vesting of shares of restricted stock, and other stock-based awards.  Entergy Corporation did not repurchase any of its common stock during the six months ended June 30, 2025.

Retained Earnings

On July 25, 2025, Entergy Corporation’s Board of Directors declared a common stock dividend of $0.60 per share, payable on September 2, 2025 to holders of record as of August 13, 2025.

Comprehensive Income

Accumulated other comprehensive income (loss) is included in the equity section of the balance sheets of Entergy and Entergy Louisiana. The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 30, 2025 and 2024:
Pension and Other Postretirement Plan Changes
20252024
(In Thousands)
Beginning balance, April 1,$39,040 ($166,128)
Amounts reclassified from accumulated other comprehensive income (loss)(4,602)246,489 
Net other comprehensive income (loss) for the period(4,602)246,489 
Ending balance, June 30,$34,438 $80,361 

The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2025 and 2024:
Pension and Other Postretirement Plan Changes
20252024
(In Thousands)
Beginning balance, January 1,$42,769 ($162,460)
Amounts reclassified from accumulated other comprehensive income (loss)
(8,331)242,821 
Net other comprehensive income (loss) for the period(8,331)242,821 
Ending balance, June 30,$34,438 $80,361 
The following table presents changes in accumulated other comprehensive income for Entergy Louisiana for the three months ended June 30, 2025 and 2024:
Pension and Other Postretirement Plan Changes
20252024
(In Thousands)
Beginning balance, April 1,$52,687 $52,774 
Amounts reclassified from accumulated other comprehensive income(2,132)(2,023)
Net other comprehensive loss for the period(2,132)(2,023)
Ending balance, June 30,$50,555 $50,751 

The following table presents changes in accumulated other comprehensive income for Entergy Louisiana for the six months ended June 30, 2025 and 2024:
Pension and Other Postretirement Plan Changes
20252024
(In Thousands)
Beginning balance, January 1,$53,658 $54,798 
Amounts reclassified from accumulated other comprehensive income(3,103)(4,047)
Net other comprehensive loss for the period(3,103)(4,047)
Ending balance, June 30,$50,555 $50,751 

Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended June 30, 2025 and 2024 are as follows:
Amounts reclassified from AOCIIncome Statement Location
20252024
(In Thousands)
Pension and other postretirement plan changes
   Amortization of prior service credit$3,462 $3,473 (a)
   Amortization of net gain2,551 1,641 (a)
   Settlement loss— (316,974)(a)
Total amortization and settlement loss6,013 (311,860)
Income taxes(1,411)65,371 Income taxes
Total amortization and settlement loss (net of tax)$4,602 ($246,489)
Total reclassifications for the period (net of tax)$4,602 ($246,489)

(a)These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.
Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the six months ended June 30, 2025 and 2024 are as follows:
Amounts reclassified from AOCIIncome Statement Location
20252024
(In Thousands)
Pension and other postretirement plan changes
   Amortization of prior service credit$6,924 $6,946 (a)
   Amortization of net gain5,102 3,037 (a)
   Settlement loss— (316,974)(a)
Total amortization and settlement loss12,026 (306,991)
Income taxes(3,695)64,170 Income taxes
Total amortization and settlement loss (net of tax)
$8,331 ($242,821)
Total reclassifications for the period (net of tax)$8,331 ($242,821)

(a)These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.

Total reclassifications out of accumulated other comprehensive income (AOCI) for Entergy Louisiana for the three months ended June 30, 2025 and 2024 are as follows:
Amounts reclassified from AOCIIncome Statement Location
20252024
(In Thousands)
Pension and other postretirement plan changes
   Amortization of prior service credit$1,136 $1,136 (a)
   Amortization of net gain1,719 1,632 (a)
Total amortization2,855 2,768 
Income taxes(723)(745)Income taxes
Total amortization (net of tax)
2,132 2,023 
Total reclassifications for the period (net of tax)$2,132 $2,023 

(a)These accumulated other comprehensive income components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.
Total reclassifications out of accumulated other comprehensive income (AOCI) for Entergy Louisiana for the six months ended June 30, 2025 and 2024 are as follows:
Amounts reclassified from AOCIIncome Statement Location
20252024
(In Thousands)
Pension and other postretirement plan changes
   Amortization of prior service credit$2,272 $2,272 (a)
   Amortization of net gain3,438 3,266 (a)
Total amortization
5,710 5,538 
Income taxes(2,607)(1,491)Income taxes
Total amortization (net of tax)
$3,103 $4,047 
Total reclassifications for the period (net of tax)$3,103 $4,047 

(a)These accumulated other comprehensive income components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.
v3.25.2
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt
 6 Months Ended
Jun. 30, 2025
Debt Disclosure [Text Block] REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy Corporation has in place a credit facility that has a borrowing capacity of $3 billion and expires in June 2030. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  As there were no borrowings under the facility for the six months ended June 30, 2025, the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility was 5.93%. The following is a summary of the amounts outstanding and capacity available under the credit facility as of June 30, 2025:
Capacity BorrowingsLetters
of Credit		Capacity
Available
(In Millions)
$3,000$—$4$2,996

Entergy Corporation’s credit facility includes a covenant requiring Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Registrant Subsidiaries (except Entergy New Orleans and System Energy) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur.

Entergy Corporation has a commercial paper program with a Board-approved program limit of $2 billion.  As of June 30, 2025, Entergy Corporation had $459 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2025 was 4.65%.
Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2025 as follows:
CompanyExpiration
Date		Amount of
Facility		Interest Rate
(a)		Amount Drawn
as of
June 30, 2025		Letters of Credit
Outstanding as of
June 30, 2025
Entergy ArkansasApril 2026$25 million (b)6.28%$—$—
Entergy ArkansasJune 2030$300 million (c)5.55%$—$—
Entergy LouisianaJune 2030$400 million (c)5.68%$—$—
Entergy MississippiJune 2030$300 million (c)5.55%$—$—
Entergy New OrleansJune 2027$25 million (c)6.05%$—$—
Entergy TexasJune 2030$300 million (c)5.68%$—$1.1 million

(a)The interest rate is the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility.
(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.
(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $5 million for Entergy Mississippi; $10 million for Entergy New Orleans; and $25 million for Entergy Texas.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO and for other purposes. In July 2025, Entergy Texas entered into a second uncommitted standby letter of credit facility in the amount of $160 million with a letter of credit fee of 1.05%. The following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2025:
CompanyAmount of
Uncommitted Facility		Letter of Credit Fee
Letters of Credit
Issued as of
June 30, 2025
(a)
Entergy Arkansas$25 million0.78%$23.6 million
Entergy Arkansas
$75 million0.50%$—
Entergy Louisiana$125 million 0.78%$74.3 million
Entergy Louisiana
$45 million 0.50%$—
Entergy Mississippi$65 million0.78%$47.3 million (b)
Entergy Mississippi
$65 million0.50%$—
Entergy New Orleans$1 million1.625%$0.5 million
Entergy Texas$150 million1.250%$54.0 million

(a)As of June 30, 2025, letters of credit posted with MISO covered financial transmission rights exposure of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.6 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
(b)As of June 30, 2025, the letters of credit issued for Entergy Mississippi include $46.0 million in MISO letters of credit and $1.3 million in non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy have FERC-authorized short-term borrowing limits effective through January 2027. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy system money pool and from other internal short-term borrowing arrangements.  The money pool is an intercompany cash management program that makes possible intercompany borrowing and lending arrangements, and the money pool and the other internal borrowing arrangements are designed to reduce the Registrant Subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2025 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
 AuthorizedBorrowings
 (In Millions)
Entergy Arkansas$250$—
Entergy Louisiana $450 $—
Entergy Mississippi$200$—
Entergy New Orleans$150$21
Entergy Texas$200$—
System Energy$200$—

Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of June 30, 2025:
CompanyExpiration
Date 		Amount
of
Facility		Weighted-
 Average Interest
 Rate on
 Borrowings (a)		Amount
Outstanding as of
June 30, 2025
(Dollars in Millions)
Entergy Arkansas VIEJune 2027$805.44%$33.2
Entergy Louisiana River Bend VIEJune 2027$1055.42%$69.5
Entergy Louisiana Waterford VIEJune 2027$1055.43%$61.0
System Energy VIEJune 2027$1205.43%$44.3

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant.
The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of June 30, 2025 as follows:
CompanyDescriptionAmount
Entergy Arkansas VIE
1.84% Series N due July 2026
$90 million
Entergy Arkansas VIE
5.54% Series O due May 2029
$70 million
Entergy Louisiana River Bend VIE
2.51% Series V due June 2027
$70 million
Entergy Louisiana Waterford VIE
5.94% Series J due September 2026
$70 million
System Energy VIE
2.05% Series K due September 2027
$90 million

In accordance with regulatory treatment, interest on the nuclear fuel company VIEs’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.

As of June 30, 2025, Entergy Arkansas, Entergy Louisiana, and System Energy each has obtained financing authorization from the FERC that extends through January 2027 for issuances by its nuclear fuel company VIEs.

Debt Issuances and Retirements

(Entergy Arkansas)

In May 2025, Entergy Arkansas issued $300 million of 5.45% Series mortgage bonds due June 2034. Entergy Arkansas expects to use the proceeds, together with other funds, to finance the construction of Lake Catherine Unit 5, and for general corporate purposes.

(Entergy Louisiana)

In January 2025, Entergy Louisiana issued $750 million of 5.80% Series mortgage bonds due March 2055. Entergy Louisiana used the proceeds, together with other funds: (1) to repay, prior to maturity, its $190 million of 3.78% Series mortgage bonds due April 2025; (2) to repay, prior to maturity, its $110 million of 3.78% Series mortgage bonds due April 2025; (3) for capital expenditures; and (4) for general corporate purposes.

(Entergy Mississippi)

In March 2025, Entergy Mississippi issued $600 million of 5.80% Series mortgage bonds due April 2055. Entergy Mississippi expects to use the proceeds, together with other funds, to finance a portion of the construction of the Delta Blues Advanced Power Station, the Delta Solar facility, and the Penton Solar facility, and for general corporate purposes.

(Entergy New Orleans)

In February 2025, Entergy New Orleans entered into a term loan credit agreement providing a $80 million unsecured term loan due March 2026. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable adjustment. The rate set as of June 30, 2025 was 5.79%. Entergy New Orleans received the funds in March 2025 and used the proceeds to repay, at maturity, its $78 million of 3.00% Series mortgage bonds due March 2025 and for general corporate purposes. The term loan was subsequently repaid, prior to its maturity, in July 2025.

(Entergy Texas)

In February 2025, Entergy Texas issued $500 million of 5.25% Series mortgage bonds due April 2035. Entergy Texas expects to use the proceeds, together with other funds, to finance the construction of the Orange County Advanced Power Station and the Lone Star Power Station, and for general corporate purposes.
(System Energy)

In May 2025, System Energy issued $240 million of 5.30% Series mortgage bonds due December 2034. System Energy used the proceeds, together with other funds, to repay, prior to maturity, its $200 million of 2.14% Series mortgage bonds due December 2025, and for general corporate purposes.

Fair Value

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2025 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$29,929,838 $27,487,432 
Entergy Arkansas$5,438,033 $4,883,114 
Entergy Louisiana$10,399,823 $9,410,962 
Entergy Mississippi$3,020,687 $2,720,374 
Entergy New Orleans$737,560 $697,241 
Entergy Texas$4,038,417 $3,729,255 
System Energy$1,094,396 $1,101,434 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2024 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$27,991,595 $25,181,802 
Entergy Arkansas$5,122,494 $4,546,643 
Entergy Louisiana$9,866,453 $8,751,266 
Entergy Mississippi$2,427,073 $2,116,246 
Entergy New Orleans$735,467 $697,466 
Entergy Texas$3,552,443 $3,176,230 
System Energy$1,089,736 $1,063,946 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Arkansas [Member]  
Debt Disclosure [Text Block] REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy Corporation has in place a credit facility that has a borrowing capacity of $3 billion and expires in June 2030. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  As there were no borrowings under the facility for the six months ended June 30, 2025, the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility was 5.93%. The following is a summary of the amounts outstanding and capacity available under the credit facility as of June 30, 2025:
Capacity BorrowingsLetters
of Credit		Capacity
Available
(In Millions)
$3,000$—$4$2,996

Entergy Corporation’s credit facility includes a covenant requiring Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Registrant Subsidiaries (except Entergy New Orleans and System Energy) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur.

Entergy Corporation has a commercial paper program with a Board-approved program limit of $2 billion.  As of June 30, 2025, Entergy Corporation had $459 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2025 was 4.65%.
Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2025 as follows:
CompanyExpiration
Date		Amount of
Facility		Interest Rate
(a)		Amount Drawn
as of
June 30, 2025		Letters of Credit
Outstanding as of
June 30, 2025
Entergy ArkansasApril 2026$25 million (b)6.28%$—$—
Entergy ArkansasJune 2030$300 million (c)5.55%$—$—
Entergy LouisianaJune 2030$400 million (c)5.68%$—$—
Entergy MississippiJune 2030$300 million (c)5.55%$—$—
Entergy New OrleansJune 2027$25 million (c)6.05%$—$—
Entergy TexasJune 2030$300 million (c)5.68%$—$1.1 million

(a)The interest rate is the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility.
(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.
(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $5 million for Entergy Mississippi; $10 million for Entergy New Orleans; and $25 million for Entergy Texas.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO and for other purposes. In July 2025, Entergy Texas entered into a second uncommitted standby letter of credit facility in the amount of $160 million with a letter of credit fee of 1.05%. The following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2025:
CompanyAmount of
Uncommitted Facility		Letter of Credit Fee
Letters of Credit
Issued as of
June 30, 2025
(a)
Entergy Arkansas$25 million0.78%$23.6 million
Entergy Arkansas
$75 million0.50%$—
Entergy Louisiana$125 million 0.78%$74.3 million
Entergy Louisiana
$45 million 0.50%$—
Entergy Mississippi$65 million0.78%$47.3 million (b)
Entergy Mississippi
$65 million0.50%$—
Entergy New Orleans$1 million1.625%$0.5 million
Entergy Texas$150 million1.250%$54.0 million

(a)As of June 30, 2025, letters of credit posted with MISO covered financial transmission rights exposure of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.6 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
(b)As of June 30, 2025, the letters of credit issued for Entergy Mississippi include $46.0 million in MISO letters of credit and $1.3 million in non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy have FERC-authorized short-term borrowing limits effective through January 2027. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy system money pool and from other internal short-term borrowing arrangements.  The money pool is an intercompany cash management program that makes possible intercompany borrowing and lending arrangements, and the money pool and the other internal borrowing arrangements are designed to reduce the Registrant Subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2025 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
 AuthorizedBorrowings
 (In Millions)
Entergy Arkansas$250$—
Entergy Louisiana $450 $—
Entergy Mississippi$200$—
Entergy New Orleans$150$21
Entergy Texas$200$—
System Energy$200$—

Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of June 30, 2025:
CompanyExpiration
Date 		Amount
of
Facility		Weighted-
 Average Interest
 Rate on
 Borrowings (a)		Amount
Outstanding as of
June 30, 2025
(Dollars in Millions)
Entergy Arkansas VIEJune 2027$805.44%$33.2
Entergy Louisiana River Bend VIEJune 2027$1055.42%$69.5
Entergy Louisiana Waterford VIEJune 2027$1055.43%$61.0
System Energy VIEJune 2027$1205.43%$44.3

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant.
The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of June 30, 2025 as follows:
CompanyDescriptionAmount
Entergy Arkansas VIE
1.84% Series N due July 2026
$90 million
Entergy Arkansas VIE
5.54% Series O due May 2029
$70 million
Entergy Louisiana River Bend VIE
2.51% Series V due June 2027
$70 million
Entergy Louisiana Waterford VIE
5.94% Series J due September 2026
$70 million
System Energy VIE
2.05% Series K due September 2027
$90 million

In accordance with regulatory treatment, interest on the nuclear fuel company VIEs’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.

As of June 30, 2025, Entergy Arkansas, Entergy Louisiana, and System Energy each has obtained financing authorization from the FERC that extends through January 2027 for issuances by its nuclear fuel company VIEs.

Debt Issuances and Retirements

(Entergy Arkansas)

In May 2025, Entergy Arkansas issued $300 million of 5.45% Series mortgage bonds due June 2034. Entergy Arkansas expects to use the proceeds, together with other funds, to finance the construction of Lake Catherine Unit 5, and for general corporate purposes.

(Entergy Louisiana)

In January 2025, Entergy Louisiana issued $750 million of 5.80% Series mortgage bonds due March 2055. Entergy Louisiana used the proceeds, together with other funds: (1) to repay, prior to maturity, its $190 million of 3.78% Series mortgage bonds due April 2025; (2) to repay, prior to maturity, its $110 million of 3.78% Series mortgage bonds due April 2025; (3) for capital expenditures; and (4) for general corporate purposes.

(Entergy Mississippi)

In March 2025, Entergy Mississippi issued $600 million of 5.80% Series mortgage bonds due April 2055. Entergy Mississippi expects to use the proceeds, together with other funds, to finance a portion of the construction of the Delta Blues Advanced Power Station, the Delta Solar facility, and the Penton Solar facility, and for general corporate purposes.

(Entergy New Orleans)

In February 2025, Entergy New Orleans entered into a term loan credit agreement providing a $80 million unsecured term loan due March 2026. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable adjustment. The rate set as of June 30, 2025 was 5.79%. Entergy New Orleans received the funds in March 2025 and used the proceeds to repay, at maturity, its $78 million of 3.00% Series mortgage bonds due March 2025 and for general corporate purposes. The term loan was subsequently repaid, prior to its maturity, in July 2025.

(Entergy Texas)

In February 2025, Entergy Texas issued $500 million of 5.25% Series mortgage bonds due April 2035. Entergy Texas expects to use the proceeds, together with other funds, to finance the construction of the Orange County Advanced Power Station and the Lone Star Power Station, and for general corporate purposes.
(System Energy)

In May 2025, System Energy issued $240 million of 5.30% Series mortgage bonds due December 2034. System Energy used the proceeds, together with other funds, to repay, prior to maturity, its $200 million of 2.14% Series mortgage bonds due December 2025, and for general corporate purposes.

Fair Value

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2025 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$29,929,838 $27,487,432 
Entergy Arkansas$5,438,033 $4,883,114 
Entergy Louisiana$10,399,823 $9,410,962 
Entergy Mississippi$3,020,687 $2,720,374 
Entergy New Orleans$737,560 $697,241 
Entergy Texas$4,038,417 $3,729,255 
System Energy$1,094,396 $1,101,434 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2024 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$27,991,595 $25,181,802 
Entergy Arkansas$5,122,494 $4,546,643 
Entergy Louisiana$9,866,453 $8,751,266 
Entergy Mississippi$2,427,073 $2,116,246 
Entergy New Orleans$735,467 $697,466 
Entergy Texas$3,552,443 $3,176,230 
System Energy$1,089,736 $1,063,946 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Louisiana [Member]  
Debt Disclosure [Text Block] REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy Corporation has in place a credit facility that has a borrowing capacity of $3 billion and expires in June 2030. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  As there were no borrowings under the facility for the six months ended June 30, 2025, the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility was 5.93%. The following is a summary of the amounts outstanding and capacity available under the credit facility as of June 30, 2025:
Capacity BorrowingsLetters
of Credit		Capacity
Available
(In Millions)
$3,000$—$4$2,996

Entergy Corporation’s credit facility includes a covenant requiring Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Registrant Subsidiaries (except Entergy New Orleans and System Energy) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur.

Entergy Corporation has a commercial paper program with a Board-approved program limit of $2 billion.  As of June 30, 2025, Entergy Corporation had $459 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2025 was 4.65%.
Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2025 as follows:
CompanyExpiration
Date		Amount of
Facility		Interest Rate
(a)		Amount Drawn
as of
June 30, 2025		Letters of Credit
Outstanding as of
June 30, 2025
Entergy ArkansasApril 2026$25 million (b)6.28%$—$—
Entergy ArkansasJune 2030$300 million (c)5.55%$—$—
Entergy LouisianaJune 2030$400 million (c)5.68%$—$—
Entergy MississippiJune 2030$300 million (c)5.55%$—$—
Entergy New OrleansJune 2027$25 million (c)6.05%$—$—
Entergy TexasJune 2030$300 million (c)5.68%$—$1.1 million

(a)The interest rate is the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility.
(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.
(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $5 million for Entergy Mississippi; $10 million for Entergy New Orleans; and $25 million for Entergy Texas.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO and for other purposes. In July 2025, Entergy Texas entered into a second uncommitted standby letter of credit facility in the amount of $160 million with a letter of credit fee of 1.05%. The following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2025:
CompanyAmount of
Uncommitted Facility		Letter of Credit Fee
Letters of Credit
Issued as of
June 30, 2025
(a)
Entergy Arkansas$25 million0.78%$23.6 million
Entergy Arkansas
$75 million0.50%$—
Entergy Louisiana$125 million 0.78%$74.3 million
Entergy Louisiana
$45 million 0.50%$—
Entergy Mississippi$65 million0.78%$47.3 million (b)
Entergy Mississippi
$65 million0.50%$—
Entergy New Orleans$1 million1.625%$0.5 million
Entergy Texas$150 million1.250%$54.0 million

(a)As of June 30, 2025, letters of credit posted with MISO covered financial transmission rights exposure of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.6 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
(b)As of June 30, 2025, the letters of credit issued for Entergy Mississippi include $46.0 million in MISO letters of credit and $1.3 million in non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy have FERC-authorized short-term borrowing limits effective through January 2027. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy system money pool and from other internal short-term borrowing arrangements.  The money pool is an intercompany cash management program that makes possible intercompany borrowing and lending arrangements, and the money pool and the other internal borrowing arrangements are designed to reduce the Registrant Subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2025 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
 AuthorizedBorrowings
 (In Millions)
Entergy Arkansas$250$—
Entergy Louisiana $450 $—
Entergy Mississippi$200$—
Entergy New Orleans$150$21
Entergy Texas$200$—
System Energy$200$—

Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of June 30, 2025:
CompanyExpiration
Date 		Amount
of
Facility		Weighted-
 Average Interest
 Rate on
 Borrowings (a)		Amount
Outstanding as of
June 30, 2025
(Dollars in Millions)
Entergy Arkansas VIEJune 2027$805.44%$33.2
Entergy Louisiana River Bend VIEJune 2027$1055.42%$69.5
Entergy Louisiana Waterford VIEJune 2027$1055.43%$61.0
System Energy VIEJune 2027$1205.43%$44.3

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant.
The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of June 30, 2025 as follows:
CompanyDescriptionAmount
Entergy Arkansas VIE
1.84% Series N due July 2026
$90 million
Entergy Arkansas VIE
5.54% Series O due May 2029
$70 million
Entergy Louisiana River Bend VIE
2.51% Series V due June 2027
$70 million
Entergy Louisiana Waterford VIE
5.94% Series J due September 2026
$70 million
System Energy VIE
2.05% Series K due September 2027
$90 million

In accordance with regulatory treatment, interest on the nuclear fuel company VIEs’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.

As of June 30, 2025, Entergy Arkansas, Entergy Louisiana, and System Energy each has obtained financing authorization from the FERC that extends through January 2027 for issuances by its nuclear fuel company VIEs.

Debt Issuances and Retirements

(Entergy Arkansas)

In May 2025, Entergy Arkansas issued $300 million of 5.45% Series mortgage bonds due June 2034. Entergy Arkansas expects to use the proceeds, together with other funds, to finance the construction of Lake Catherine Unit 5, and for general corporate purposes.

(Entergy Louisiana)

In January 2025, Entergy Louisiana issued $750 million of 5.80% Series mortgage bonds due March 2055. Entergy Louisiana used the proceeds, together with other funds: (1) to repay, prior to maturity, its $190 million of 3.78% Series mortgage bonds due April 2025; (2) to repay, prior to maturity, its $110 million of 3.78% Series mortgage bonds due April 2025; (3) for capital expenditures; and (4) for general corporate purposes.

(Entergy Mississippi)

In March 2025, Entergy Mississippi issued $600 million of 5.80% Series mortgage bonds due April 2055. Entergy Mississippi expects to use the proceeds, together with other funds, to finance a portion of the construction of the Delta Blues Advanced Power Station, the Delta Solar facility, and the Penton Solar facility, and for general corporate purposes.

(Entergy New Orleans)

In February 2025, Entergy New Orleans entered into a term loan credit agreement providing a $80 million unsecured term loan due March 2026. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable adjustment. The rate set as of June 30, 2025 was 5.79%. Entergy New Orleans received the funds in March 2025 and used the proceeds to repay, at maturity, its $78 million of 3.00% Series mortgage bonds due March 2025 and for general corporate purposes. The term loan was subsequently repaid, prior to its maturity, in July 2025.

(Entergy Texas)

In February 2025, Entergy Texas issued $500 million of 5.25% Series mortgage bonds due April 2035. Entergy Texas expects to use the proceeds, together with other funds, to finance the construction of the Orange County Advanced Power Station and the Lone Star Power Station, and for general corporate purposes.
(System Energy)

In May 2025, System Energy issued $240 million of 5.30% Series mortgage bonds due December 2034. System Energy used the proceeds, together with other funds, to repay, prior to maturity, its $200 million of 2.14% Series mortgage bonds due December 2025, and for general corporate purposes.

Fair Value

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2025 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$29,929,838 $27,487,432 
Entergy Arkansas$5,438,033 $4,883,114 
Entergy Louisiana$10,399,823 $9,410,962 
Entergy Mississippi$3,020,687 $2,720,374 
Entergy New Orleans$737,560 $697,241 
Entergy Texas$4,038,417 $3,729,255 
System Energy$1,094,396 $1,101,434 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2024 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$27,991,595 $25,181,802 
Entergy Arkansas$5,122,494 $4,546,643 
Entergy Louisiana$9,866,453 $8,751,266 
Entergy Mississippi$2,427,073 $2,116,246 
Entergy New Orleans$735,467 $697,466 
Entergy Texas$3,552,443 $3,176,230 
System Energy$1,089,736 $1,063,946 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Mississippi [Member]  
Debt Disclosure [Text Block] REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy Corporation has in place a credit facility that has a borrowing capacity of $3 billion and expires in June 2030. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  As there were no borrowings under the facility for the six months ended June 30, 2025, the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility was 5.93%. The following is a summary of the amounts outstanding and capacity available under the credit facility as of June 30, 2025:
Capacity BorrowingsLetters
of Credit		Capacity
Available
(In Millions)
$3,000$—$4$2,996

Entergy Corporation’s credit facility includes a covenant requiring Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Registrant Subsidiaries (except Entergy New Orleans and System Energy) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur.

Entergy Corporation has a commercial paper program with a Board-approved program limit of $2 billion.  As of June 30, 2025, Entergy Corporation had $459 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2025 was 4.65%.
Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2025 as follows:
CompanyExpiration
Date		Amount of
Facility		Interest Rate
(a)		Amount Drawn
as of
June 30, 2025		Letters of Credit
Outstanding as of
June 30, 2025
Entergy ArkansasApril 2026$25 million (b)6.28%$—$—
Entergy ArkansasJune 2030$300 million (c)5.55%$—$—
Entergy LouisianaJune 2030$400 million (c)5.68%$—$—
Entergy MississippiJune 2030$300 million (c)5.55%$—$—
Entergy New OrleansJune 2027$25 million (c)6.05%$—$—
Entergy TexasJune 2030$300 million (c)5.68%$—$1.1 million

(a)The interest rate is the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility.
(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.
(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $5 million for Entergy Mississippi; $10 million for Entergy New Orleans; and $25 million for Entergy Texas.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO and for other purposes. In July 2025, Entergy Texas entered into a second uncommitted standby letter of credit facility in the amount of $160 million with a letter of credit fee of 1.05%. The following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2025:
CompanyAmount of
Uncommitted Facility		Letter of Credit Fee
Letters of Credit
Issued as of
June 30, 2025
(a)
Entergy Arkansas$25 million0.78%$23.6 million
Entergy Arkansas
$75 million0.50%$—
Entergy Louisiana$125 million 0.78%$74.3 million
Entergy Louisiana
$45 million 0.50%$—
Entergy Mississippi$65 million0.78%$47.3 million (b)
Entergy Mississippi
$65 million0.50%$—
Entergy New Orleans$1 million1.625%$0.5 million
Entergy Texas$150 million1.250%$54.0 million

(a)As of June 30, 2025, letters of credit posted with MISO covered financial transmission rights exposure of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.6 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
(b)As of June 30, 2025, the letters of credit issued for Entergy Mississippi include $46.0 million in MISO letters of credit and $1.3 million in non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy have FERC-authorized short-term borrowing limits effective through January 2027. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy system money pool and from other internal short-term borrowing arrangements.  The money pool is an intercompany cash management program that makes possible intercompany borrowing and lending arrangements, and the money pool and the other internal borrowing arrangements are designed to reduce the Registrant Subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2025 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
 AuthorizedBorrowings
 (In Millions)
Entergy Arkansas$250$—
Entergy Louisiana $450 $—
Entergy Mississippi$200$—
Entergy New Orleans$150$21
Entergy Texas$200$—
System Energy$200$—

Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of June 30, 2025:
CompanyExpiration
Date 		Amount
of
Facility		Weighted-
 Average Interest
 Rate on
 Borrowings (a)		Amount
Outstanding as of
June 30, 2025
(Dollars in Millions)
Entergy Arkansas VIEJune 2027$805.44%$33.2
Entergy Louisiana River Bend VIEJune 2027$1055.42%$69.5
Entergy Louisiana Waterford VIEJune 2027$1055.43%$61.0
System Energy VIEJune 2027$1205.43%$44.3

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant.
The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of June 30, 2025 as follows:
CompanyDescriptionAmount
Entergy Arkansas VIE
1.84% Series N due July 2026
$90 million
Entergy Arkansas VIE
5.54% Series O due May 2029
$70 million
Entergy Louisiana River Bend VIE
2.51% Series V due June 2027
$70 million
Entergy Louisiana Waterford VIE
5.94% Series J due September 2026
$70 million
System Energy VIE
2.05% Series K due September 2027
$90 million

In accordance with regulatory treatment, interest on the nuclear fuel company VIEs’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.

As of June 30, 2025, Entergy Arkansas, Entergy Louisiana, and System Energy each has obtained financing authorization from the FERC that extends through January 2027 for issuances by its nuclear fuel company VIEs.

Debt Issuances and Retirements

(Entergy Arkansas)

In May 2025, Entergy Arkansas issued $300 million of 5.45% Series mortgage bonds due June 2034. Entergy Arkansas expects to use the proceeds, together with other funds, to finance the construction of Lake Catherine Unit 5, and for general corporate purposes.

(Entergy Louisiana)

In January 2025, Entergy Louisiana issued $750 million of 5.80% Series mortgage bonds due March 2055. Entergy Louisiana used the proceeds, together with other funds: (1) to repay, prior to maturity, its $190 million of 3.78% Series mortgage bonds due April 2025; (2) to repay, prior to maturity, its $110 million of 3.78% Series mortgage bonds due April 2025; (3) for capital expenditures; and (4) for general corporate purposes.

(Entergy Mississippi)

In March 2025, Entergy Mississippi issued $600 million of 5.80% Series mortgage bonds due April 2055. Entergy Mississippi expects to use the proceeds, together with other funds, to finance a portion of the construction of the Delta Blues Advanced Power Station, the Delta Solar facility, and the Penton Solar facility, and for general corporate purposes.

(Entergy New Orleans)

In February 2025, Entergy New Orleans entered into a term loan credit agreement providing a $80 million unsecured term loan due March 2026. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable adjustment. The rate set as of June 30, 2025 was 5.79%. Entergy New Orleans received the funds in March 2025 and used the proceeds to repay, at maturity, its $78 million of 3.00% Series mortgage bonds due March 2025 and for general corporate purposes. The term loan was subsequently repaid, prior to its maturity, in July 2025.

(Entergy Texas)

In February 2025, Entergy Texas issued $500 million of 5.25% Series mortgage bonds due April 2035. Entergy Texas expects to use the proceeds, together with other funds, to finance the construction of the Orange County Advanced Power Station and the Lone Star Power Station, and for general corporate purposes.
(System Energy)

In May 2025, System Energy issued $240 million of 5.30% Series mortgage bonds due December 2034. System Energy used the proceeds, together with other funds, to repay, prior to maturity, its $200 million of 2.14% Series mortgage bonds due December 2025, and for general corporate purposes.

Fair Value

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2025 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$29,929,838 $27,487,432 
Entergy Arkansas$5,438,033 $4,883,114 
Entergy Louisiana$10,399,823 $9,410,962 
Entergy Mississippi$3,020,687 $2,720,374 
Entergy New Orleans$737,560 $697,241 
Entergy Texas$4,038,417 $3,729,255 
System Energy$1,094,396 $1,101,434 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2024 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$27,991,595 $25,181,802 
Entergy Arkansas$5,122,494 $4,546,643 
Entergy Louisiana$9,866,453 $8,751,266 
Entergy Mississippi$2,427,073 $2,116,246 
Entergy New Orleans$735,467 $697,466 
Entergy Texas$3,552,443 $3,176,230 
System Energy$1,089,736 $1,063,946 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy New Orleans [Member]  
Debt Disclosure [Text Block] REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy Corporation has in place a credit facility that has a borrowing capacity of $3 billion and expires in June 2030. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  As there were no borrowings under the facility for the six months ended June 30, 2025, the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility was 5.93%. The following is a summary of the amounts outstanding and capacity available under the credit facility as of June 30, 2025:
Capacity BorrowingsLetters
of Credit		Capacity
Available
(In Millions)
$3,000$—$4$2,996

Entergy Corporation’s credit facility includes a covenant requiring Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Registrant Subsidiaries (except Entergy New Orleans and System Energy) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur.

Entergy Corporation has a commercial paper program with a Board-approved program limit of $2 billion.  As of June 30, 2025, Entergy Corporation had $459 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2025 was 4.65%.
Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2025 as follows:
CompanyExpiration
Date		Amount of
Facility		Interest Rate
(a)		Amount Drawn
as of
June 30, 2025		Letters of Credit
Outstanding as of
June 30, 2025
Entergy ArkansasApril 2026$25 million (b)6.28%$—$—
Entergy ArkansasJune 2030$300 million (c)5.55%$—$—
Entergy LouisianaJune 2030$400 million (c)5.68%$—$—
Entergy MississippiJune 2030$300 million (c)5.55%$—$—
Entergy New OrleansJune 2027$25 million (c)6.05%$—$—
Entergy TexasJune 2030$300 million (c)5.68%$—$1.1 million

(a)The interest rate is the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility.
(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.
(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $5 million for Entergy Mississippi; $10 million for Entergy New Orleans; and $25 million for Entergy Texas.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO and for other purposes. In July 2025, Entergy Texas entered into a second uncommitted standby letter of credit facility in the amount of $160 million with a letter of credit fee of 1.05%. The following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2025:
CompanyAmount of
Uncommitted Facility		Letter of Credit Fee
Letters of Credit
Issued as of
June 30, 2025
(a)
Entergy Arkansas$25 million0.78%$23.6 million
Entergy Arkansas
$75 million0.50%$—
Entergy Louisiana$125 million 0.78%$74.3 million
Entergy Louisiana
$45 million 0.50%$—
Entergy Mississippi$65 million0.78%$47.3 million (b)
Entergy Mississippi
$65 million0.50%$—
Entergy New Orleans$1 million1.625%$0.5 million
Entergy Texas$150 million1.250%$54.0 million

(a)As of June 30, 2025, letters of credit posted with MISO covered financial transmission rights exposure of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.6 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
(b)As of June 30, 2025, the letters of credit issued for Entergy Mississippi include $46.0 million in MISO letters of credit and $1.3 million in non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy have FERC-authorized short-term borrowing limits effective through January 2027. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy system money pool and from other internal short-term borrowing arrangements.  The money pool is an intercompany cash management program that makes possible intercompany borrowing and lending arrangements, and the money pool and the other internal borrowing arrangements are designed to reduce the Registrant Subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2025 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
 AuthorizedBorrowings
 (In Millions)
Entergy Arkansas$250$—
Entergy Louisiana $450 $—
Entergy Mississippi$200$—
Entergy New Orleans$150$21
Entergy Texas$200$—
System Energy$200$—

Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of June 30, 2025:
CompanyExpiration
Date 		Amount
of
Facility		Weighted-
 Average Interest
 Rate on
 Borrowings (a)		Amount
Outstanding as of
June 30, 2025
(Dollars in Millions)
Entergy Arkansas VIEJune 2027$805.44%$33.2
Entergy Louisiana River Bend VIEJune 2027$1055.42%$69.5
Entergy Louisiana Waterford VIEJune 2027$1055.43%$61.0
System Energy VIEJune 2027$1205.43%$44.3

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant.
The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of June 30, 2025 as follows:
CompanyDescriptionAmount
Entergy Arkansas VIE
1.84% Series N due July 2026
$90 million
Entergy Arkansas VIE
5.54% Series O due May 2029
$70 million
Entergy Louisiana River Bend VIE
2.51% Series V due June 2027
$70 million
Entergy Louisiana Waterford VIE
5.94% Series J due September 2026
$70 million
System Energy VIE
2.05% Series K due September 2027
$90 million

In accordance with regulatory treatment, interest on the nuclear fuel company VIEs’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.

As of June 30, 2025, Entergy Arkansas, Entergy Louisiana, and System Energy each has obtained financing authorization from the FERC that extends through January 2027 for issuances by its nuclear fuel company VIEs.

Debt Issuances and Retirements

(Entergy Arkansas)

In May 2025, Entergy Arkansas issued $300 million of 5.45% Series mortgage bonds due June 2034. Entergy Arkansas expects to use the proceeds, together with other funds, to finance the construction of Lake Catherine Unit 5, and for general corporate purposes.

(Entergy Louisiana)

In January 2025, Entergy Louisiana issued $750 million of 5.80% Series mortgage bonds due March 2055. Entergy Louisiana used the proceeds, together with other funds: (1) to repay, prior to maturity, its $190 million of 3.78% Series mortgage bonds due April 2025; (2) to repay, prior to maturity, its $110 million of 3.78% Series mortgage bonds due April 2025; (3) for capital expenditures; and (4) for general corporate purposes.

(Entergy Mississippi)

In March 2025, Entergy Mississippi issued $600 million of 5.80% Series mortgage bonds due April 2055. Entergy Mississippi expects to use the proceeds, together with other funds, to finance a portion of the construction of the Delta Blues Advanced Power Station, the Delta Solar facility, and the Penton Solar facility, and for general corporate purposes.

(Entergy New Orleans)

In February 2025, Entergy New Orleans entered into a term loan credit agreement providing a $80 million unsecured term loan due March 2026. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable adjustment. The rate set as of June 30, 2025 was 5.79%. Entergy New Orleans received the funds in March 2025 and used the proceeds to repay, at maturity, its $78 million of 3.00% Series mortgage bonds due March 2025 and for general corporate purposes. The term loan was subsequently repaid, prior to its maturity, in July 2025.

(Entergy Texas)

In February 2025, Entergy Texas issued $500 million of 5.25% Series mortgage bonds due April 2035. Entergy Texas expects to use the proceeds, together with other funds, to finance the construction of the Orange County Advanced Power Station and the Lone Star Power Station, and for general corporate purposes.
(System Energy)

In May 2025, System Energy issued $240 million of 5.30% Series mortgage bonds due December 2034. System Energy used the proceeds, together with other funds, to repay, prior to maturity, its $200 million of 2.14% Series mortgage bonds due December 2025, and for general corporate purposes.

Fair Value

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2025 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$29,929,838 $27,487,432 
Entergy Arkansas$5,438,033 $4,883,114 
Entergy Louisiana$10,399,823 $9,410,962 
Entergy Mississippi$3,020,687 $2,720,374 
Entergy New Orleans$737,560 $697,241 
Entergy Texas$4,038,417 $3,729,255 
System Energy$1,094,396 $1,101,434 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2024 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$27,991,595 $25,181,802 
Entergy Arkansas$5,122,494 $4,546,643 
Entergy Louisiana$9,866,453 $8,751,266 
Entergy Mississippi$2,427,073 $2,116,246 
Entergy New Orleans$735,467 $697,466 
Entergy Texas$3,552,443 $3,176,230 
System Energy$1,089,736 $1,063,946 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Texas [Member]  
Debt Disclosure [Text Block] REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy Corporation has in place a credit facility that has a borrowing capacity of $3 billion and expires in June 2030. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  As there were no borrowings under the facility for the six months ended June 30, 2025, the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility was 5.93%. The following is a summary of the amounts outstanding and capacity available under the credit facility as of June 30, 2025:
Capacity BorrowingsLetters
of Credit		Capacity
Available
(In Millions)
$3,000$—$4$2,996

Entergy Corporation’s credit facility includes a covenant requiring Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Registrant Subsidiaries (except Entergy New Orleans and System Energy) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur.

Entergy Corporation has a commercial paper program with a Board-approved program limit of $2 billion.  As of June 30, 2025, Entergy Corporation had $459 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2025 was 4.65%.
Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2025 as follows:
CompanyExpiration
Date		Amount of
Facility		Interest Rate
(a)		Amount Drawn
as of
June 30, 2025		Letters of Credit
Outstanding as of
June 30, 2025
Entergy ArkansasApril 2026$25 million (b)6.28%$—$—
Entergy ArkansasJune 2030$300 million (c)5.55%$—$—
Entergy LouisianaJune 2030$400 million (c)5.68%$—$—
Entergy MississippiJune 2030$300 million (c)5.55%$—$—
Entergy New OrleansJune 2027$25 million (c)6.05%$—$—
Entergy TexasJune 2030$300 million (c)5.68%$—$1.1 million

(a)The interest rate is the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility.
(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.
(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $5 million for Entergy Mississippi; $10 million for Entergy New Orleans; and $25 million for Entergy Texas.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO and for other purposes. In July 2025, Entergy Texas entered into a second uncommitted standby letter of credit facility in the amount of $160 million with a letter of credit fee of 1.05%. The following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2025:
CompanyAmount of
Uncommitted Facility		Letter of Credit Fee
Letters of Credit
Issued as of
June 30, 2025
(a)
Entergy Arkansas$25 million0.78%$23.6 million
Entergy Arkansas
$75 million0.50%$—
Entergy Louisiana$125 million 0.78%$74.3 million
Entergy Louisiana
$45 million 0.50%$—
Entergy Mississippi$65 million0.78%$47.3 million (b)
Entergy Mississippi
$65 million0.50%$—
Entergy New Orleans$1 million1.625%$0.5 million
Entergy Texas$150 million1.250%$54.0 million

(a)As of June 30, 2025, letters of credit posted with MISO covered financial transmission rights exposure of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.6 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
(b)As of June 30, 2025, the letters of credit issued for Entergy Mississippi include $46.0 million in MISO letters of credit and $1.3 million in non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy have FERC-authorized short-term borrowing limits effective through January 2027. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy system money pool and from other internal short-term borrowing arrangements.  The money pool is an intercompany cash management program that makes possible intercompany borrowing and lending arrangements, and the money pool and the other internal borrowing arrangements are designed to reduce the Registrant Subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2025 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
 AuthorizedBorrowings
 (In Millions)
Entergy Arkansas$250$—
Entergy Louisiana $450 $—
Entergy Mississippi$200$—
Entergy New Orleans$150$21
Entergy Texas$200$—
System Energy$200$—

Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of June 30, 2025:
CompanyExpiration
Date 		Amount
of
Facility		Weighted-
 Average Interest
 Rate on
 Borrowings (a)		Amount
Outstanding as of
June 30, 2025
(Dollars in Millions)
Entergy Arkansas VIEJune 2027$805.44%$33.2
Entergy Louisiana River Bend VIEJune 2027$1055.42%$69.5
Entergy Louisiana Waterford VIEJune 2027$1055.43%$61.0
System Energy VIEJune 2027$1205.43%$44.3

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant.
The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of June 30, 2025 as follows:
CompanyDescriptionAmount
Entergy Arkansas VIE
1.84% Series N due July 2026
$90 million
Entergy Arkansas VIE
5.54% Series O due May 2029
$70 million
Entergy Louisiana River Bend VIE
2.51% Series V due June 2027
$70 million
Entergy Louisiana Waterford VIE
5.94% Series J due September 2026
$70 million
System Energy VIE
2.05% Series K due September 2027
$90 million

In accordance with regulatory treatment, interest on the nuclear fuel company VIEs’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.

As of June 30, 2025, Entergy Arkansas, Entergy Louisiana, and System Energy each has obtained financing authorization from the FERC that extends through January 2027 for issuances by its nuclear fuel company VIEs.

Debt Issuances and Retirements

(Entergy Arkansas)

In May 2025, Entergy Arkansas issued $300 million of 5.45% Series mortgage bonds due June 2034. Entergy Arkansas expects to use the proceeds, together with other funds, to finance the construction of Lake Catherine Unit 5, and for general corporate purposes.

(Entergy Louisiana)

In January 2025, Entergy Louisiana issued $750 million of 5.80% Series mortgage bonds due March 2055. Entergy Louisiana used the proceeds, together with other funds: (1) to repay, prior to maturity, its $190 million of 3.78% Series mortgage bonds due April 2025; (2) to repay, prior to maturity, its $110 million of 3.78% Series mortgage bonds due April 2025; (3) for capital expenditures; and (4) for general corporate purposes.

(Entergy Mississippi)

In March 2025, Entergy Mississippi issued $600 million of 5.80% Series mortgage bonds due April 2055. Entergy Mississippi expects to use the proceeds, together with other funds, to finance a portion of the construction of the Delta Blues Advanced Power Station, the Delta Solar facility, and the Penton Solar facility, and for general corporate purposes.

(Entergy New Orleans)

In February 2025, Entergy New Orleans entered into a term loan credit agreement providing a $80 million unsecured term loan due March 2026. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable adjustment. The rate set as of June 30, 2025 was 5.79%. Entergy New Orleans received the funds in March 2025 and used the proceeds to repay, at maturity, its $78 million of 3.00% Series mortgage bonds due March 2025 and for general corporate purposes. The term loan was subsequently repaid, prior to its maturity, in July 2025.

(Entergy Texas)

In February 2025, Entergy Texas issued $500 million of 5.25% Series mortgage bonds due April 2035. Entergy Texas expects to use the proceeds, together with other funds, to finance the construction of the Orange County Advanced Power Station and the Lone Star Power Station, and for general corporate purposes.
(System Energy)

In May 2025, System Energy issued $240 million of 5.30% Series mortgage bonds due December 2034. System Energy used the proceeds, together with other funds, to repay, prior to maturity, its $200 million of 2.14% Series mortgage bonds due December 2025, and for general corporate purposes.

Fair Value

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2025 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$29,929,838 $27,487,432 
Entergy Arkansas$5,438,033 $4,883,114 
Entergy Louisiana$10,399,823 $9,410,962 
Entergy Mississippi$3,020,687 $2,720,374 
Entergy New Orleans$737,560 $697,241 
Entergy Texas$4,038,417 $3,729,255 
System Energy$1,094,396 $1,101,434 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2024 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$27,991,595 $25,181,802 
Entergy Arkansas$5,122,494 $4,546,643 
Entergy Louisiana$9,866,453 $8,751,266 
Entergy Mississippi$2,427,073 $2,116,246 
Entergy New Orleans$735,467 $697,466 
Entergy Texas$3,552,443 $3,176,230 
System Energy$1,089,736 $1,063,946 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
System Energy [Member]  
Debt Disclosure [Text Block] REVOLVING CREDIT FACILITIES, LINES OF CREDIT, SHORT-TERM BORROWINGS, AND LONG-TERM DEBT (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy Corporation has in place a credit facility that has a borrowing capacity of $3 billion and expires in June 2030. The facility includes fronting commitments for the issuance of letters of credit against $20 million of the total borrowing capacity of the credit facility. The commitment fee is currently 0.225% of the undrawn commitment amount. Commitment fees and interest rates on loans under the credit facility can fluctuate depending on the senior unsecured debt ratings of Entergy Corporation.  As there were no borrowings under the facility for the six months ended June 30, 2025, the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility was 5.93%. The following is a summary of the amounts outstanding and capacity available under the credit facility as of June 30, 2025:
Capacity BorrowingsLetters
of Credit		Capacity
Available
(In Millions)
$3,000$—$4$2,996

Entergy Corporation’s credit facility includes a covenant requiring Entergy to maintain a consolidated debt ratio, as defined, of 65% or less of its total capitalization. Entergy is in compliance with this covenant. If Entergy fails to meet this ratio, or if Entergy Corporation or one of the Registrant Subsidiaries (except Entergy New Orleans and System Energy) defaults on other indebtedness or is in bankruptcy or insolvency proceedings, an acceleration of the Entergy Corporation credit facility’s maturity date may occur.

Entergy Corporation has a commercial paper program with a Board-approved program limit of $2 billion.  As of June 30, 2025, Entergy Corporation had $459 million of commercial paper outstanding. The weighted-average interest rate for the six months ended June 30, 2025 was 4.65%.
Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2025 as follows:
CompanyExpiration
Date		Amount of
Facility		Interest Rate
(a)		Amount Drawn
as of
June 30, 2025		Letters of Credit
Outstanding as of
June 30, 2025
Entergy ArkansasApril 2026$25 million (b)6.28%$—$—
Entergy ArkansasJune 2030$300 million (c)5.55%$—$—
Entergy LouisianaJune 2030$400 million (c)5.68%$—$—
Entergy MississippiJune 2030$300 million (c)5.55%$—$—
Entergy New OrleansJune 2027$25 million (c)6.05%$—$—
Entergy TexasJune 2030$300 million (c)5.68%$—$1.1 million

(a)The interest rate is the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility.
(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.
(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $5 million for Entergy Mississippi; $10 million for Entergy New Orleans; and $25 million for Entergy Texas.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization.  Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has one or more uncommitted standby letter of credit facilities as a means to post collateral to support its obligations to MISO and for other purposes. In July 2025, Entergy Texas entered into a second uncommitted standby letter of credit facility in the amount of $160 million with a letter of credit fee of 1.05%. The following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2025:
CompanyAmount of
Uncommitted Facility		Letter of Credit Fee
Letters of Credit
Issued as of
June 30, 2025
(a)
Entergy Arkansas$25 million0.78%$23.6 million
Entergy Arkansas
$75 million0.50%$—
Entergy Louisiana$125 million 0.78%$74.3 million
Entergy Louisiana
$45 million 0.50%$—
Entergy Mississippi$65 million0.78%$47.3 million (b)
Entergy Mississippi
$65 million0.50%$—
Entergy New Orleans$1 million1.625%$0.5 million
Entergy Texas$150 million1.250%$54.0 million

(a)As of June 30, 2025, letters of credit posted with MISO covered financial transmission rights exposure of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.6 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
(b)As of June 30, 2025, the letters of credit issued for Entergy Mississippi include $46.0 million in MISO letters of credit and $1.3 million in non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy have FERC-authorized short-term borrowing limits effective through January 2027. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy system money pool and from other internal short-term borrowing arrangements.  The money pool is an intercompany cash management program that makes possible intercompany borrowing and lending arrangements, and the money pool and the other internal borrowing arrangements are designed to reduce the Registrant Subsidiaries’ dependence on external short-term borrowings.  Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2025 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
 AuthorizedBorrowings
 (In Millions)
Entergy Arkansas$250$—
Entergy Louisiana $450 $—
Entergy Mississippi$200$—
Entergy New Orleans$150$21
Entergy Texas$200$—
System Energy$200$—

Variable Interest Entities (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)

See Note 17 to the financial statements in the Form 10-K for a discussion of the consolidation of the nuclear fuel company variable interest entities (VIEs).  To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of June 30, 2025:
CompanyExpiration
Date 		Amount
of
Facility		Weighted-
 Average Interest
 Rate on
 Borrowings (a)		Amount
Outstanding as of
June 30, 2025
(Dollars in Millions)
Entergy Arkansas VIEJune 2027$805.44%$33.2
Entergy Louisiana River Bend VIEJune 2027$1055.42%$69.5
Entergy Louisiana Waterford VIEJune 2027$1055.43%$61.0
System Energy VIEJune 2027$1205.43%$44.3

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

The commitment fees on the credit facilities are 0.100% of the undrawn commitment amount for the Entergy Arkansas, Entergy Louisiana, and System Energy VIEs.  Each credit facility requires the respective lessee of nuclear fuel (Entergy Arkansas, Entergy Louisiana, or Entergy Corporation as guarantor for System Energy) to maintain a consolidated debt ratio, as defined, of 70% or less of its total capitalization. Each lessee is in compliance with this covenant.
The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of June 30, 2025 as follows:
CompanyDescriptionAmount
Entergy Arkansas VIE
1.84% Series N due July 2026
$90 million
Entergy Arkansas VIE
5.54% Series O due May 2029
$70 million
Entergy Louisiana River Bend VIE
2.51% Series V due June 2027
$70 million
Entergy Louisiana Waterford VIE
5.94% Series J due September 2026
$70 million
System Energy VIE
2.05% Series K due September 2027
$90 million

In accordance with regulatory treatment, interest on the nuclear fuel company VIEs’ credit facilities, commercial paper, and long-term notes payable is reported in fuel expense.

As of June 30, 2025, Entergy Arkansas, Entergy Louisiana, and System Energy each has obtained financing authorization from the FERC that extends through January 2027 for issuances by its nuclear fuel company VIEs.

Debt Issuances and Retirements

(Entergy Arkansas)

In May 2025, Entergy Arkansas issued $300 million of 5.45% Series mortgage bonds due June 2034. Entergy Arkansas expects to use the proceeds, together with other funds, to finance the construction of Lake Catherine Unit 5, and for general corporate purposes.

(Entergy Louisiana)

In January 2025, Entergy Louisiana issued $750 million of 5.80% Series mortgage bonds due March 2055. Entergy Louisiana used the proceeds, together with other funds: (1) to repay, prior to maturity, its $190 million of 3.78% Series mortgage bonds due April 2025; (2) to repay, prior to maturity, its $110 million of 3.78% Series mortgage bonds due April 2025; (3) for capital expenditures; and (4) for general corporate purposes.

(Entergy Mississippi)

In March 2025, Entergy Mississippi issued $600 million of 5.80% Series mortgage bonds due April 2055. Entergy Mississippi expects to use the proceeds, together with other funds, to finance a portion of the construction of the Delta Blues Advanced Power Station, the Delta Solar facility, and the Penton Solar facility, and for general corporate purposes.

(Entergy New Orleans)

In February 2025, Entergy New Orleans entered into a term loan credit agreement providing a $80 million unsecured term loan due March 2026. The term loan bears interest at a variable interest rate based on an adjusted term Secured Overnight Financing Rate plus the applicable adjustment. The rate set as of June 30, 2025 was 5.79%. Entergy New Orleans received the funds in March 2025 and used the proceeds to repay, at maturity, its $78 million of 3.00% Series mortgage bonds due March 2025 and for general corporate purposes. The term loan was subsequently repaid, prior to its maturity, in July 2025.

(Entergy Texas)

In February 2025, Entergy Texas issued $500 million of 5.25% Series mortgage bonds due April 2035. Entergy Texas expects to use the proceeds, together with other funds, to finance the construction of the Orange County Advanced Power Station and the Lone Star Power Station, and for general corporate purposes.
(System Energy)

In May 2025, System Energy issued $240 million of 5.30% Series mortgage bonds due December 2034. System Energy used the proceeds, together with other funds, to repay, prior to maturity, its $200 million of 2.14% Series mortgage bonds due December 2025, and for general corporate purposes.

Fair Value

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2025 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$29,929,838 $27,487,432 
Entergy Arkansas$5,438,033 $4,883,114 
Entergy Louisiana$10,399,823 $9,410,962 
Entergy Mississippi$3,020,687 $2,720,374 
Entergy New Orleans$737,560 $697,241 
Entergy Texas$4,038,417 $3,729,255 
System Energy$1,094,396 $1,101,434 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2024 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$27,991,595 $25,181,802 
Entergy Arkansas$5,122,494 $4,546,643 
Entergy Louisiana$9,866,453 $8,751,266 
Entergy Mississippi$2,427,073 $2,116,246 
Entergy New Orleans$735,467 $697,466 
Entergy Texas$3,552,443 $3,176,230 
System Energy$1,089,736 $1,063,946 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
v3.25.2
Stock-Based Compensation
 6 Months Ended
Jun. 30, 2025
Share-Based Payment Arrangement [Text Block] STOCK-BASED COMPENSATION (Entergy Corporation)
Entergy grants stock and stock-based awards, which are described more fully in Note 12 to the financial statements in the Form 10-K.  Awards under Entergy’s plans generally vest over three years.

Stock Options

In February 2025 the Board approved and Entergy granted long-term incentive awards in the form of options on 366,136 shares of its common stock under the 2019 Omnibus Incentive Plan with a fair value of $17.43 per option.  As of June 30, 2025, there were options on 3,132,728 shares of common stock outstanding with a weighted-average exercise price of $56.71.  The intrinsic value, which has no effect on net income, of the outstanding stock options is calculated by the positive difference between the weighted-average exercise price of the stock options granted and Entergy Corporation’s common stock price as of June 30, 2025.  The aggregate intrinsic value of the stock options outstanding as of June 30, 2025 was $78.6 million.

The following table includes financial information for stock options for the three months ended June 30, 2025 and 2024:
20252024
(In Millions)
Compensation expense included in Entergy’s consolidated net income$1.0 $1.1 
Tax benefit recognized in Entergy’s consolidated net income$0.2 $0.3 
Compensation cost capitalized as part of fixed assets and materials and supplies$0.5 $0.5 

The following table includes financial information for stock options for the six months ended June 30, 2025 and 2024:
20252024
(In Millions)
Compensation expense included in Entergy’s consolidated net income$2.1 $2.2 
Tax benefit recognized in Entergy’s consolidated net income$0.5 $0.6 
Compensation cost capitalized as part of fixed assets and materials and supplies$1.0 $1.0 

Other Equity Awards

In February 2025 the Board approved and Entergy granted long-term incentive awards in the form of 510,009 restricted stock awards and 187,036 performance units under the 2019 Omnibus Incentive Plan.  The restricted stock awards were made effective on February 6, 2025 and were valued at $82.79 per share, which was the closing price of Entergy Corporation’s common stock on the grant date.  Shares of restricted stock have the same dividend and voting rights as other common stock, are considered issued and outstanding shares of Entergy upon vesting, and are expensed ratably over the three-year vesting period. One-third of the restricted stock awards and accrued dividends will vest upon each anniversary of the grant date.

The performance units represent the value of, and are settled with, one share of Entergy Corporation common stock at the end of the three-year performance period, plus dividends accrued during the performance period on the number of performance units earned. To emphasize the importance of environmental stewardship, specifically of carbon-free generation and resilience, an environmental achievement measure was selected as one of the performance measures for the 2025-2027 performance period. For the 2025-2027 performance period, performance will be measured based eighty percent on relative total shareholder return and twenty percent on the environmental achievement measure.  The performance units were granted on February 6, 2025 and eighty percent
were valued at $115.13 per share based on various factors, primarily market conditions; and twenty percent were valued at $82.79 per share, the closing price of Entergy Corporation’s common stock on the grant date.  Performance units have the same dividend and voting rights as other common stock, are considered issued and outstanding shares of Entergy upon vesting, and are expensed ratably over the three-year vesting period, and compensation cost for the portion of the award based on the selected environmental achievement measure will be adjusted based on the number of units that ultimately vest. See Note 12 to the financial statements in the Form 10-K for a description of the Long-Term Performance Unit Program.

The following table includes financial information for other outstanding equity awards for the three months ended June 30, 2025 and 2024:
20252024
(In Millions)
Compensation expense included in Entergy’s consolidated net income$9.4 $9.8 
Tax benefit recognized in Entergy’s consolidated net income$2.3 $2.5 
Compensation cost capitalized as part of fixed assets and materials and supplies$4.7 $4.6 

The following table includes financial information for other equity awards for the six months ended June 30, 2025 and 2024:
20252024
(In Millions)
Compensation expense included in Entergy’s consolidated net income$19.4 $19.7 
Tax benefit recognized in Entergy’s consolidated net income$4.8 $5.0 
Compensation cost capitalized as part of fixed assets and materials and supplies$9.5 $9.1 
v3.25.2
Retirement And Other Postretirement Benefits
 6 Months Ended
Jun. 30, 2025
Retirement Benefits [Text Block] RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Components of Qualified Net Pension Cost

Entergy’s qualified pension costs, including amounts capitalized, for the second quarters of 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$23,617 $23,370 
Interest cost on projected benefit obligation59,680 65,961 
Expected return on assets(75,280)(89,506)
Recognized net loss13,309 14,854 
Settlement charges— 325,253 
Net pension cost$21,326 $339,932 
Entergy’s qualified pension costs, including amounts capitalized, for the six months ended June 30, 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$47,234 $46,746 
Interest cost on projected benefit obligation119,360 136,587 
Expected return on assets(150,560)(185,486)
Recognized net loss26,618 29,974 
Settlement charges— 325,253 
Net pension cost$42,652 $353,074 

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,427 $5,454 $1,304 $411 $1,024 $1,372 
Interest cost on projected benefit obligation13,814 14,704 3,699 1,647 2,973 3,585 
Expected return on assets(17,676)(18,897)(4,949)(2,174)(3,889)(4,575)
Recognized net loss4,791 2,268 822 415 454 1,114 
Net pension cost$5,356 $3,529 $876 $299 $562 $1,496 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,100 $5,551 $1,284 $440 $962 $1,383 
Interest cost on projected benefit obligation13,217 13,961 3,521 1,569 2,831 3,386 
Expected return on assets(18,155)(19,447)(5,113)(2,203)(4,077)(4,633)
Recognized net loss5,746 2,602 1,140 470 393 1,162 
Settlement charges— — — — — 611 
Net pension cost$4,908 $2,667 $832 $276 $109 $1,909 
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,854 $10,908 $2,608 $822 $2,048 $2,744 
Interest cost on projected benefit obligation27,628 29,408 7,398 3,294 5,946 7,170 
Expected return on assets(35,352)(37,794)(9,898)(4,348)(7,778)(9,150)
Recognized net loss9,582 4,536 1,644 830 908 2,228 
Net pension cost$10,712 $7,058 $1,752 $598 $1,124 $2,992 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,199 $11,102 $2,568 $880 $1,923 $2,767 
Interest cost on projected benefit obligation26,434 27,922 7,042 3,138 5,662 6,777 
Expected return on assets(36,310)(38,894)(10,226)(4,407)(8,154)(9,281)
Recognized net loss11,492 5,204 2,280 940 786 2,327 
Settlement charges— — — — — 611 
Net pension cost$9,815 $5,334 $1,664 $551 $217 $3,201 

Non-Qualified Net Pension Cost

Entergy recognized $2.5 million and $2.7 million in pension cost for its non-qualified pension plans for the second quarters of 2025 and 2024, respectively. For the second quarters of 2025 and 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Entergy recognized $5 million and $5.4 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2025 and 2024, respectively. For the six months ended June 30, 2025 and 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan.

The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for second quarters of 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$47 $36 $90 $35 $39 
2024$68 $51 $83 $31 $62 
The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$94 $72 $180 $70 $78 
2024$136 $102 $166 $61 $124 

For the second quarters of 2025 and 2024, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sums benefits out of the plan. For the six months ended June 30, 2025 and 2024 there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan.

Components of Net Other Postretirement Benefits Income

Entergy’s other postretirement benefits income, including amounts capitalized, for the second quarters of 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$2,757 $3,126 
Interest cost on accumulated postretirement benefit obligation (APBO)9,690 9,852 
Expected return on assets(10,209)(10,569)
Amortization of prior service credit(5,720)(5,720)
Recognized net gain(3,870)(2,761)
Net other postretirement benefits income($7,352)($6,072)

Entergy’s other postretirement benefits income, including amounts capitalized, for the six months ended June 30, 2025 and 2024, included the following components:
 20252024
 (In Thousands)
Service cost - benefits earned during the period$5,514 $6,252 
Interest cost on APBO
19,380 19,704 
Expected return on assets(20,418)(21,138)
Amortization of prior service credit(11,440)(11,440)
Recognized net gain(7,740)(5,522)
Net other postretirement benefits income($14,704)($12,144)
The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$572 $671 $162 $52 $159 $174 
Interest cost on APBO1,775 2,012 489 249 582 394 
Expected return on assets(4,225)— (1,328)(1,445)(2,452)(702)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss(353)(1,811)(57)(27)153 (7)
Net other postretirement benefits income($1,707)($264)($973)($1,400)($2,651)($214)

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$642 $700 $184 $51 $168 $175 
Interest cost on APBO1,833 1,999 486 253 603 398 
Expected return on assets(4,384)— (1,372)(1,479)(2,539)(728)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss— (1,738)15 19 148 — 
Net other postretirement benefits income($1,385)($175)($926)($1,385)($2,713)($228)

The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,144 $1,342 $324 $104 $318 $348 
Interest cost on APBO3,550 4,024 978 498 1,164 788 
Expected return on assets(8,450)— (2,656)(2,890)(4,904)(1,404)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss(706)(3,622)(114)(54)306 (14)
Net other postretirement benefits income($3,414)($528)($1,946)($2,800)($5,302)($428)
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,284 $1,400 $368 $102 $336 $350 
Interest cost on APBO3,666 3,998 972 506 1,206 796 
Expected return on assets(8,768)— (2,744)(2,958)(5,078)(1,456)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss— (3,476)30 38 296 — 
Net other postretirement benefits income($2,770)($350)($1,852)($2,770)($5,426)($456)

Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2025 and 2024:
2025Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $3,493 ($31)$3,462 
Amortization of net gain (loss)(411)3,070 (108)2,551 
($411)$6,563 ($139)$6,013 
Entergy Louisiana
Amortization of prior service credit$— $1,136 $— $1,136 
Amortization of net gain (loss)(91)1,811 (1)1,719 
($91)$2,947 ($1)$2,855 

2024Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $3,513 ($40)$3,473 
Amortization of net gain (loss)(894)2,615 (80)1,641 
Settlement loss(316,974)— — (316,974)
($317,868)$6,128 ($120)($311,860)
Entergy Louisiana
Amortization of prior service credit$— $1,136 $— $1,136 
Amortization of net gain (loss)(104)1,738 (2)1,632 
($104)$2,874 ($2)$2,768 
Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2025 and 2024:
2025Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $6,986 ($62)$6,924 
Amortization of net gain (loss)(822)6,140 (216)5,102 
($822)$13,126 ($278)$12,026 
Entergy Louisiana
Amortization of prior service credit$— $2,272 $— $2,272 
Amortization of net gain (loss)(182)3,622 (2)3,438 
($182)$5,894 ($2)$5,710 

2024Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $7,026 ($80)$6,946 
Amortization of net gain (loss)(2,033)5,230 (160)3,037 
Settlement loss(316,974)— — (316,974)
($319,007)$12,256 ($240)($306,991)
Entergy Louisiana
Amortization of prior service credit$— $2,272 $— $2,272 
Amortization of net gain (loss)(208)3,476 (2)3,266 
($208)$5,748 ($2)$5,538 

Accounting for Pension and Other Postretirement Benefits

In accordance with accounting standards, the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income.

See Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefits costs.
Employer Contributions

Based on current assumptions, Entergy expects to contribute $240 million to its qualified pension plans in 2025.  As of June 30, 2025, Entergy had contributed $99.7 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2025:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Expected 2025 pension contributions$35,544 $41,253 $8,064 $5,016 $7,725 $15,668 
Pension contributions made through June 2025$16,968 $17,448 $3,951 $2,112 $3,240 $6,413 
Remaining estimated pension contributions to be made in 2025$18,576 $23,805 $4,113 $2,904 $4,485 $9,255 
Entergy Arkansas [Member]  
Retirement Benefits [Text Block] RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Components of Qualified Net Pension Cost

Entergy’s qualified pension costs, including amounts capitalized, for the second quarters of 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$23,617 $23,370 
Interest cost on projected benefit obligation59,680 65,961 
Expected return on assets(75,280)(89,506)
Recognized net loss13,309 14,854 
Settlement charges— 325,253 
Net pension cost$21,326 $339,932 
Entergy’s qualified pension costs, including amounts capitalized, for the six months ended June 30, 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$47,234 $46,746 
Interest cost on projected benefit obligation119,360 136,587 
Expected return on assets(150,560)(185,486)
Recognized net loss26,618 29,974 
Settlement charges— 325,253 
Net pension cost$42,652 $353,074 

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,427 $5,454 $1,304 $411 $1,024 $1,372 
Interest cost on projected benefit obligation13,814 14,704 3,699 1,647 2,973 3,585 
Expected return on assets(17,676)(18,897)(4,949)(2,174)(3,889)(4,575)
Recognized net loss4,791 2,268 822 415 454 1,114 
Net pension cost$5,356 $3,529 $876 $299 $562 $1,496 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,100 $5,551 $1,284 $440 $962 $1,383 
Interest cost on projected benefit obligation13,217 13,961 3,521 1,569 2,831 3,386 
Expected return on assets(18,155)(19,447)(5,113)(2,203)(4,077)(4,633)
Recognized net loss5,746 2,602 1,140 470 393 1,162 
Settlement charges— — — — — 611 
Net pension cost$4,908 $2,667 $832 $276 $109 $1,909 
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,854 $10,908 $2,608 $822 $2,048 $2,744 
Interest cost on projected benefit obligation27,628 29,408 7,398 3,294 5,946 7,170 
Expected return on assets(35,352)(37,794)(9,898)(4,348)(7,778)(9,150)
Recognized net loss9,582 4,536 1,644 830 908 2,228 
Net pension cost$10,712 $7,058 $1,752 $598 $1,124 $2,992 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,199 $11,102 $2,568 $880 $1,923 $2,767 
Interest cost on projected benefit obligation26,434 27,922 7,042 3,138 5,662 6,777 
Expected return on assets(36,310)(38,894)(10,226)(4,407)(8,154)(9,281)
Recognized net loss11,492 5,204 2,280 940 786 2,327 
Settlement charges— — — — — 611 
Net pension cost$9,815 $5,334 $1,664 $551 $217 $3,201 

Non-Qualified Net Pension Cost

Entergy recognized $2.5 million and $2.7 million in pension cost for its non-qualified pension plans for the second quarters of 2025 and 2024, respectively. For the second quarters of 2025 and 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Entergy recognized $5 million and $5.4 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2025 and 2024, respectively. For the six months ended June 30, 2025 and 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan.

The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for second quarters of 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$47 $36 $90 $35 $39 
2024$68 $51 $83 $31 $62 
The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$94 $72 $180 $70 $78 
2024$136 $102 $166 $61 $124 

For the second quarters of 2025 and 2024, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sums benefits out of the plan. For the six months ended June 30, 2025 and 2024 there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan.

Components of Net Other Postretirement Benefits Income

Entergy’s other postretirement benefits income, including amounts capitalized, for the second quarters of 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$2,757 $3,126 
Interest cost on accumulated postretirement benefit obligation (APBO)9,690 9,852 
Expected return on assets(10,209)(10,569)
Amortization of prior service credit(5,720)(5,720)
Recognized net gain(3,870)(2,761)
Net other postretirement benefits income($7,352)($6,072)

Entergy’s other postretirement benefits income, including amounts capitalized, for the six months ended June 30, 2025 and 2024, included the following components:
 20252024
 (In Thousands)
Service cost - benefits earned during the period$5,514 $6,252 
Interest cost on APBO
19,380 19,704 
Expected return on assets(20,418)(21,138)
Amortization of prior service credit(11,440)(11,440)
Recognized net gain(7,740)(5,522)
Net other postretirement benefits income($14,704)($12,144)
The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$572 $671 $162 $52 $159 $174 
Interest cost on APBO1,775 2,012 489 249 582 394 
Expected return on assets(4,225)— (1,328)(1,445)(2,452)(702)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss(353)(1,811)(57)(27)153 (7)
Net other postretirement benefits income($1,707)($264)($973)($1,400)($2,651)($214)

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$642 $700 $184 $51 $168 $175 
Interest cost on APBO1,833 1,999 486 253 603 398 
Expected return on assets(4,384)— (1,372)(1,479)(2,539)(728)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss— (1,738)15 19 148 — 
Net other postretirement benefits income($1,385)($175)($926)($1,385)($2,713)($228)

The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,144 $1,342 $324 $104 $318 $348 
Interest cost on APBO3,550 4,024 978 498 1,164 788 
Expected return on assets(8,450)— (2,656)(2,890)(4,904)(1,404)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss(706)(3,622)(114)(54)306 (14)
Net other postretirement benefits income($3,414)($528)($1,946)($2,800)($5,302)($428)
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,284 $1,400 $368 $102 $336 $350 
Interest cost on APBO3,666 3,998 972 506 1,206 796 
Expected return on assets(8,768)— (2,744)(2,958)(5,078)(1,456)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss— (3,476)30 38 296 — 
Net other postretirement benefits income($2,770)($350)($1,852)($2,770)($5,426)($456)

Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2025 and 2024:
2025Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $3,493 ($31)$3,462 
Amortization of net gain (loss)(411)3,070 (108)2,551 
($411)$6,563 ($139)$6,013 
Entergy Louisiana
Amortization of prior service credit$— $1,136 $— $1,136 
Amortization of net gain (loss)(91)1,811 (1)1,719 
($91)$2,947 ($1)$2,855 

2024Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $3,513 ($40)$3,473 
Amortization of net gain (loss)(894)2,615 (80)1,641 
Settlement loss(316,974)— — (316,974)
($317,868)$6,128 ($120)($311,860)
Entergy Louisiana
Amortization of prior service credit$— $1,136 $— $1,136 
Amortization of net gain (loss)(104)1,738 (2)1,632 
($104)$2,874 ($2)$2,768 
Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2025 and 2024:
2025Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $6,986 ($62)$6,924 
Amortization of net gain (loss)(822)6,140 (216)5,102 
($822)$13,126 ($278)$12,026 
Entergy Louisiana
Amortization of prior service credit$— $2,272 $— $2,272 
Amortization of net gain (loss)(182)3,622 (2)3,438 
($182)$5,894 ($2)$5,710 

2024Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $7,026 ($80)$6,946 
Amortization of net gain (loss)(2,033)5,230 (160)3,037 
Settlement loss(316,974)— — (316,974)
($319,007)$12,256 ($240)($306,991)
Entergy Louisiana
Amortization of prior service credit$— $2,272 $— $2,272 
Amortization of net gain (loss)(208)3,476 (2)3,266 
($208)$5,748 ($2)$5,538 

Accounting for Pension and Other Postretirement Benefits

In accordance with accounting standards, the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income.

See Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefits costs.
Employer Contributions

Based on current assumptions, Entergy expects to contribute $240 million to its qualified pension plans in 2025.  As of June 30, 2025, Entergy had contributed $99.7 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2025:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Expected 2025 pension contributions$35,544 $41,253 $8,064 $5,016 $7,725 $15,668 
Pension contributions made through June 2025$16,968 $17,448 $3,951 $2,112 $3,240 $6,413 
Remaining estimated pension contributions to be made in 2025$18,576 $23,805 $4,113 $2,904 $4,485 $9,255 
Entergy Louisiana [Member]  
Retirement Benefits [Text Block] RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Components of Qualified Net Pension Cost

Entergy’s qualified pension costs, including amounts capitalized, for the second quarters of 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$23,617 $23,370 
Interest cost on projected benefit obligation59,680 65,961 
Expected return on assets(75,280)(89,506)
Recognized net loss13,309 14,854 
Settlement charges— 325,253 
Net pension cost$21,326 $339,932 
Entergy’s qualified pension costs, including amounts capitalized, for the six months ended June 30, 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$47,234 $46,746 
Interest cost on projected benefit obligation119,360 136,587 
Expected return on assets(150,560)(185,486)
Recognized net loss26,618 29,974 
Settlement charges— 325,253 
Net pension cost$42,652 $353,074 

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,427 $5,454 $1,304 $411 $1,024 $1,372 
Interest cost on projected benefit obligation13,814 14,704 3,699 1,647 2,973 3,585 
Expected return on assets(17,676)(18,897)(4,949)(2,174)(3,889)(4,575)
Recognized net loss4,791 2,268 822 415 454 1,114 
Net pension cost$5,356 $3,529 $876 $299 $562 $1,496 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,100 $5,551 $1,284 $440 $962 $1,383 
Interest cost on projected benefit obligation13,217 13,961 3,521 1,569 2,831 3,386 
Expected return on assets(18,155)(19,447)(5,113)(2,203)(4,077)(4,633)
Recognized net loss5,746 2,602 1,140 470 393 1,162 
Settlement charges— — — — — 611 
Net pension cost$4,908 $2,667 $832 $276 $109 $1,909 
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,854 $10,908 $2,608 $822 $2,048 $2,744 
Interest cost on projected benefit obligation27,628 29,408 7,398 3,294 5,946 7,170 
Expected return on assets(35,352)(37,794)(9,898)(4,348)(7,778)(9,150)
Recognized net loss9,582 4,536 1,644 830 908 2,228 
Net pension cost$10,712 $7,058 $1,752 $598 $1,124 $2,992 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,199 $11,102 $2,568 $880 $1,923 $2,767 
Interest cost on projected benefit obligation26,434 27,922 7,042 3,138 5,662 6,777 
Expected return on assets(36,310)(38,894)(10,226)(4,407)(8,154)(9,281)
Recognized net loss11,492 5,204 2,280 940 786 2,327 
Settlement charges— — — — — 611 
Net pension cost$9,815 $5,334 $1,664 $551 $217 $3,201 

Non-Qualified Net Pension Cost

Entergy recognized $2.5 million and $2.7 million in pension cost for its non-qualified pension plans for the second quarters of 2025 and 2024, respectively. For the second quarters of 2025 and 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Entergy recognized $5 million and $5.4 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2025 and 2024, respectively. For the six months ended June 30, 2025 and 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan.

The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for second quarters of 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$47 $36 $90 $35 $39 
2024$68 $51 $83 $31 $62 
The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$94 $72 $180 $70 $78 
2024$136 $102 $166 $61 $124 

For the second quarters of 2025 and 2024, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sums benefits out of the plan. For the six months ended June 30, 2025 and 2024 there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan.

Components of Net Other Postretirement Benefits Income

Entergy’s other postretirement benefits income, including amounts capitalized, for the second quarters of 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$2,757 $3,126 
Interest cost on accumulated postretirement benefit obligation (APBO)9,690 9,852 
Expected return on assets(10,209)(10,569)
Amortization of prior service credit(5,720)(5,720)
Recognized net gain(3,870)(2,761)
Net other postretirement benefits income($7,352)($6,072)

Entergy’s other postretirement benefits income, including amounts capitalized, for the six months ended June 30, 2025 and 2024, included the following components:
 20252024
 (In Thousands)
Service cost - benefits earned during the period$5,514 $6,252 
Interest cost on APBO
19,380 19,704 
Expected return on assets(20,418)(21,138)
Amortization of prior service credit(11,440)(11,440)
Recognized net gain(7,740)(5,522)
Net other postretirement benefits income($14,704)($12,144)
The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$572 $671 $162 $52 $159 $174 
Interest cost on APBO1,775 2,012 489 249 582 394 
Expected return on assets(4,225)— (1,328)(1,445)(2,452)(702)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss(353)(1,811)(57)(27)153 (7)
Net other postretirement benefits income($1,707)($264)($973)($1,400)($2,651)($214)

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$642 $700 $184 $51 $168 $175 
Interest cost on APBO1,833 1,999 486 253 603 398 
Expected return on assets(4,384)— (1,372)(1,479)(2,539)(728)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss— (1,738)15 19 148 — 
Net other postretirement benefits income($1,385)($175)($926)($1,385)($2,713)($228)

The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,144 $1,342 $324 $104 $318 $348 
Interest cost on APBO3,550 4,024 978 498 1,164 788 
Expected return on assets(8,450)— (2,656)(2,890)(4,904)(1,404)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss(706)(3,622)(114)(54)306 (14)
Net other postretirement benefits income($3,414)($528)($1,946)($2,800)($5,302)($428)
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,284 $1,400 $368 $102 $336 $350 
Interest cost on APBO3,666 3,998 972 506 1,206 796 
Expected return on assets(8,768)— (2,744)(2,958)(5,078)(1,456)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss— (3,476)30 38 296 — 
Net other postretirement benefits income($2,770)($350)($1,852)($2,770)($5,426)($456)

Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2025 and 2024:
2025Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $3,493 ($31)$3,462 
Amortization of net gain (loss)(411)3,070 (108)2,551 
($411)$6,563 ($139)$6,013 
Entergy Louisiana
Amortization of prior service credit$— $1,136 $— $1,136 
Amortization of net gain (loss)(91)1,811 (1)1,719 
($91)$2,947 ($1)$2,855 

2024Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $3,513 ($40)$3,473 
Amortization of net gain (loss)(894)2,615 (80)1,641 
Settlement loss(316,974)— — (316,974)
($317,868)$6,128 ($120)($311,860)
Entergy Louisiana
Amortization of prior service credit$— $1,136 $— $1,136 
Amortization of net gain (loss)(104)1,738 (2)1,632 
($104)$2,874 ($2)$2,768 
Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2025 and 2024:
2025Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $6,986 ($62)$6,924 
Amortization of net gain (loss)(822)6,140 (216)5,102 
($822)$13,126 ($278)$12,026 
Entergy Louisiana
Amortization of prior service credit$— $2,272 $— $2,272 
Amortization of net gain (loss)(182)3,622 (2)3,438 
($182)$5,894 ($2)$5,710 

2024Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $7,026 ($80)$6,946 
Amortization of net gain (loss)(2,033)5,230 (160)3,037 
Settlement loss(316,974)— — (316,974)
($319,007)$12,256 ($240)($306,991)
Entergy Louisiana
Amortization of prior service credit$— $2,272 $— $2,272 
Amortization of net gain (loss)(208)3,476 (2)3,266 
($208)$5,748 ($2)$5,538 

Accounting for Pension and Other Postretirement Benefits

In accordance with accounting standards, the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income.

See Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefits costs.
Employer Contributions

Based on current assumptions, Entergy expects to contribute $240 million to its qualified pension plans in 2025.  As of June 30, 2025, Entergy had contributed $99.7 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2025:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Expected 2025 pension contributions$35,544 $41,253 $8,064 $5,016 $7,725 $15,668 
Pension contributions made through June 2025$16,968 $17,448 $3,951 $2,112 $3,240 $6,413 
Remaining estimated pension contributions to be made in 2025$18,576 $23,805 $4,113 $2,904 $4,485 $9,255 
Entergy Mississippi [Member]  
Retirement Benefits [Text Block] RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Components of Qualified Net Pension Cost

Entergy’s qualified pension costs, including amounts capitalized, for the second quarters of 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$23,617 $23,370 
Interest cost on projected benefit obligation59,680 65,961 
Expected return on assets(75,280)(89,506)
Recognized net loss13,309 14,854 
Settlement charges— 325,253 
Net pension cost$21,326 $339,932 
Entergy’s qualified pension costs, including amounts capitalized, for the six months ended June 30, 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$47,234 $46,746 
Interest cost on projected benefit obligation119,360 136,587 
Expected return on assets(150,560)(185,486)
Recognized net loss26,618 29,974 
Settlement charges— 325,253 
Net pension cost$42,652 $353,074 

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,427 $5,454 $1,304 $411 $1,024 $1,372 
Interest cost on projected benefit obligation13,814 14,704 3,699 1,647 2,973 3,585 
Expected return on assets(17,676)(18,897)(4,949)(2,174)(3,889)(4,575)
Recognized net loss4,791 2,268 822 415 454 1,114 
Net pension cost$5,356 $3,529 $876 $299 $562 $1,496 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,100 $5,551 $1,284 $440 $962 $1,383 
Interest cost on projected benefit obligation13,217 13,961 3,521 1,569 2,831 3,386 
Expected return on assets(18,155)(19,447)(5,113)(2,203)(4,077)(4,633)
Recognized net loss5,746 2,602 1,140 470 393 1,162 
Settlement charges— — — — — 611 
Net pension cost$4,908 $2,667 $832 $276 $109 $1,909 
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,854 $10,908 $2,608 $822 $2,048 $2,744 
Interest cost on projected benefit obligation27,628 29,408 7,398 3,294 5,946 7,170 
Expected return on assets(35,352)(37,794)(9,898)(4,348)(7,778)(9,150)
Recognized net loss9,582 4,536 1,644 830 908 2,228 
Net pension cost$10,712 $7,058 $1,752 $598 $1,124 $2,992 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,199 $11,102 $2,568 $880 $1,923 $2,767 
Interest cost on projected benefit obligation26,434 27,922 7,042 3,138 5,662 6,777 
Expected return on assets(36,310)(38,894)(10,226)(4,407)(8,154)(9,281)
Recognized net loss11,492 5,204 2,280 940 786 2,327 
Settlement charges— — — — — 611 
Net pension cost$9,815 $5,334 $1,664 $551 $217 $3,201 

Non-Qualified Net Pension Cost

Entergy recognized $2.5 million and $2.7 million in pension cost for its non-qualified pension plans for the second quarters of 2025 and 2024, respectively. For the second quarters of 2025 and 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Entergy recognized $5 million and $5.4 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2025 and 2024, respectively. For the six months ended June 30, 2025 and 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan.

The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for second quarters of 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$47 $36 $90 $35 $39 
2024$68 $51 $83 $31 $62 
The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$94 $72 $180 $70 $78 
2024$136 $102 $166 $61 $124 

For the second quarters of 2025 and 2024, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sums benefits out of the plan. For the six months ended June 30, 2025 and 2024 there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan.

Components of Net Other Postretirement Benefits Income

Entergy’s other postretirement benefits income, including amounts capitalized, for the second quarters of 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$2,757 $3,126 
Interest cost on accumulated postretirement benefit obligation (APBO)9,690 9,852 
Expected return on assets(10,209)(10,569)
Amortization of prior service credit(5,720)(5,720)
Recognized net gain(3,870)(2,761)
Net other postretirement benefits income($7,352)($6,072)

Entergy’s other postretirement benefits income, including amounts capitalized, for the six months ended June 30, 2025 and 2024, included the following components:
 20252024
 (In Thousands)
Service cost - benefits earned during the period$5,514 $6,252 
Interest cost on APBO
19,380 19,704 
Expected return on assets(20,418)(21,138)
Amortization of prior service credit(11,440)(11,440)
Recognized net gain(7,740)(5,522)
Net other postretirement benefits income($14,704)($12,144)
The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$572 $671 $162 $52 $159 $174 
Interest cost on APBO1,775 2,012 489 249 582 394 
Expected return on assets(4,225)— (1,328)(1,445)(2,452)(702)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss(353)(1,811)(57)(27)153 (7)
Net other postretirement benefits income($1,707)($264)($973)($1,400)($2,651)($214)

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$642 $700 $184 $51 $168 $175 
Interest cost on APBO1,833 1,999 486 253 603 398 
Expected return on assets(4,384)— (1,372)(1,479)(2,539)(728)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss— (1,738)15 19 148 — 
Net other postretirement benefits income($1,385)($175)($926)($1,385)($2,713)($228)

The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,144 $1,342 $324 $104 $318 $348 
Interest cost on APBO3,550 4,024 978 498 1,164 788 
Expected return on assets(8,450)— (2,656)(2,890)(4,904)(1,404)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss(706)(3,622)(114)(54)306 (14)
Net other postretirement benefits income($3,414)($528)($1,946)($2,800)($5,302)($428)
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,284 $1,400 $368 $102 $336 $350 
Interest cost on APBO3,666 3,998 972 506 1,206 796 
Expected return on assets(8,768)— (2,744)(2,958)(5,078)(1,456)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss— (3,476)30 38 296 — 
Net other postretirement benefits income($2,770)($350)($1,852)($2,770)($5,426)($456)

Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2025 and 2024:
2025Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $3,493 ($31)$3,462 
Amortization of net gain (loss)(411)3,070 (108)2,551 
($411)$6,563 ($139)$6,013 
Entergy Louisiana
Amortization of prior service credit$— $1,136 $— $1,136 
Amortization of net gain (loss)(91)1,811 (1)1,719 
($91)$2,947 ($1)$2,855 

2024Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $3,513 ($40)$3,473 
Amortization of net gain (loss)(894)2,615 (80)1,641 
Settlement loss(316,974)— — (316,974)
($317,868)$6,128 ($120)($311,860)
Entergy Louisiana
Amortization of prior service credit$— $1,136 $— $1,136 
Amortization of net gain (loss)(104)1,738 (2)1,632 
($104)$2,874 ($2)$2,768 
Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2025 and 2024:
2025Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $6,986 ($62)$6,924 
Amortization of net gain (loss)(822)6,140 (216)5,102 
($822)$13,126 ($278)$12,026 
Entergy Louisiana
Amortization of prior service credit$— $2,272 $— $2,272 
Amortization of net gain (loss)(182)3,622 (2)3,438 
($182)$5,894 ($2)$5,710 

2024Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $7,026 ($80)$6,946 
Amortization of net gain (loss)(2,033)5,230 (160)3,037 
Settlement loss(316,974)— — (316,974)
($319,007)$12,256 ($240)($306,991)
Entergy Louisiana
Amortization of prior service credit$— $2,272 $— $2,272 
Amortization of net gain (loss)(208)3,476 (2)3,266 
($208)$5,748 ($2)$5,538 

Accounting for Pension and Other Postretirement Benefits

In accordance with accounting standards, the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income.

See Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefits costs.
Employer Contributions

Based on current assumptions, Entergy expects to contribute $240 million to its qualified pension plans in 2025.  As of June 30, 2025, Entergy had contributed $99.7 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2025:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Expected 2025 pension contributions$35,544 $41,253 $8,064 $5,016 $7,725 $15,668 
Pension contributions made through June 2025$16,968 $17,448 $3,951 $2,112 $3,240 $6,413 
Remaining estimated pension contributions to be made in 2025$18,576 $23,805 $4,113 $2,904 $4,485 $9,255 
Entergy New Orleans [Member]  
Retirement Benefits [Text Block] RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Components of Qualified Net Pension Cost

Entergy’s qualified pension costs, including amounts capitalized, for the second quarters of 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$23,617 $23,370 
Interest cost on projected benefit obligation59,680 65,961 
Expected return on assets(75,280)(89,506)
Recognized net loss13,309 14,854 
Settlement charges— 325,253 
Net pension cost$21,326 $339,932 
Entergy’s qualified pension costs, including amounts capitalized, for the six months ended June 30, 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$47,234 $46,746 
Interest cost on projected benefit obligation119,360 136,587 
Expected return on assets(150,560)(185,486)
Recognized net loss26,618 29,974 
Settlement charges— 325,253 
Net pension cost$42,652 $353,074 

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,427 $5,454 $1,304 $411 $1,024 $1,372 
Interest cost on projected benefit obligation13,814 14,704 3,699 1,647 2,973 3,585 
Expected return on assets(17,676)(18,897)(4,949)(2,174)(3,889)(4,575)
Recognized net loss4,791 2,268 822 415 454 1,114 
Net pension cost$5,356 $3,529 $876 $299 $562 $1,496 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,100 $5,551 $1,284 $440 $962 $1,383 
Interest cost on projected benefit obligation13,217 13,961 3,521 1,569 2,831 3,386 
Expected return on assets(18,155)(19,447)(5,113)(2,203)(4,077)(4,633)
Recognized net loss5,746 2,602 1,140 470 393 1,162 
Settlement charges— — — — — 611 
Net pension cost$4,908 $2,667 $832 $276 $109 $1,909 
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,854 $10,908 $2,608 $822 $2,048 $2,744 
Interest cost on projected benefit obligation27,628 29,408 7,398 3,294 5,946 7,170 
Expected return on assets(35,352)(37,794)(9,898)(4,348)(7,778)(9,150)
Recognized net loss9,582 4,536 1,644 830 908 2,228 
Net pension cost$10,712 $7,058 $1,752 $598 $1,124 $2,992 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,199 $11,102 $2,568 $880 $1,923 $2,767 
Interest cost on projected benefit obligation26,434 27,922 7,042 3,138 5,662 6,777 
Expected return on assets(36,310)(38,894)(10,226)(4,407)(8,154)(9,281)
Recognized net loss11,492 5,204 2,280 940 786 2,327 
Settlement charges— — — — — 611 
Net pension cost$9,815 $5,334 $1,664 $551 $217 $3,201 

Non-Qualified Net Pension Cost

Entergy recognized $2.5 million and $2.7 million in pension cost for its non-qualified pension plans for the second quarters of 2025 and 2024, respectively. For the second quarters of 2025 and 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Entergy recognized $5 million and $5.4 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2025 and 2024, respectively. For the six months ended June 30, 2025 and 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan.

The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for second quarters of 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$47 $36 $90 $35 $39 
2024$68 $51 $83 $31 $62 
The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$94 $72 $180 $70 $78 
2024$136 $102 $166 $61 $124 

For the second quarters of 2025 and 2024, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sums benefits out of the plan. For the six months ended June 30, 2025 and 2024 there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan.

Components of Net Other Postretirement Benefits Income

Entergy’s other postretirement benefits income, including amounts capitalized, for the second quarters of 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$2,757 $3,126 
Interest cost on accumulated postretirement benefit obligation (APBO)9,690 9,852 
Expected return on assets(10,209)(10,569)
Amortization of prior service credit(5,720)(5,720)
Recognized net gain(3,870)(2,761)
Net other postretirement benefits income($7,352)($6,072)

Entergy’s other postretirement benefits income, including amounts capitalized, for the six months ended June 30, 2025 and 2024, included the following components:
 20252024
 (In Thousands)
Service cost - benefits earned during the period$5,514 $6,252 
Interest cost on APBO
19,380 19,704 
Expected return on assets(20,418)(21,138)
Amortization of prior service credit(11,440)(11,440)
Recognized net gain(7,740)(5,522)
Net other postretirement benefits income($14,704)($12,144)
The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$572 $671 $162 $52 $159 $174 
Interest cost on APBO1,775 2,012 489 249 582 394 
Expected return on assets(4,225)— (1,328)(1,445)(2,452)(702)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss(353)(1,811)(57)(27)153 (7)
Net other postretirement benefits income($1,707)($264)($973)($1,400)($2,651)($214)

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$642 $700 $184 $51 $168 $175 
Interest cost on APBO1,833 1,999 486 253 603 398 
Expected return on assets(4,384)— (1,372)(1,479)(2,539)(728)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss— (1,738)15 19 148 — 
Net other postretirement benefits income($1,385)($175)($926)($1,385)($2,713)($228)

The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,144 $1,342 $324 $104 $318 $348 
Interest cost on APBO3,550 4,024 978 498 1,164 788 
Expected return on assets(8,450)— (2,656)(2,890)(4,904)(1,404)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss(706)(3,622)(114)(54)306 (14)
Net other postretirement benefits income($3,414)($528)($1,946)($2,800)($5,302)($428)
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,284 $1,400 $368 $102 $336 $350 
Interest cost on APBO3,666 3,998 972 506 1,206 796 
Expected return on assets(8,768)— (2,744)(2,958)(5,078)(1,456)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss— (3,476)30 38 296 — 
Net other postretirement benefits income($2,770)($350)($1,852)($2,770)($5,426)($456)

Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2025 and 2024:
2025Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $3,493 ($31)$3,462 
Amortization of net gain (loss)(411)3,070 (108)2,551 
($411)$6,563 ($139)$6,013 
Entergy Louisiana
Amortization of prior service credit$— $1,136 $— $1,136 
Amortization of net gain (loss)(91)1,811 (1)1,719 
($91)$2,947 ($1)$2,855 

2024Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $3,513 ($40)$3,473 
Amortization of net gain (loss)(894)2,615 (80)1,641 
Settlement loss(316,974)— — (316,974)
($317,868)$6,128 ($120)($311,860)
Entergy Louisiana
Amortization of prior service credit$— $1,136 $— $1,136 
Amortization of net gain (loss)(104)1,738 (2)1,632 
($104)$2,874 ($2)$2,768 
Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2025 and 2024:
2025Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $6,986 ($62)$6,924 
Amortization of net gain (loss)(822)6,140 (216)5,102 
($822)$13,126 ($278)$12,026 
Entergy Louisiana
Amortization of prior service credit$— $2,272 $— $2,272 
Amortization of net gain (loss)(182)3,622 (2)3,438 
($182)$5,894 ($2)$5,710 

2024Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $7,026 ($80)$6,946 
Amortization of net gain (loss)(2,033)5,230 (160)3,037 
Settlement loss(316,974)— — (316,974)
($319,007)$12,256 ($240)($306,991)
Entergy Louisiana
Amortization of prior service credit$— $2,272 $— $2,272 
Amortization of net gain (loss)(208)3,476 (2)3,266 
($208)$5,748 ($2)$5,538 

Accounting for Pension and Other Postretirement Benefits

In accordance with accounting standards, the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income.

See Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefits costs.
Employer Contributions

Based on current assumptions, Entergy expects to contribute $240 million to its qualified pension plans in 2025.  As of June 30, 2025, Entergy had contributed $99.7 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2025:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Expected 2025 pension contributions$35,544 $41,253 $8,064 $5,016 $7,725 $15,668 
Pension contributions made through June 2025$16,968 $17,448 $3,951 $2,112 $3,240 $6,413 
Remaining estimated pension contributions to be made in 2025$18,576 $23,805 $4,113 $2,904 $4,485 $9,255 
Entergy Texas [Member]  
Retirement Benefits [Text Block] RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Components of Qualified Net Pension Cost

Entergy’s qualified pension costs, including amounts capitalized, for the second quarters of 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$23,617 $23,370 
Interest cost on projected benefit obligation59,680 65,961 
Expected return on assets(75,280)(89,506)
Recognized net loss13,309 14,854 
Settlement charges— 325,253 
Net pension cost$21,326 $339,932 
Entergy’s qualified pension costs, including amounts capitalized, for the six months ended June 30, 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$47,234 $46,746 
Interest cost on projected benefit obligation119,360 136,587 
Expected return on assets(150,560)(185,486)
Recognized net loss26,618 29,974 
Settlement charges— 325,253 
Net pension cost$42,652 $353,074 

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,427 $5,454 $1,304 $411 $1,024 $1,372 
Interest cost on projected benefit obligation13,814 14,704 3,699 1,647 2,973 3,585 
Expected return on assets(17,676)(18,897)(4,949)(2,174)(3,889)(4,575)
Recognized net loss4,791 2,268 822 415 454 1,114 
Net pension cost$5,356 $3,529 $876 $299 $562 $1,496 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,100 $5,551 $1,284 $440 $962 $1,383 
Interest cost on projected benefit obligation13,217 13,961 3,521 1,569 2,831 3,386 
Expected return on assets(18,155)(19,447)(5,113)(2,203)(4,077)(4,633)
Recognized net loss5,746 2,602 1,140 470 393 1,162 
Settlement charges— — — — — 611 
Net pension cost$4,908 $2,667 $832 $276 $109 $1,909 
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,854 $10,908 $2,608 $822 $2,048 $2,744 
Interest cost on projected benefit obligation27,628 29,408 7,398 3,294 5,946 7,170 
Expected return on assets(35,352)(37,794)(9,898)(4,348)(7,778)(9,150)
Recognized net loss9,582 4,536 1,644 830 908 2,228 
Net pension cost$10,712 $7,058 $1,752 $598 $1,124 $2,992 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,199 $11,102 $2,568 $880 $1,923 $2,767 
Interest cost on projected benefit obligation26,434 27,922 7,042 3,138 5,662 6,777 
Expected return on assets(36,310)(38,894)(10,226)(4,407)(8,154)(9,281)
Recognized net loss11,492 5,204 2,280 940 786 2,327 
Settlement charges— — — — — 611 
Net pension cost$9,815 $5,334 $1,664 $551 $217 $3,201 

Non-Qualified Net Pension Cost

Entergy recognized $2.5 million and $2.7 million in pension cost for its non-qualified pension plans for the second quarters of 2025 and 2024, respectively. For the second quarters of 2025 and 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Entergy recognized $5 million and $5.4 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2025 and 2024, respectively. For the six months ended June 30, 2025 and 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan.

The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for second quarters of 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$47 $36 $90 $35 $39 
2024$68 $51 $83 $31 $62 
The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$94 $72 $180 $70 $78 
2024$136 $102 $166 $61 $124 

For the second quarters of 2025 and 2024, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sums benefits out of the plan. For the six months ended June 30, 2025 and 2024 there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan.

Components of Net Other Postretirement Benefits Income

Entergy’s other postretirement benefits income, including amounts capitalized, for the second quarters of 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$2,757 $3,126 
Interest cost on accumulated postretirement benefit obligation (APBO)9,690 9,852 
Expected return on assets(10,209)(10,569)
Amortization of prior service credit(5,720)(5,720)
Recognized net gain(3,870)(2,761)
Net other postretirement benefits income($7,352)($6,072)

Entergy’s other postretirement benefits income, including amounts capitalized, for the six months ended June 30, 2025 and 2024, included the following components:
 20252024
 (In Thousands)
Service cost - benefits earned during the period$5,514 $6,252 
Interest cost on APBO
19,380 19,704 
Expected return on assets(20,418)(21,138)
Amortization of prior service credit(11,440)(11,440)
Recognized net gain(7,740)(5,522)
Net other postretirement benefits income($14,704)($12,144)
The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$572 $671 $162 $52 $159 $174 
Interest cost on APBO1,775 2,012 489 249 582 394 
Expected return on assets(4,225)— (1,328)(1,445)(2,452)(702)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss(353)(1,811)(57)(27)153 (7)
Net other postretirement benefits income($1,707)($264)($973)($1,400)($2,651)($214)

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$642 $700 $184 $51 $168 $175 
Interest cost on APBO1,833 1,999 486 253 603 398 
Expected return on assets(4,384)— (1,372)(1,479)(2,539)(728)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss— (1,738)15 19 148 — 
Net other postretirement benefits income($1,385)($175)($926)($1,385)($2,713)($228)

The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,144 $1,342 $324 $104 $318 $348 
Interest cost on APBO3,550 4,024 978 498 1,164 788 
Expected return on assets(8,450)— (2,656)(2,890)(4,904)(1,404)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss(706)(3,622)(114)(54)306 (14)
Net other postretirement benefits income($3,414)($528)($1,946)($2,800)($5,302)($428)
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,284 $1,400 $368 $102 $336 $350 
Interest cost on APBO3,666 3,998 972 506 1,206 796 
Expected return on assets(8,768)— (2,744)(2,958)(5,078)(1,456)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss— (3,476)30 38 296 — 
Net other postretirement benefits income($2,770)($350)($1,852)($2,770)($5,426)($456)

Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2025 and 2024:
2025Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $3,493 ($31)$3,462 
Amortization of net gain (loss)(411)3,070 (108)2,551 
($411)$6,563 ($139)$6,013 
Entergy Louisiana
Amortization of prior service credit$— $1,136 $— $1,136 
Amortization of net gain (loss)(91)1,811 (1)1,719 
($91)$2,947 ($1)$2,855 

2024Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $3,513 ($40)$3,473 
Amortization of net gain (loss)(894)2,615 (80)1,641 
Settlement loss(316,974)— — (316,974)
($317,868)$6,128 ($120)($311,860)
Entergy Louisiana
Amortization of prior service credit$— $1,136 $— $1,136 
Amortization of net gain (loss)(104)1,738 (2)1,632 
($104)$2,874 ($2)$2,768 
Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2025 and 2024:
2025Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $6,986 ($62)$6,924 
Amortization of net gain (loss)(822)6,140 (216)5,102 
($822)$13,126 ($278)$12,026 
Entergy Louisiana
Amortization of prior service credit$— $2,272 $— $2,272 
Amortization of net gain (loss)(182)3,622 (2)3,438 
($182)$5,894 ($2)$5,710 

2024Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $7,026 ($80)$6,946 
Amortization of net gain (loss)(2,033)5,230 (160)3,037 
Settlement loss(316,974)— — (316,974)
($319,007)$12,256 ($240)($306,991)
Entergy Louisiana
Amortization of prior service credit$— $2,272 $— $2,272 
Amortization of net gain (loss)(208)3,476 (2)3,266 
($208)$5,748 ($2)$5,538 

Accounting for Pension and Other Postretirement Benefits

In accordance with accounting standards, the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income.

See Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefits costs.
Employer Contributions

Based on current assumptions, Entergy expects to contribute $240 million to its qualified pension plans in 2025.  As of June 30, 2025, Entergy had contributed $99.7 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2025:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Expected 2025 pension contributions$35,544 $41,253 $8,064 $5,016 $7,725 $15,668 
Pension contributions made through June 2025$16,968 $17,448 $3,951 $2,112 $3,240 $6,413 
Remaining estimated pension contributions to be made in 2025$18,576 $23,805 $4,113 $2,904 $4,485 $9,255 
System Energy [Member]  
Retirement Benefits [Text Block] RETIREMENT AND OTHER POSTRETIREMENT BENEFITS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Components of Qualified Net Pension Cost

Entergy’s qualified pension costs, including amounts capitalized, for the second quarters of 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$23,617 $23,370 
Interest cost on projected benefit obligation59,680 65,961 
Expected return on assets(75,280)(89,506)
Recognized net loss13,309 14,854 
Settlement charges— 325,253 
Net pension cost$21,326 $339,932 
Entergy’s qualified pension costs, including amounts capitalized, for the six months ended June 30, 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$47,234 $46,746 
Interest cost on projected benefit obligation119,360 136,587 
Expected return on assets(150,560)(185,486)
Recognized net loss26,618 29,974 
Settlement charges— 325,253 
Net pension cost$42,652 $353,074 

The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,427 $5,454 $1,304 $411 $1,024 $1,372 
Interest cost on projected benefit obligation13,814 14,704 3,699 1,647 2,973 3,585 
Expected return on assets(17,676)(18,897)(4,949)(2,174)(3,889)(4,575)
Recognized net loss4,791 2,268 822 415 454 1,114 
Net pension cost$5,356 $3,529 $876 $299 $562 $1,496 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,100 $5,551 $1,284 $440 $962 $1,383 
Interest cost on projected benefit obligation13,217 13,961 3,521 1,569 2,831 3,386 
Expected return on assets(18,155)(19,447)(5,113)(2,203)(4,077)(4,633)
Recognized net loss5,746 2,602 1,140 470 393 1,162 
Settlement charges— — — — — 611 
Net pension cost$4,908 $2,667 $832 $276 $109 $1,909 
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,854 $10,908 $2,608 $822 $2,048 $2,744 
Interest cost on projected benefit obligation27,628 29,408 7,398 3,294 5,946 7,170 
Expected return on assets(35,352)(37,794)(9,898)(4,348)(7,778)(9,150)
Recognized net loss9,582 4,536 1,644 830 908 2,228 
Net pension cost$10,712 $7,058 $1,752 $598 $1,124 $2,992 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,199 $11,102 $2,568 $880 $1,923 $2,767 
Interest cost on projected benefit obligation26,434 27,922 7,042 3,138 5,662 6,777 
Expected return on assets(36,310)(38,894)(10,226)(4,407)(8,154)(9,281)
Recognized net loss11,492 5,204 2,280 940 786 2,327 
Settlement charges— — — — — 611 
Net pension cost$9,815 $5,334 $1,664 $551 $217 $3,201 

Non-Qualified Net Pension Cost

Entergy recognized $2.5 million and $2.7 million in pension cost for its non-qualified pension plans for the second quarters of 2025 and 2024, respectively. For the second quarters of 2025 and 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan. Entergy recognized $5 million and $5.4 million in pension cost for its non-qualified pension plans for the six months ended June 30, 2025 and 2024, respectively. For the six months ended June 30, 2025 and 2024, there were no settlement charges related to the payment of lump sum benefits out of the plan.

The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for second quarters of 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$47 $36 $90 $35 $39 
2024$68 $51 $83 $31 $62 
The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$94 $72 $180 $70 $78 
2024$136 $102 $166 $61 $124 

For the second quarters of 2025 and 2024, there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sums benefits out of the plan. For the six months ended June 30, 2025 and 2024 there were no settlement charges for the Registrant Subsidiaries related to the payment of lump sum benefits out of the plan.

Components of Net Other Postretirement Benefits Income

Entergy’s other postretirement benefits income, including amounts capitalized, for the second quarters of 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$2,757 $3,126 
Interest cost on accumulated postretirement benefit obligation (APBO)9,690 9,852 
Expected return on assets(10,209)(10,569)
Amortization of prior service credit(5,720)(5,720)
Recognized net gain(3,870)(2,761)
Net other postretirement benefits income($7,352)($6,072)

Entergy’s other postretirement benefits income, including amounts capitalized, for the six months ended June 30, 2025 and 2024, included the following components:
 20252024
 (In Thousands)
Service cost - benefits earned during the period$5,514 $6,252 
Interest cost on APBO
19,380 19,704 
Expected return on assets(20,418)(21,138)
Amortization of prior service credit(11,440)(11,440)
Recognized net gain(7,740)(5,522)
Net other postretirement benefits income($14,704)($12,144)
The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$572 $671 $162 $52 $159 $174 
Interest cost on APBO1,775 2,012 489 249 582 394 
Expected return on assets(4,225)— (1,328)(1,445)(2,452)(702)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss(353)(1,811)(57)(27)153 (7)
Net other postretirement benefits income($1,707)($264)($973)($1,400)($2,651)($214)

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$642 $700 $184 $51 $168 $175 
Interest cost on APBO1,833 1,999 486 253 603 398 
Expected return on assets(4,384)— (1,372)(1,479)(2,539)(728)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss— (1,738)15 19 148 — 
Net other postretirement benefits income($1,385)($175)($926)($1,385)($2,713)($228)

The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,144 $1,342 $324 $104 $318 $348 
Interest cost on APBO3,550 4,024 978 498 1,164 788 
Expected return on assets(8,450)— (2,656)(2,890)(4,904)(1,404)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss(706)(3,622)(114)(54)306 (14)
Net other postretirement benefits income($3,414)($528)($1,946)($2,800)($5,302)($428)
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,284 $1,400 $368 $102 $336 $350 
Interest cost on APBO3,666 3,998 972 506 1,206 796 
Expected return on assets(8,768)— (2,744)(2,958)(5,078)(1,456)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss— (3,476)30 38 296 — 
Net other postretirement benefits income($2,770)($350)($1,852)($2,770)($5,426)($456)

Reclassification out of Accumulated Other Comprehensive Income (Loss)

Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2025 and 2024:
2025Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $3,493 ($31)$3,462 
Amortization of net gain (loss)(411)3,070 (108)2,551 
($411)$6,563 ($139)$6,013 
Entergy Louisiana
Amortization of prior service credit$— $1,136 $— $1,136 
Amortization of net gain (loss)(91)1,811 (1)1,719 
($91)$2,947 ($1)$2,855 

2024Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $3,513 ($40)$3,473 
Amortization of net gain (loss)(894)2,615 (80)1,641 
Settlement loss(316,974)— — (316,974)
($317,868)$6,128 ($120)($311,860)
Entergy Louisiana
Amortization of prior service credit$— $1,136 $— $1,136 
Amortization of net gain (loss)(104)1,738 (2)1,632 
($104)$2,874 ($2)$2,768 
Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2025 and 2024:
2025Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $6,986 ($62)$6,924 
Amortization of net gain (loss)(822)6,140 (216)5,102 
($822)$13,126 ($278)$12,026 
Entergy Louisiana
Amortization of prior service credit$— $2,272 $— $2,272 
Amortization of net gain (loss)(182)3,622 (2)3,438 
($182)$5,894 ($2)$5,710 

2024Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $7,026 ($80)$6,946 
Amortization of net gain (loss)(2,033)5,230 (160)3,037 
Settlement loss(316,974)— — (316,974)
($319,007)$12,256 ($240)($306,991)
Entergy Louisiana
Amortization of prior service credit$— $2,272 $— $2,272 
Amortization of net gain (loss)(208)3,476 (2)3,266 
($208)$5,748 ($2)$5,538 

Accounting for Pension and Other Postretirement Benefits

In accordance with accounting standards, the other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations and are presented by Entergy in miscellaneous - net in other income.

See Note 11 to the financial statements in the Form 10-K for further discussion of pension and other postretirement benefits costs.
Employer Contributions

Based on current assumptions, Entergy expects to contribute $240 million to its qualified pension plans in 2025.  As of June 30, 2025, Entergy had contributed $99.7 million to its pension plans.  Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2025:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Expected 2025 pension contributions$35,544 $41,253 $8,064 $5,016 $7,725 $15,668 
Pension contributions made through June 2025$16,968 $17,448 $3,951 $2,112 $3,240 $6,413 
Remaining estimated pension contributions to be made in 2025$18,576 $23,805 $4,113 $2,904 $4,485 $9,255 
v3.25.2
Business Segment Information
 6 Months Ended
Jun. 30, 2025
Segment Reporting Disclosure [Text Block] BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy has a single reportable segment, Utility, which includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business in portions of Louisiana through June 30, 2025. See Note 13 to the financial statements herein for discussion of the sale of the natural gas distribution business on July 1, 2025.  Parent & Other includes the parent company, Entergy Corporation, and other business activity, including Entergy’s non-utility operations business, which is an operating segment that does not meet the quantitative thresholds for determining reportable segments.
The following table includes operating revenues and significant expense categories regularly provided to the chief operating decision maker for the Utility segment, a reconciliation of Utility operating revenues to Entergy’s consolidated operating revenues, and a reconciliation of Utility net income to consolidated net income and net income attributable to Entergy Corporation for the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
2025202420252024
(In Thousands)(In Thousands)
Utility operating revenues$3,315,723 $2,941,404 $6,145,320 $5,713,577 
Reconciliation of revenues:
Other revenues (a)13,144 12,227 30,448 34,703 
Elimination of intersegment revenues(18)(11)(45)(32)
Consolidated operating revenues3,328,849 2,953,620 6,175,723 5,748,248 
Less Utility expenses and other items:
Fuel, fuel-related expenses, and gas purchased for resale631,773 514,223 970,756 1,118,627 
Purchased power372,842 193,010 714,926 412,204 
Other operation and maintenance expenses713,296 685,990 1,375,770 1,366,705 
Other regulatory charges (credits) - net(55,957)125,607 (72,800)234,954 
Other Utility items (b)1,051,596 979,255 2,063,453 1,941,788 
Utility net income602,173 443,319 1,093,215 639,299 
Reconciliation of net income:
Non-cash pension settlement charge (c)— (316,738)— (316,738)
Income taxes on reconciling item noted above— 66,515 — 66,515 
Other loss(55,678)(62,479)(109,050)(102,362)
Elimination of intersegment loss(74,541)(78,885)(149,789)(158,446)
Consolidated net income471,954 51,732 834,376 128,268 
Preferred dividend requirements of subsidiaries and noncontrolling interests (d)4,024 2,810 5,686 4,065 
Net income attributable to Entergy Corporation$467,930 $48,922 $828,690 $124,203 

(a)See Note 12 to the financial statements herein and Note 19 to the financial statements in the Form 10-K for discussion of other revenues.
(b)Other Utility items includes nuclear refueling outage expenses, asset write-offs, decommissioning expenses, taxes other than income taxes, depreciation and amortization expenses, other income, interest expense, and income tax expense.
(c)See Note 11 to the financial statements in the Form 10-K for discussion of the one-time non-cash pension settlement charge resulting from a group annuity contract purchased in second quarter 2024 to settle certain pension liabilities, of which $8 million was recorded at Utility and $317 million was recorded at Parent & Other.
(d)Preferred dividend requirements of subsidiaries and noncontrolling interests is substantially derived from the Utility segment. See Note 6 to the financial statements in the Form 10-K for discussion of preferred stock and noncontrolling interests.
The following table presents segment financial information for Entergy’s single reportable segment, Utility, and a reconciliation to the corresponding consolidated amounts for Entergy Corporation for the three months ended June 30, 2025 and 2024:
UtilityParent & OtherEliminationsConsolidated
(In Thousands)
2025
Depreciation, amortization, and decommissioning$577,386 $1,766 $— $579,152 
Interest and investment income$160,248 $2,146 ($74,975)$87,419 
Interest expense$261,033 $61,475 ($434)$322,074 
Income taxes$152,836 ($14,437)$— $138,399 
2024
Depreciation, amortization, and decommissioning$557,962 $1,594 $— $559,556 
Interest and investment income$141,249 $9,985 ($80,647)$70,587 
Interest expense$225,511 $65,829 ($1,763)$289,577 
Income taxes$113,017 ($79,383)$— $33,634 

The following table presents segment financial information for Entergy’s single reportable segment, Utility, and a reconciliation to the corresponding consolidated amounts for Entergy Corporation for the six months ended June 30, 2025 and 2024:
UtilityParent & OtherEliminationsConsolidated
(In Thousands)
2025
Depreciation, amortization, and decommissioning$1,144,573 $3,451 $— $1,148,024 
Interest and investment income$267,423 $3,835 ($150,433)$120,825 
Interest expense$528,164 $124,344 ($643)$651,865 
Income taxes$267,109 ($28,669)$— $238,440 
Total assets as of June 30, 2025
$72,511,224 $777,674 ($4,905,758)$68,383,140 
Total expenditures for additions to long-lived assets$3,798,452 $606 $— $3,799,058 
2024
Asset write-offs, impairments, and related charges (credits)$131,775 $— $— $131,775 
Depreciation, amortization, and decommissioning$1,109,452 $3,146 $— $1,112,598 
Interest and investment income$366,499 $15,353 ($160,569)$221,283 
Interest expense$437,659 $121,242 ($2,124)$556,777 
Income taxes$147,565 ($92,938)$— $54,627 
Total assets as of December 31, 2024
$68,951,564 $721,459 ($4,882,991)$64,790,032 
Total expenditures for additions to long-lived assets$2,457,683 $693 $— $2,458,376 

Eliminations are primarily intersegment activity. All of Entergy’s goodwill is related to the Utility segment.
Registrant Subsidiaries

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has one operating and reportable segment, an integrated utility business which includes the generation, transmission, and distribution of electric power; and operation of a small natural gas distribution business at each of Entergy Louisiana and Entergy New Orleans through June 30, 2025. See Note 13 to the financial statements herein for discussion of the sale of the Entergy New Orleans and Entergy Louisiana natural gas distribution businesses on July 1, 2025. System Energy has one operating and reportable segment, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations are managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results. All segment financial information for the Registrant Subsidiaries is as reported on the respective financial statements for each of the Registrant Subsidiaries.
Entergy Arkansas [Member]  
Segment Reporting Disclosure [Text Block] BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy has a single reportable segment, Utility, which includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business in portions of Louisiana through June 30, 2025. See Note 13 to the financial statements herein for discussion of the sale of the natural gas distribution business on July 1, 2025.  Parent & Other includes the parent company, Entergy Corporation, and other business activity, including Entergy’s non-utility operations business, which is an operating segment that does not meet the quantitative thresholds for determining reportable segments.
The following table includes operating revenues and significant expense categories regularly provided to the chief operating decision maker for the Utility segment, a reconciliation of Utility operating revenues to Entergy’s consolidated operating revenues, and a reconciliation of Utility net income to consolidated net income and net income attributable to Entergy Corporation for the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
2025202420252024
(In Thousands)(In Thousands)
Utility operating revenues$3,315,723 $2,941,404 $6,145,320 $5,713,577 
Reconciliation of revenues:
Other revenues (a)13,144 12,227 30,448 34,703 
Elimination of intersegment revenues(18)(11)(45)(32)
Consolidated operating revenues3,328,849 2,953,620 6,175,723 5,748,248 
Less Utility expenses and other items:
Fuel, fuel-related expenses, and gas purchased for resale631,773 514,223 970,756 1,118,627 
Purchased power372,842 193,010 714,926 412,204 
Other operation and maintenance expenses713,296 685,990 1,375,770 1,366,705 
Other regulatory charges (credits) - net(55,957)125,607 (72,800)234,954 
Other Utility items (b)1,051,596 979,255 2,063,453 1,941,788 
Utility net income602,173 443,319 1,093,215 639,299 
Reconciliation of net income:
Non-cash pension settlement charge (c)— (316,738)— (316,738)
Income taxes on reconciling item noted above— 66,515 — 66,515 
Other loss(55,678)(62,479)(109,050)(102,362)
Elimination of intersegment loss(74,541)(78,885)(149,789)(158,446)
Consolidated net income471,954 51,732 834,376 128,268 
Preferred dividend requirements of subsidiaries and noncontrolling interests (d)4,024 2,810 5,686 4,065 
Net income attributable to Entergy Corporation$467,930 $48,922 $828,690 $124,203 

(a)See Note 12 to the financial statements herein and Note 19 to the financial statements in the Form 10-K for discussion of other revenues.
(b)Other Utility items includes nuclear refueling outage expenses, asset write-offs, decommissioning expenses, taxes other than income taxes, depreciation and amortization expenses, other income, interest expense, and income tax expense.
(c)See Note 11 to the financial statements in the Form 10-K for discussion of the one-time non-cash pension settlement charge resulting from a group annuity contract purchased in second quarter 2024 to settle certain pension liabilities, of which $8 million was recorded at Utility and $317 million was recorded at Parent & Other.
(d)Preferred dividend requirements of subsidiaries and noncontrolling interests is substantially derived from the Utility segment. See Note 6 to the financial statements in the Form 10-K for discussion of preferred stock and noncontrolling interests.
The following table presents segment financial information for Entergy’s single reportable segment, Utility, and a reconciliation to the corresponding consolidated amounts for Entergy Corporation for the three months ended June 30, 2025 and 2024:
UtilityParent & OtherEliminationsConsolidated
(In Thousands)
2025
Depreciation, amortization, and decommissioning$577,386 $1,766 $— $579,152 
Interest and investment income$160,248 $2,146 ($74,975)$87,419 
Interest expense$261,033 $61,475 ($434)$322,074 
Income taxes$152,836 ($14,437)$— $138,399 
2024
Depreciation, amortization, and decommissioning$557,962 $1,594 $— $559,556 
Interest and investment income$141,249 $9,985 ($80,647)$70,587 
Interest expense$225,511 $65,829 ($1,763)$289,577 
Income taxes$113,017 ($79,383)$— $33,634 

The following table presents segment financial information for Entergy’s single reportable segment, Utility, and a reconciliation to the corresponding consolidated amounts for Entergy Corporation for the six months ended June 30, 2025 and 2024:
UtilityParent & OtherEliminationsConsolidated
(In Thousands)
2025
Depreciation, amortization, and decommissioning$1,144,573 $3,451 $— $1,148,024 
Interest and investment income$267,423 $3,835 ($150,433)$120,825 
Interest expense$528,164 $124,344 ($643)$651,865 
Income taxes$267,109 ($28,669)$— $238,440 
Total assets as of June 30, 2025
$72,511,224 $777,674 ($4,905,758)$68,383,140 
Total expenditures for additions to long-lived assets$3,798,452 $606 $— $3,799,058 
2024
Asset write-offs, impairments, and related charges (credits)$131,775 $— $— $131,775 
Depreciation, amortization, and decommissioning$1,109,452 $3,146 $— $1,112,598 
Interest and investment income$366,499 $15,353 ($160,569)$221,283 
Interest expense$437,659 $121,242 ($2,124)$556,777 
Income taxes$147,565 ($92,938)$— $54,627 
Total assets as of December 31, 2024
$68,951,564 $721,459 ($4,882,991)$64,790,032 
Total expenditures for additions to long-lived assets$2,457,683 $693 $— $2,458,376 

Eliminations are primarily intersegment activity. All of Entergy’s goodwill is related to the Utility segment.
Registrant Subsidiaries

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has one operating and reportable segment, an integrated utility business which includes the generation, transmission, and distribution of electric power; and operation of a small natural gas distribution business at each of Entergy Louisiana and Entergy New Orleans through June 30, 2025. See Note 13 to the financial statements herein for discussion of the sale of the Entergy New Orleans and Entergy Louisiana natural gas distribution businesses on July 1, 2025. System Energy has one operating and reportable segment, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations are managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results. All segment financial information for the Registrant Subsidiaries is as reported on the respective financial statements for each of the Registrant Subsidiaries.
Entergy Louisiana [Member]  
Segment Reporting Disclosure [Text Block] BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy has a single reportable segment, Utility, which includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business in portions of Louisiana through June 30, 2025. See Note 13 to the financial statements herein for discussion of the sale of the natural gas distribution business on July 1, 2025.  Parent & Other includes the parent company, Entergy Corporation, and other business activity, including Entergy’s non-utility operations business, which is an operating segment that does not meet the quantitative thresholds for determining reportable segments.
The following table includes operating revenues and significant expense categories regularly provided to the chief operating decision maker for the Utility segment, a reconciliation of Utility operating revenues to Entergy’s consolidated operating revenues, and a reconciliation of Utility net income to consolidated net income and net income attributable to Entergy Corporation for the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
2025202420252024
(In Thousands)(In Thousands)
Utility operating revenues$3,315,723 $2,941,404 $6,145,320 $5,713,577 
Reconciliation of revenues:
Other revenues (a)13,144 12,227 30,448 34,703 
Elimination of intersegment revenues(18)(11)(45)(32)
Consolidated operating revenues3,328,849 2,953,620 6,175,723 5,748,248 
Less Utility expenses and other items:
Fuel, fuel-related expenses, and gas purchased for resale631,773 514,223 970,756 1,118,627 
Purchased power372,842 193,010 714,926 412,204 
Other operation and maintenance expenses713,296 685,990 1,375,770 1,366,705 
Other regulatory charges (credits) - net(55,957)125,607 (72,800)234,954 
Other Utility items (b)1,051,596 979,255 2,063,453 1,941,788 
Utility net income602,173 443,319 1,093,215 639,299 
Reconciliation of net income:
Non-cash pension settlement charge (c)— (316,738)— (316,738)
Income taxes on reconciling item noted above— 66,515 — 66,515 
Other loss(55,678)(62,479)(109,050)(102,362)
Elimination of intersegment loss(74,541)(78,885)(149,789)(158,446)
Consolidated net income471,954 51,732 834,376 128,268 
Preferred dividend requirements of subsidiaries and noncontrolling interests (d)4,024 2,810 5,686 4,065 
Net income attributable to Entergy Corporation$467,930 $48,922 $828,690 $124,203 

(a)See Note 12 to the financial statements herein and Note 19 to the financial statements in the Form 10-K for discussion of other revenues.
(b)Other Utility items includes nuclear refueling outage expenses, asset write-offs, decommissioning expenses, taxes other than income taxes, depreciation and amortization expenses, other income, interest expense, and income tax expense.
(c)See Note 11 to the financial statements in the Form 10-K for discussion of the one-time non-cash pension settlement charge resulting from a group annuity contract purchased in second quarter 2024 to settle certain pension liabilities, of which $8 million was recorded at Utility and $317 million was recorded at Parent & Other.
(d)Preferred dividend requirements of subsidiaries and noncontrolling interests is substantially derived from the Utility segment. See Note 6 to the financial statements in the Form 10-K for discussion of preferred stock and noncontrolling interests.
The following table presents segment financial information for Entergy’s single reportable segment, Utility, and a reconciliation to the corresponding consolidated amounts for Entergy Corporation for the three months ended June 30, 2025 and 2024:
UtilityParent & OtherEliminationsConsolidated
(In Thousands)
2025
Depreciation, amortization, and decommissioning$577,386 $1,766 $— $579,152 
Interest and investment income$160,248 $2,146 ($74,975)$87,419 
Interest expense$261,033 $61,475 ($434)$322,074 
Income taxes$152,836 ($14,437)$— $138,399 
2024
Depreciation, amortization, and decommissioning$557,962 $1,594 $— $559,556 
Interest and investment income$141,249 $9,985 ($80,647)$70,587 
Interest expense$225,511 $65,829 ($1,763)$289,577 
Income taxes$113,017 ($79,383)$— $33,634 

The following table presents segment financial information for Entergy’s single reportable segment, Utility, and a reconciliation to the corresponding consolidated amounts for Entergy Corporation for the six months ended June 30, 2025 and 2024:
UtilityParent & OtherEliminationsConsolidated
(In Thousands)
2025
Depreciation, amortization, and decommissioning$1,144,573 $3,451 $— $1,148,024 
Interest and investment income$267,423 $3,835 ($150,433)$120,825 
Interest expense$528,164 $124,344 ($643)$651,865 
Income taxes$267,109 ($28,669)$— $238,440 
Total assets as of June 30, 2025
$72,511,224 $777,674 ($4,905,758)$68,383,140 
Total expenditures for additions to long-lived assets$3,798,452 $606 $— $3,799,058 
2024
Asset write-offs, impairments, and related charges (credits)$131,775 $— $— $131,775 
Depreciation, amortization, and decommissioning$1,109,452 $3,146 $— $1,112,598 
Interest and investment income$366,499 $15,353 ($160,569)$221,283 
Interest expense$437,659 $121,242 ($2,124)$556,777 
Income taxes$147,565 ($92,938)$— $54,627 
Total assets as of December 31, 2024
$68,951,564 $721,459 ($4,882,991)$64,790,032 
Total expenditures for additions to long-lived assets$2,457,683 $693 $— $2,458,376 

Eliminations are primarily intersegment activity. All of Entergy’s goodwill is related to the Utility segment.
Registrant Subsidiaries

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has one operating and reportable segment, an integrated utility business which includes the generation, transmission, and distribution of electric power; and operation of a small natural gas distribution business at each of Entergy Louisiana and Entergy New Orleans through June 30, 2025. See Note 13 to the financial statements herein for discussion of the sale of the Entergy New Orleans and Entergy Louisiana natural gas distribution businesses on July 1, 2025. System Energy has one operating and reportable segment, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations are managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results. All segment financial information for the Registrant Subsidiaries is as reported on the respective financial statements for each of the Registrant Subsidiaries.
Entergy Mississippi [Member]  
Segment Reporting Disclosure [Text Block] BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy has a single reportable segment, Utility, which includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business in portions of Louisiana through June 30, 2025. See Note 13 to the financial statements herein for discussion of the sale of the natural gas distribution business on July 1, 2025.  Parent & Other includes the parent company, Entergy Corporation, and other business activity, including Entergy’s non-utility operations business, which is an operating segment that does not meet the quantitative thresholds for determining reportable segments.
The following table includes operating revenues and significant expense categories regularly provided to the chief operating decision maker for the Utility segment, a reconciliation of Utility operating revenues to Entergy’s consolidated operating revenues, and a reconciliation of Utility net income to consolidated net income and net income attributable to Entergy Corporation for the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
2025202420252024
(In Thousands)(In Thousands)
Utility operating revenues$3,315,723 $2,941,404 $6,145,320 $5,713,577 
Reconciliation of revenues:
Other revenues (a)13,144 12,227 30,448 34,703 
Elimination of intersegment revenues(18)(11)(45)(32)
Consolidated operating revenues3,328,849 2,953,620 6,175,723 5,748,248 
Less Utility expenses and other items:
Fuel, fuel-related expenses, and gas purchased for resale631,773 514,223 970,756 1,118,627 
Purchased power372,842 193,010 714,926 412,204 
Other operation and maintenance expenses713,296 685,990 1,375,770 1,366,705 
Other regulatory charges (credits) - net(55,957)125,607 (72,800)234,954 
Other Utility items (b)1,051,596 979,255 2,063,453 1,941,788 
Utility net income602,173 443,319 1,093,215 639,299 
Reconciliation of net income:
Non-cash pension settlement charge (c)— (316,738)— (316,738)
Income taxes on reconciling item noted above— 66,515 — 66,515 
Other loss(55,678)(62,479)(109,050)(102,362)
Elimination of intersegment loss(74,541)(78,885)(149,789)(158,446)
Consolidated net income471,954 51,732 834,376 128,268 
Preferred dividend requirements of subsidiaries and noncontrolling interests (d)4,024 2,810 5,686 4,065 
Net income attributable to Entergy Corporation$467,930 $48,922 $828,690 $124,203 

(a)See Note 12 to the financial statements herein and Note 19 to the financial statements in the Form 10-K for discussion of other revenues.
(b)Other Utility items includes nuclear refueling outage expenses, asset write-offs, decommissioning expenses, taxes other than income taxes, depreciation and amortization expenses, other income, interest expense, and income tax expense.
(c)See Note 11 to the financial statements in the Form 10-K for discussion of the one-time non-cash pension settlement charge resulting from a group annuity contract purchased in second quarter 2024 to settle certain pension liabilities, of which $8 million was recorded at Utility and $317 million was recorded at Parent & Other.
(d)Preferred dividend requirements of subsidiaries and noncontrolling interests is substantially derived from the Utility segment. See Note 6 to the financial statements in the Form 10-K for discussion of preferred stock and noncontrolling interests.
The following table presents segment financial information for Entergy’s single reportable segment, Utility, and a reconciliation to the corresponding consolidated amounts for Entergy Corporation for the three months ended June 30, 2025 and 2024:
UtilityParent & OtherEliminationsConsolidated
(In Thousands)
2025
Depreciation, amortization, and decommissioning$577,386 $1,766 $— $579,152 
Interest and investment income$160,248 $2,146 ($74,975)$87,419 
Interest expense$261,033 $61,475 ($434)$322,074 
Income taxes$152,836 ($14,437)$— $138,399 
2024
Depreciation, amortization, and decommissioning$557,962 $1,594 $— $559,556 
Interest and investment income$141,249 $9,985 ($80,647)$70,587 
Interest expense$225,511 $65,829 ($1,763)$289,577 
Income taxes$113,017 ($79,383)$— $33,634 

The following table presents segment financial information for Entergy’s single reportable segment, Utility, and a reconciliation to the corresponding consolidated amounts for Entergy Corporation for the six months ended June 30, 2025 and 2024:
UtilityParent & OtherEliminationsConsolidated
(In Thousands)
2025
Depreciation, amortization, and decommissioning$1,144,573 $3,451 $— $1,148,024 
Interest and investment income$267,423 $3,835 ($150,433)$120,825 
Interest expense$528,164 $124,344 ($643)$651,865 
Income taxes$267,109 ($28,669)$— $238,440 
Total assets as of June 30, 2025
$72,511,224 $777,674 ($4,905,758)$68,383,140 
Total expenditures for additions to long-lived assets$3,798,452 $606 $— $3,799,058 
2024
Asset write-offs, impairments, and related charges (credits)$131,775 $— $— $131,775 
Depreciation, amortization, and decommissioning$1,109,452 $3,146 $— $1,112,598 
Interest and investment income$366,499 $15,353 ($160,569)$221,283 
Interest expense$437,659 $121,242 ($2,124)$556,777 
Income taxes$147,565 ($92,938)$— $54,627 
Total assets as of December 31, 2024
$68,951,564 $721,459 ($4,882,991)$64,790,032 
Total expenditures for additions to long-lived assets$2,457,683 $693 $— $2,458,376 

Eliminations are primarily intersegment activity. All of Entergy’s goodwill is related to the Utility segment.
Registrant Subsidiaries

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has one operating and reportable segment, an integrated utility business which includes the generation, transmission, and distribution of electric power; and operation of a small natural gas distribution business at each of Entergy Louisiana and Entergy New Orleans through June 30, 2025. See Note 13 to the financial statements herein for discussion of the sale of the Entergy New Orleans and Entergy Louisiana natural gas distribution businesses on July 1, 2025. System Energy has one operating and reportable segment, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations are managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results. All segment financial information for the Registrant Subsidiaries is as reported on the respective financial statements for each of the Registrant Subsidiaries.
Entergy New Orleans [Member]  
Segment Reporting Disclosure [Text Block] BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy has a single reportable segment, Utility, which includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business in portions of Louisiana through June 30, 2025. See Note 13 to the financial statements herein for discussion of the sale of the natural gas distribution business on July 1, 2025.  Parent & Other includes the parent company, Entergy Corporation, and other business activity, including Entergy’s non-utility operations business, which is an operating segment that does not meet the quantitative thresholds for determining reportable segments.
The following table includes operating revenues and significant expense categories regularly provided to the chief operating decision maker for the Utility segment, a reconciliation of Utility operating revenues to Entergy’s consolidated operating revenues, and a reconciliation of Utility net income to consolidated net income and net income attributable to Entergy Corporation for the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
2025202420252024
(In Thousands)(In Thousands)
Utility operating revenues$3,315,723 $2,941,404 $6,145,320 $5,713,577 
Reconciliation of revenues:
Other revenues (a)13,144 12,227 30,448 34,703 
Elimination of intersegment revenues(18)(11)(45)(32)
Consolidated operating revenues3,328,849 2,953,620 6,175,723 5,748,248 
Less Utility expenses and other items:
Fuel, fuel-related expenses, and gas purchased for resale631,773 514,223 970,756 1,118,627 
Purchased power372,842 193,010 714,926 412,204 
Other operation and maintenance expenses713,296 685,990 1,375,770 1,366,705 
Other regulatory charges (credits) - net(55,957)125,607 (72,800)234,954 
Other Utility items (b)1,051,596 979,255 2,063,453 1,941,788 
Utility net income602,173 443,319 1,093,215 639,299 
Reconciliation of net income:
Non-cash pension settlement charge (c)— (316,738)— (316,738)
Income taxes on reconciling item noted above— 66,515 — 66,515 
Other loss(55,678)(62,479)(109,050)(102,362)
Elimination of intersegment loss(74,541)(78,885)(149,789)(158,446)
Consolidated net income471,954 51,732 834,376 128,268 
Preferred dividend requirements of subsidiaries and noncontrolling interests (d)4,024 2,810 5,686 4,065 
Net income attributable to Entergy Corporation$467,930 $48,922 $828,690 $124,203 

(a)See Note 12 to the financial statements herein and Note 19 to the financial statements in the Form 10-K for discussion of other revenues.
(b)Other Utility items includes nuclear refueling outage expenses, asset write-offs, decommissioning expenses, taxes other than income taxes, depreciation and amortization expenses, other income, interest expense, and income tax expense.
(c)See Note 11 to the financial statements in the Form 10-K for discussion of the one-time non-cash pension settlement charge resulting from a group annuity contract purchased in second quarter 2024 to settle certain pension liabilities, of which $8 million was recorded at Utility and $317 million was recorded at Parent & Other.
(d)Preferred dividend requirements of subsidiaries and noncontrolling interests is substantially derived from the Utility segment. See Note 6 to the financial statements in the Form 10-K for discussion of preferred stock and noncontrolling interests.
The following table presents segment financial information for Entergy’s single reportable segment, Utility, and a reconciliation to the corresponding consolidated amounts for Entergy Corporation for the three months ended June 30, 2025 and 2024:
UtilityParent & OtherEliminationsConsolidated
(In Thousands)
2025
Depreciation, amortization, and decommissioning$577,386 $1,766 $— $579,152 
Interest and investment income$160,248 $2,146 ($74,975)$87,419 
Interest expense$261,033 $61,475 ($434)$322,074 
Income taxes$152,836 ($14,437)$— $138,399 
2024
Depreciation, amortization, and decommissioning$557,962 $1,594 $— $559,556 
Interest and investment income$141,249 $9,985 ($80,647)$70,587 
Interest expense$225,511 $65,829 ($1,763)$289,577 
Income taxes$113,017 ($79,383)$— $33,634 

The following table presents segment financial information for Entergy’s single reportable segment, Utility, and a reconciliation to the corresponding consolidated amounts for Entergy Corporation for the six months ended June 30, 2025 and 2024:
UtilityParent & OtherEliminationsConsolidated
(In Thousands)
2025
Depreciation, amortization, and decommissioning$1,144,573 $3,451 $— $1,148,024 
Interest and investment income$267,423 $3,835 ($150,433)$120,825 
Interest expense$528,164 $124,344 ($643)$651,865 
Income taxes$267,109 ($28,669)$— $238,440 
Total assets as of June 30, 2025
$72,511,224 $777,674 ($4,905,758)$68,383,140 
Total expenditures for additions to long-lived assets$3,798,452 $606 $— $3,799,058 
2024
Asset write-offs, impairments, and related charges (credits)$131,775 $— $— $131,775 
Depreciation, amortization, and decommissioning$1,109,452 $3,146 $— $1,112,598 
Interest and investment income$366,499 $15,353 ($160,569)$221,283 
Interest expense$437,659 $121,242 ($2,124)$556,777 
Income taxes$147,565 ($92,938)$— $54,627 
Total assets as of December 31, 2024
$68,951,564 $721,459 ($4,882,991)$64,790,032 
Total expenditures for additions to long-lived assets$2,457,683 $693 $— $2,458,376 

Eliminations are primarily intersegment activity. All of Entergy’s goodwill is related to the Utility segment.
Registrant Subsidiaries

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has one operating and reportable segment, an integrated utility business which includes the generation, transmission, and distribution of electric power; and operation of a small natural gas distribution business at each of Entergy Louisiana and Entergy New Orleans through June 30, 2025. See Note 13 to the financial statements herein for discussion of the sale of the Entergy New Orleans and Entergy Louisiana natural gas distribution businesses on July 1, 2025. System Energy has one operating and reportable segment, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations are managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results. All segment financial information for the Registrant Subsidiaries is as reported on the respective financial statements for each of the Registrant Subsidiaries.
Entergy Texas [Member]  
Segment Reporting Disclosure [Text Block] BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy has a single reportable segment, Utility, which includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business in portions of Louisiana through June 30, 2025. See Note 13 to the financial statements herein for discussion of the sale of the natural gas distribution business on July 1, 2025.  Parent & Other includes the parent company, Entergy Corporation, and other business activity, including Entergy’s non-utility operations business, which is an operating segment that does not meet the quantitative thresholds for determining reportable segments.
The following table includes operating revenues and significant expense categories regularly provided to the chief operating decision maker for the Utility segment, a reconciliation of Utility operating revenues to Entergy’s consolidated operating revenues, and a reconciliation of Utility net income to consolidated net income and net income attributable to Entergy Corporation for the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
2025202420252024
(In Thousands)(In Thousands)
Utility operating revenues$3,315,723 $2,941,404 $6,145,320 $5,713,577 
Reconciliation of revenues:
Other revenues (a)13,144 12,227 30,448 34,703 
Elimination of intersegment revenues(18)(11)(45)(32)
Consolidated operating revenues3,328,849 2,953,620 6,175,723 5,748,248 
Less Utility expenses and other items:
Fuel, fuel-related expenses, and gas purchased for resale631,773 514,223 970,756 1,118,627 
Purchased power372,842 193,010 714,926 412,204 
Other operation and maintenance expenses713,296 685,990 1,375,770 1,366,705 
Other regulatory charges (credits) - net(55,957)125,607 (72,800)234,954 
Other Utility items (b)1,051,596 979,255 2,063,453 1,941,788 
Utility net income602,173 443,319 1,093,215 639,299 
Reconciliation of net income:
Non-cash pension settlement charge (c)— (316,738)— (316,738)
Income taxes on reconciling item noted above— 66,515 — 66,515 
Other loss(55,678)(62,479)(109,050)(102,362)
Elimination of intersegment loss(74,541)(78,885)(149,789)(158,446)
Consolidated net income471,954 51,732 834,376 128,268 
Preferred dividend requirements of subsidiaries and noncontrolling interests (d)4,024 2,810 5,686 4,065 
Net income attributable to Entergy Corporation$467,930 $48,922 $828,690 $124,203 

(a)See Note 12 to the financial statements herein and Note 19 to the financial statements in the Form 10-K for discussion of other revenues.
(b)Other Utility items includes nuclear refueling outage expenses, asset write-offs, decommissioning expenses, taxes other than income taxes, depreciation and amortization expenses, other income, interest expense, and income tax expense.
(c)See Note 11 to the financial statements in the Form 10-K for discussion of the one-time non-cash pension settlement charge resulting from a group annuity contract purchased in second quarter 2024 to settle certain pension liabilities, of which $8 million was recorded at Utility and $317 million was recorded at Parent & Other.
(d)Preferred dividend requirements of subsidiaries and noncontrolling interests is substantially derived from the Utility segment. See Note 6 to the financial statements in the Form 10-K for discussion of preferred stock and noncontrolling interests.
The following table presents segment financial information for Entergy’s single reportable segment, Utility, and a reconciliation to the corresponding consolidated amounts for Entergy Corporation for the three months ended June 30, 2025 and 2024:
UtilityParent & OtherEliminationsConsolidated
(In Thousands)
2025
Depreciation, amortization, and decommissioning$577,386 $1,766 $— $579,152 
Interest and investment income$160,248 $2,146 ($74,975)$87,419 
Interest expense$261,033 $61,475 ($434)$322,074 
Income taxes$152,836 ($14,437)$— $138,399 
2024
Depreciation, amortization, and decommissioning$557,962 $1,594 $— $559,556 
Interest and investment income$141,249 $9,985 ($80,647)$70,587 
Interest expense$225,511 $65,829 ($1,763)$289,577 
Income taxes$113,017 ($79,383)$— $33,634 

The following table presents segment financial information for Entergy’s single reportable segment, Utility, and a reconciliation to the corresponding consolidated amounts for Entergy Corporation for the six months ended June 30, 2025 and 2024:
UtilityParent & OtherEliminationsConsolidated
(In Thousands)
2025
Depreciation, amortization, and decommissioning$1,144,573 $3,451 $— $1,148,024 
Interest and investment income$267,423 $3,835 ($150,433)$120,825 
Interest expense$528,164 $124,344 ($643)$651,865 
Income taxes$267,109 ($28,669)$— $238,440 
Total assets as of June 30, 2025
$72,511,224 $777,674 ($4,905,758)$68,383,140 
Total expenditures for additions to long-lived assets$3,798,452 $606 $— $3,799,058 
2024
Asset write-offs, impairments, and related charges (credits)$131,775 $— $— $131,775 
Depreciation, amortization, and decommissioning$1,109,452 $3,146 $— $1,112,598 
Interest and investment income$366,499 $15,353 ($160,569)$221,283 
Interest expense$437,659 $121,242 ($2,124)$556,777 
Income taxes$147,565 ($92,938)$— $54,627 
Total assets as of December 31, 2024
$68,951,564 $721,459 ($4,882,991)$64,790,032 
Total expenditures for additions to long-lived assets$2,457,683 $693 $— $2,458,376 

Eliminations are primarily intersegment activity. All of Entergy’s goodwill is related to the Utility segment.
Registrant Subsidiaries

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has one operating and reportable segment, an integrated utility business which includes the generation, transmission, and distribution of electric power; and operation of a small natural gas distribution business at each of Entergy Louisiana and Entergy New Orleans through June 30, 2025. See Note 13 to the financial statements herein for discussion of the sale of the Entergy New Orleans and Entergy Louisiana natural gas distribution businesses on July 1, 2025. System Energy has one operating and reportable segment, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations are managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results. All segment financial information for the Registrant Subsidiaries is as reported on the respective financial statements for each of the Registrant Subsidiaries.
System Energy [Member]  
Segment Reporting Disclosure [Text Block] BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Entergy has a single reportable segment, Utility, which includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business in portions of Louisiana through June 30, 2025. See Note 13 to the financial statements herein for discussion of the sale of the natural gas distribution business on July 1, 2025.  Parent & Other includes the parent company, Entergy Corporation, and other business activity, including Entergy’s non-utility operations business, which is an operating segment that does not meet the quantitative thresholds for determining reportable segments.
The following table includes operating revenues and significant expense categories regularly provided to the chief operating decision maker for the Utility segment, a reconciliation of Utility operating revenues to Entergy’s consolidated operating revenues, and a reconciliation of Utility net income to consolidated net income and net income attributable to Entergy Corporation for the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
2025202420252024
(In Thousands)(In Thousands)
Utility operating revenues$3,315,723 $2,941,404 $6,145,320 $5,713,577 
Reconciliation of revenues:
Other revenues (a)13,144 12,227 30,448 34,703 
Elimination of intersegment revenues(18)(11)(45)(32)
Consolidated operating revenues3,328,849 2,953,620 6,175,723 5,748,248 
Less Utility expenses and other items:
Fuel, fuel-related expenses, and gas purchased for resale631,773 514,223 970,756 1,118,627 
Purchased power372,842 193,010 714,926 412,204 
Other operation and maintenance expenses713,296 685,990 1,375,770 1,366,705 
Other regulatory charges (credits) - net(55,957)125,607 (72,800)234,954 
Other Utility items (b)1,051,596 979,255 2,063,453 1,941,788 
Utility net income602,173 443,319 1,093,215 639,299 
Reconciliation of net income:
Non-cash pension settlement charge (c)— (316,738)— (316,738)
Income taxes on reconciling item noted above— 66,515 — 66,515 
Other loss(55,678)(62,479)(109,050)(102,362)
Elimination of intersegment loss(74,541)(78,885)(149,789)(158,446)
Consolidated net income471,954 51,732 834,376 128,268 
Preferred dividend requirements of subsidiaries and noncontrolling interests (d)4,024 2,810 5,686 4,065 
Net income attributable to Entergy Corporation$467,930 $48,922 $828,690 $124,203 

(a)See Note 12 to the financial statements herein and Note 19 to the financial statements in the Form 10-K for discussion of other revenues.
(b)Other Utility items includes nuclear refueling outage expenses, asset write-offs, decommissioning expenses, taxes other than income taxes, depreciation and amortization expenses, other income, interest expense, and income tax expense.
(c)See Note 11 to the financial statements in the Form 10-K for discussion of the one-time non-cash pension settlement charge resulting from a group annuity contract purchased in second quarter 2024 to settle certain pension liabilities, of which $8 million was recorded at Utility and $317 million was recorded at Parent & Other.
(d)Preferred dividend requirements of subsidiaries and noncontrolling interests is substantially derived from the Utility segment. See Note 6 to the financial statements in the Form 10-K for discussion of preferred stock and noncontrolling interests.
The following table presents segment financial information for Entergy’s single reportable segment, Utility, and a reconciliation to the corresponding consolidated amounts for Entergy Corporation for the three months ended June 30, 2025 and 2024:
UtilityParent & OtherEliminationsConsolidated
(In Thousands)
2025
Depreciation, amortization, and decommissioning$577,386 $1,766 $— $579,152 
Interest and investment income$160,248 $2,146 ($74,975)$87,419 
Interest expense$261,033 $61,475 ($434)$322,074 
Income taxes$152,836 ($14,437)$— $138,399 
2024
Depreciation, amortization, and decommissioning$557,962 $1,594 $— $559,556 
Interest and investment income$141,249 $9,985 ($80,647)$70,587 
Interest expense$225,511 $65,829 ($1,763)$289,577 
Income taxes$113,017 ($79,383)$— $33,634 

The following table presents segment financial information for Entergy’s single reportable segment, Utility, and a reconciliation to the corresponding consolidated amounts for Entergy Corporation for the six months ended June 30, 2025 and 2024:
UtilityParent & OtherEliminationsConsolidated
(In Thousands)
2025
Depreciation, amortization, and decommissioning$1,144,573 $3,451 $— $1,148,024 
Interest and investment income$267,423 $3,835 ($150,433)$120,825 
Interest expense$528,164 $124,344 ($643)$651,865 
Income taxes$267,109 ($28,669)$— $238,440 
Total assets as of June 30, 2025
$72,511,224 $777,674 ($4,905,758)$68,383,140 
Total expenditures for additions to long-lived assets$3,798,452 $606 $— $3,799,058 
2024
Asset write-offs, impairments, and related charges (credits)$131,775 $— $— $131,775 
Depreciation, amortization, and decommissioning$1,109,452 $3,146 $— $1,112,598 
Interest and investment income$366,499 $15,353 ($160,569)$221,283 
Interest expense$437,659 $121,242 ($2,124)$556,777 
Income taxes$147,565 ($92,938)$— $54,627 
Total assets as of December 31, 2024
$68,951,564 $721,459 ($4,882,991)$64,790,032 
Total expenditures for additions to long-lived assets$2,457,683 $693 $— $2,458,376 

Eliminations are primarily intersegment activity. All of Entergy’s goodwill is related to the Utility segment.
Registrant Subsidiaries

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has one operating and reportable segment, an integrated utility business which includes the generation, transmission, and distribution of electric power; and operation of a small natural gas distribution business at each of Entergy Louisiana and Entergy New Orleans through June 30, 2025. See Note 13 to the financial statements herein for discussion of the sale of the Entergy New Orleans and Entergy Louisiana natural gas distribution businesses on July 1, 2025. System Energy has one operating and reportable segment, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations are managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results. All segment financial information for the Registrant Subsidiaries is as reported on the respective financial statements for each of the Registrant Subsidiaries.
v3.25.2
Risk Management And Fair Values
 6 Months Ended
Jun. 30, 2025
Derivative Instruments and Hedging Activities Disclosure [Text Block] RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Market Risk

In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk associated with the price of fuel.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use commodity and financial instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

Derivatives

Entergy designates a significant portion of its derivative instruments as normal purchase/normal sale transactions due to their physical settlement provisions, including power purchase and sales agreements, fuel purchase agreements, and capacity contracts. Certain derivative instruments do not qualify for designation as normal purchase/normal sale transactions due to their financial settlement provisions. See further discussion below regarding the accounting for these derivative instruments.

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps as of June 30, 2025 is 9 months for Entergy Mississippi. The total volume of natural gas swaps outstanding as of June 30, 2025 is 9,493,000 MMBtu for Entergy and Entergy Mississippi. As of June 30, 2025, Entergy Louisiana and Entergy New Orleans had no outstanding natural gas swaps. Credit support for these natural gas swaps is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.
During the second quarter 2025, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2025 through May 31, 2026. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by the non-utility operations are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of June 30, 2025 is 102,393 GWh for Entergy, including 20,804 GWh for Entergy Arkansas, 55,064 GWh for Entergy Louisiana, 11,361 GWh for Entergy Mississippi, 3,660 GWh for Entergy New Orleans, and 11,505 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy’s non-utility operations business is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for the non-utility operations business as of June 30, 2025 and December 31, 2024. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of June 30, 2025 and for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2024.

The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of June 30, 2025 and December 31, 2024 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$49($1)$48
Liabilities:
Natural gas swapsOther current liabilities$3$—$3
2024
Assets:
Natural gas swapsPrepayments and other$2$—$2
Financial transmission rightsPrepayments and other$21($1)$20
Liabilities:
Financial transmission rightsOther current liabilities($—)$1$1

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $6 million as of June 30, 2025 and $2 million as of December 31, 2024
The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement
Location
Amount of gain
recorded in the income statement
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$11
Financial transmission rightsPurchased power expense(b)$66
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$3
Financial transmission rightsPurchased power expense(b)$47

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement
Location		Amount of gain (loss)
recorded in the income statement
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($1)
Financial transmission rightsPurchased power expense(b)$114
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($3)
Financial transmission rightsPurchased power expense(b)$100

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2025 and December 31, 2024 are shown in the tables below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$11.1$—$11.1Entergy Arkansas
Financial transmission rightsPrepayments and other$28.6($0.3)$28.3Entergy Louisiana
Financial transmission rightsPrepayments and other$1.5($0.1)$1.4Entergy Mississippi
Financial transmission rightsPrepayments and other$3.0$—$3.0Entergy New Orleans
Financial transmission rightsPrepayments and other$4.5($0.6)$3.9Entergy Texas
Liabilities:
Natural gas swapsOther current liabilities$3.0$—$3.0Entergy Mississippi

InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2024
Assets:
Natural gas swapsPrepayments and other$1.6$—$1.6Entergy Mississippi
Financial transmission rightsPrepayments and other$8.6($0.1)$8.5Entergy Arkansas
Financial transmission rightsPrepayments and other$8.7($0.1)$8.6Entergy Louisiana
Financial transmission rightsPrepayments and other$1.3$—$1.3Entergy New Orleans
Financial transmission rightsPrepayments and other$2.0($0.1)$1.9Entergy Texas
Liabilities:
Financial transmission rightsOther current liabilities($0.4)$0.9$0.5Entergy Mississippi

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi,
and $0.6 million for Entergy Texas as of June 30, 2025 and in the amount of $0.5 million for Entergy Arkansas, $0.1 million for Entergy Louisiana, $0.8 million for Entergy Mississippi, $0.1 million for Entergy New Orleans, and $0.3 million for Entergy Texas as of December 31, 2024.

The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$11.4(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$9.5(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$42.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$8.8(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$2.3(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($3.0)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$12.0(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$25.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$2.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$3.3(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$4.6(b)Entergy Texas
The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($1.2)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$28.2(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$64.1(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$5.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$11.1(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$5.8(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$2.3(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$0.5(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$38.9(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$41.2(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$4.4(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$12.1(b)Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market
participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following:

–quoted prices for similar assets or liabilities in active markets;
–quoted prices for identical assets or liabilities in inactive markets;
–inputs other than quoted prices that are observable for the asset or liability; or
–inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps valued using observable inputs.

•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight.  The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer.  The Accounting group reports to the Chief Accounting Officer.

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2025 and December 31, 2024.  The assessment of
the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels.
2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$1,012 $— $— $1,012 
Decommissioning trust funds (a):
Equity securities48 — — 48 
Debt securities857 1,250 — 2,107 
Common trusts (b)3,678 
Securitization recovery trust account1 — — 1 
Storm reserve escrow accounts303 — — 303 
Financial transmission rights— — 48 48 
$2,221 $1,250 $48 $7,197 
Liabilities:
Natural gas swaps$— $— $3 $3 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:    
Temporary cash investments$811 $— $— $811 
Decommissioning trust funds (a):
Equity securities30 — — 30 
Debt securities848 1,199 — 2,047 
Common trusts (b)3,486 
Securitization recovery trust account4 — — 4 
Storm reserve escrow accounts340 — — 340 
Natural gas swaps2 — — 2 
Financial transmission rights— — 20 20 
 $2,035 $1,199 $20 $6,740 
Liabilities:    
Financial transmission rights$— $— $1 $1 

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.
(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025 and 2024:
20252024
(In Millions)
Balance as of April 1,$7 $9 
Issuances of financial transmission rights49 53 
Gains included as a regulatory liability/asset58 34 
Settlements(66)(47)
Balance as of June 30,$48 $49 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025 and 2024:
20252024
(In Millions)
Balance as of January 1,$20 $21 
Issuances of financial transmission rights49 53 
Gains included as a regulatory liability/asset93 75 
Settlements(114)(100)
Balance as of June 30,$48 $49 

The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO.

The following tables set forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2025 and December 31, 2024.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels.

Entergy Arkansas

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$182.4 $— $— $182.4 
Decommissioning trust funds (a):
Equity securities23.3 — — 23.3 
Debt securities266.3 327.8 — 594.1 
Common trusts (b)1,069.3 
Financial transmission rights— — 11.1 11.1 
$472.0 $327.8 $11.1 $1,880.2 
2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$3.4 $— $— $3.4 
Decommissioning trust funds (a):
Equity securities12.9 — — 12.9 
Debt securities259.9 319.1 — 579.0 
Common trusts (b)1,012.5 
Financial transmission rights— — 8.5 8.5 
$276.2 $319.1 $8.5 $1,616.3 

Entergy Louisiana

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$298.3 $— $— $298.3 
Decommissioning trust funds (a):
Equity securities20.8 — — 20.8 
Debt securities332.4 598.9 — 931.3 
Common trusts (b)1,588.4 
Storm reserve escrow account228.4 — — 228.4 
Financial transmission rights— — 28.3 28.3 
$879.9 $598.9 $28.3 $3,095.5 

2024Level 1Level 2Level 3Total
 (In Millions)
Assets:    
Temporary cash investments$326.8 $— $— $326.8 
Decommissioning trust funds (a):
Equity securities14.5 — — 14.5 
Debt securities326.0 582.1 — 908.1 
Common trusts (b)1,506.5 
Storm reserve escrow account256.7 — — 256.7 
Financial transmission rights— — 8.6 8.6 
 $924.0 $582.1 $8.6 $3,021.2 
Entergy Mississippi

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$401.3 $— $— $401.3 
Financial transmission rights— — 1.4 1.4 
$401.3 $— $1.4 $402.7 
Liabilities:
Natural gas swaps$— $— $3.0 $3.0 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$155.5 $— $— $155.5 
Natural gas swaps1.6 — — 1.6 
 $157.1 $— $— $157.1 
Liabilities:
Financial transmission rights$— $— $0.5 $0.5 

Entergy New Orleans

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Storm reserve escrow account$75.1 $— $— $75.1 
Financial transmission rights— — 3.0 3.0 
$75.1 $— $3.0 $78.1 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$31.4 $— $— $31.4 
Securitization recovery trust account1.6 — — 1.6 
Storm reserve escrow account83.7 — — 83.7 
Financial transmission rights— — 1.3 1.3 
$116.7 $— $1.3 $118.0 
Entergy Texas

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$17.7 $— $— $17.7 
Securitization recovery trust account1.0 — — 1.0 
Financial transmission rights— — 3.9 3.9 
$18.7 $— $3.9 $22.6 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$184.7 $— $— $184.7 
Securitization recovery trust account2.7 — — 2.7 
Financial transmission rights— — 1.9 1.9 
$187.4 $— $1.9 $189.3 

System Energy

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$31.7 $— $— $31.7 
Decommissioning trust funds (a):
Equity securities4.1 — — 4.1 
Debt securities258.6 323.5 — 582.1 
Common trusts (b)1,020.1 
$294.4 $323.5 $— $1,638.0 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$28.5 $— $— $28.5 
Decommissioning trust funds (a):
Equity securities2.4 — — 2.4 
Debt securities262.4 297.4 — 559.8 
Common trusts (b)966.9 
$293.3 $297.4 $— $1,557.6 

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.
(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$3.0 $3.4 ($0.1)$0.4 $0.4 
Issuances of financial transmission rights11.8 28.7 1.5 3.0 4.0 
Gains included as a regulatory liability/asset5.8 38.2 3.1 8.4 1.8 
Settlements(9.5)(42.0)(3.1)(8.8)(2.3)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$2.8 $4.1 $0.6 $0.5 $1.2 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset7.7 19.1 1.2 2.6 2.7 
Settlements(12.0)(25.0)(2.1)(3.3)(4.6)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$8.6 $8.6 ($0.5)$1.3 $1.9 
Issuances of financial transmission rights11.8 28.7 1.5 2.9 4.0 
Gains included as a regulatory liability/asset18.9 55.1 5.5 9.9 3.8 
Settlements(28.2)(64.1)(5.1)(11.1)(5.8)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$6.0 $9.8 $1.4 $1.1 $2.4 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset31.4 29.6 1.4 3.1 9.0 
Settlements(38.9)(41.2)(3.1)(4.4)(12.1)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 
Entergy Arkansas [Member]  
Derivative Instruments and Hedging Activities Disclosure [Text Block] RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Market Risk

In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk associated with the price of fuel.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use commodity and financial instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

Derivatives

Entergy designates a significant portion of its derivative instruments as normal purchase/normal sale transactions due to their physical settlement provisions, including power purchase and sales agreements, fuel purchase agreements, and capacity contracts. Certain derivative instruments do not qualify for designation as normal purchase/normal sale transactions due to their financial settlement provisions. See further discussion below regarding the accounting for these derivative instruments.

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps as of June 30, 2025 is 9 months for Entergy Mississippi. The total volume of natural gas swaps outstanding as of June 30, 2025 is 9,493,000 MMBtu for Entergy and Entergy Mississippi. As of June 30, 2025, Entergy Louisiana and Entergy New Orleans had no outstanding natural gas swaps. Credit support for these natural gas swaps is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.
During the second quarter 2025, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2025 through May 31, 2026. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by the non-utility operations are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of June 30, 2025 is 102,393 GWh for Entergy, including 20,804 GWh for Entergy Arkansas, 55,064 GWh for Entergy Louisiana, 11,361 GWh for Entergy Mississippi, 3,660 GWh for Entergy New Orleans, and 11,505 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy’s non-utility operations business is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for the non-utility operations business as of June 30, 2025 and December 31, 2024. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of June 30, 2025 and for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2024.

The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of June 30, 2025 and December 31, 2024 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$49($1)$48
Liabilities:
Natural gas swapsOther current liabilities$3$—$3
2024
Assets:
Natural gas swapsPrepayments and other$2$—$2
Financial transmission rightsPrepayments and other$21($1)$20
Liabilities:
Financial transmission rightsOther current liabilities($—)$1$1

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $6 million as of June 30, 2025 and $2 million as of December 31, 2024
The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement
Location
Amount of gain
recorded in the income statement
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$11
Financial transmission rightsPurchased power expense(b)$66
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$3
Financial transmission rightsPurchased power expense(b)$47

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement
Location		Amount of gain (loss)
recorded in the income statement
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($1)
Financial transmission rightsPurchased power expense(b)$114
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($3)
Financial transmission rightsPurchased power expense(b)$100

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2025 and December 31, 2024 are shown in the tables below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$11.1$—$11.1Entergy Arkansas
Financial transmission rightsPrepayments and other$28.6($0.3)$28.3Entergy Louisiana
Financial transmission rightsPrepayments and other$1.5($0.1)$1.4Entergy Mississippi
Financial transmission rightsPrepayments and other$3.0$—$3.0Entergy New Orleans
Financial transmission rightsPrepayments and other$4.5($0.6)$3.9Entergy Texas
Liabilities:
Natural gas swapsOther current liabilities$3.0$—$3.0Entergy Mississippi

InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2024
Assets:
Natural gas swapsPrepayments and other$1.6$—$1.6Entergy Mississippi
Financial transmission rightsPrepayments and other$8.6($0.1)$8.5Entergy Arkansas
Financial transmission rightsPrepayments and other$8.7($0.1)$8.6Entergy Louisiana
Financial transmission rightsPrepayments and other$1.3$—$1.3Entergy New Orleans
Financial transmission rightsPrepayments and other$2.0($0.1)$1.9Entergy Texas
Liabilities:
Financial transmission rightsOther current liabilities($0.4)$0.9$0.5Entergy Mississippi

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi,
and $0.6 million for Entergy Texas as of June 30, 2025 and in the amount of $0.5 million for Entergy Arkansas, $0.1 million for Entergy Louisiana, $0.8 million for Entergy Mississippi, $0.1 million for Entergy New Orleans, and $0.3 million for Entergy Texas as of December 31, 2024.

The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$11.4(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$9.5(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$42.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$8.8(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$2.3(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($3.0)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$12.0(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$25.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$2.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$3.3(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$4.6(b)Entergy Texas
The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($1.2)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$28.2(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$64.1(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$5.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$11.1(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$5.8(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$2.3(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$0.5(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$38.9(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$41.2(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$4.4(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$12.1(b)Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market
participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following:

–quoted prices for similar assets or liabilities in active markets;
–quoted prices for identical assets or liabilities in inactive markets;
–inputs other than quoted prices that are observable for the asset or liability; or
–inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps valued using observable inputs.

•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight.  The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer.  The Accounting group reports to the Chief Accounting Officer.

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2025 and December 31, 2024.  The assessment of
the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels.
2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$1,012 $— $— $1,012 
Decommissioning trust funds (a):
Equity securities48 — — 48 
Debt securities857 1,250 — 2,107 
Common trusts (b)3,678 
Securitization recovery trust account1 — — 1 
Storm reserve escrow accounts303 — — 303 
Financial transmission rights— — 48 48 
$2,221 $1,250 $48 $7,197 
Liabilities:
Natural gas swaps$— $— $3 $3 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:    
Temporary cash investments$811 $— $— $811 
Decommissioning trust funds (a):
Equity securities30 — — 30 
Debt securities848 1,199 — 2,047 
Common trusts (b)3,486 
Securitization recovery trust account4 — — 4 
Storm reserve escrow accounts340 — — 340 
Natural gas swaps2 — — 2 
Financial transmission rights— — 20 20 
 $2,035 $1,199 $20 $6,740 
Liabilities:    
Financial transmission rights$— $— $1 $1 

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.
(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025 and 2024:
20252024
(In Millions)
Balance as of April 1,$7 $9 
Issuances of financial transmission rights49 53 
Gains included as a regulatory liability/asset58 34 
Settlements(66)(47)
Balance as of June 30,$48 $49 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025 and 2024:
20252024
(In Millions)
Balance as of January 1,$20 $21 
Issuances of financial transmission rights49 53 
Gains included as a regulatory liability/asset93 75 
Settlements(114)(100)
Balance as of June 30,$48 $49 

The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO.

The following tables set forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2025 and December 31, 2024.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels.

Entergy Arkansas

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$182.4 $— $— $182.4 
Decommissioning trust funds (a):
Equity securities23.3 — — 23.3 
Debt securities266.3 327.8 — 594.1 
Common trusts (b)1,069.3 
Financial transmission rights— — 11.1 11.1 
$472.0 $327.8 $11.1 $1,880.2 
2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$3.4 $— $— $3.4 
Decommissioning trust funds (a):
Equity securities12.9 — — 12.9 
Debt securities259.9 319.1 — 579.0 
Common trusts (b)1,012.5 
Financial transmission rights— — 8.5 8.5 
$276.2 $319.1 $8.5 $1,616.3 

Entergy Louisiana

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$298.3 $— $— $298.3 
Decommissioning trust funds (a):
Equity securities20.8 — — 20.8 
Debt securities332.4 598.9 — 931.3 
Common trusts (b)1,588.4 
Storm reserve escrow account228.4 — — 228.4 
Financial transmission rights— — 28.3 28.3 
$879.9 $598.9 $28.3 $3,095.5 

2024Level 1Level 2Level 3Total
 (In Millions)
Assets:    
Temporary cash investments$326.8 $— $— $326.8 
Decommissioning trust funds (a):
Equity securities14.5 — — 14.5 
Debt securities326.0 582.1 — 908.1 
Common trusts (b)1,506.5 
Storm reserve escrow account256.7 — — 256.7 
Financial transmission rights— — 8.6 8.6 
 $924.0 $582.1 $8.6 $3,021.2 
Entergy Mississippi

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$401.3 $— $— $401.3 
Financial transmission rights— — 1.4 1.4 
$401.3 $— $1.4 $402.7 
Liabilities:
Natural gas swaps$— $— $3.0 $3.0 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$155.5 $— $— $155.5 
Natural gas swaps1.6 — — 1.6 
 $157.1 $— $— $157.1 
Liabilities:
Financial transmission rights$— $— $0.5 $0.5 

Entergy New Orleans

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Storm reserve escrow account$75.1 $— $— $75.1 
Financial transmission rights— — 3.0 3.0 
$75.1 $— $3.0 $78.1 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$31.4 $— $— $31.4 
Securitization recovery trust account1.6 — — 1.6 
Storm reserve escrow account83.7 — — 83.7 
Financial transmission rights— — 1.3 1.3 
$116.7 $— $1.3 $118.0 
Entergy Texas

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$17.7 $— $— $17.7 
Securitization recovery trust account1.0 — — 1.0 
Financial transmission rights— — 3.9 3.9 
$18.7 $— $3.9 $22.6 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$184.7 $— $— $184.7 
Securitization recovery trust account2.7 — — 2.7 
Financial transmission rights— — 1.9 1.9 
$187.4 $— $1.9 $189.3 

System Energy

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$31.7 $— $— $31.7 
Decommissioning trust funds (a):
Equity securities4.1 — — 4.1 
Debt securities258.6 323.5 — 582.1 
Common trusts (b)1,020.1 
$294.4 $323.5 $— $1,638.0 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$28.5 $— $— $28.5 
Decommissioning trust funds (a):
Equity securities2.4 — — 2.4 
Debt securities262.4 297.4 — 559.8 
Common trusts (b)966.9 
$293.3 $297.4 $— $1,557.6 

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.
(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$3.0 $3.4 ($0.1)$0.4 $0.4 
Issuances of financial transmission rights11.8 28.7 1.5 3.0 4.0 
Gains included as a regulatory liability/asset5.8 38.2 3.1 8.4 1.8 
Settlements(9.5)(42.0)(3.1)(8.8)(2.3)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$2.8 $4.1 $0.6 $0.5 $1.2 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset7.7 19.1 1.2 2.6 2.7 
Settlements(12.0)(25.0)(2.1)(3.3)(4.6)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$8.6 $8.6 ($0.5)$1.3 $1.9 
Issuances of financial transmission rights11.8 28.7 1.5 2.9 4.0 
Gains included as a regulatory liability/asset18.9 55.1 5.5 9.9 3.8 
Settlements(28.2)(64.1)(5.1)(11.1)(5.8)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$6.0 $9.8 $1.4 $1.1 $2.4 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset31.4 29.6 1.4 3.1 9.0 
Settlements(38.9)(41.2)(3.1)(4.4)(12.1)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 
Entergy Louisiana [Member]  
Derivative Instruments and Hedging Activities Disclosure [Text Block] RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Market Risk

In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk associated with the price of fuel.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use commodity and financial instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

Derivatives

Entergy designates a significant portion of its derivative instruments as normal purchase/normal sale transactions due to their physical settlement provisions, including power purchase and sales agreements, fuel purchase agreements, and capacity contracts. Certain derivative instruments do not qualify for designation as normal purchase/normal sale transactions due to their financial settlement provisions. See further discussion below regarding the accounting for these derivative instruments.

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps as of June 30, 2025 is 9 months for Entergy Mississippi. The total volume of natural gas swaps outstanding as of June 30, 2025 is 9,493,000 MMBtu for Entergy and Entergy Mississippi. As of June 30, 2025, Entergy Louisiana and Entergy New Orleans had no outstanding natural gas swaps. Credit support for these natural gas swaps is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.
During the second quarter 2025, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2025 through May 31, 2026. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by the non-utility operations are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of June 30, 2025 is 102,393 GWh for Entergy, including 20,804 GWh for Entergy Arkansas, 55,064 GWh for Entergy Louisiana, 11,361 GWh for Entergy Mississippi, 3,660 GWh for Entergy New Orleans, and 11,505 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy’s non-utility operations business is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for the non-utility operations business as of June 30, 2025 and December 31, 2024. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of June 30, 2025 and for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2024.

The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of June 30, 2025 and December 31, 2024 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$49($1)$48
Liabilities:
Natural gas swapsOther current liabilities$3$—$3
2024
Assets:
Natural gas swapsPrepayments and other$2$—$2
Financial transmission rightsPrepayments and other$21($1)$20
Liabilities:
Financial transmission rightsOther current liabilities($—)$1$1

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $6 million as of June 30, 2025 and $2 million as of December 31, 2024
The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement
Location
Amount of gain
recorded in the income statement
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$11
Financial transmission rightsPurchased power expense(b)$66
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$3
Financial transmission rightsPurchased power expense(b)$47

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement
Location		Amount of gain (loss)
recorded in the income statement
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($1)
Financial transmission rightsPurchased power expense(b)$114
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($3)
Financial transmission rightsPurchased power expense(b)$100

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2025 and December 31, 2024 are shown in the tables below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$11.1$—$11.1Entergy Arkansas
Financial transmission rightsPrepayments and other$28.6($0.3)$28.3Entergy Louisiana
Financial transmission rightsPrepayments and other$1.5($0.1)$1.4Entergy Mississippi
Financial transmission rightsPrepayments and other$3.0$—$3.0Entergy New Orleans
Financial transmission rightsPrepayments and other$4.5($0.6)$3.9Entergy Texas
Liabilities:
Natural gas swapsOther current liabilities$3.0$—$3.0Entergy Mississippi

InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2024
Assets:
Natural gas swapsPrepayments and other$1.6$—$1.6Entergy Mississippi
Financial transmission rightsPrepayments and other$8.6($0.1)$8.5Entergy Arkansas
Financial transmission rightsPrepayments and other$8.7($0.1)$8.6Entergy Louisiana
Financial transmission rightsPrepayments and other$1.3$—$1.3Entergy New Orleans
Financial transmission rightsPrepayments and other$2.0($0.1)$1.9Entergy Texas
Liabilities:
Financial transmission rightsOther current liabilities($0.4)$0.9$0.5Entergy Mississippi

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi,
and $0.6 million for Entergy Texas as of June 30, 2025 and in the amount of $0.5 million for Entergy Arkansas, $0.1 million for Entergy Louisiana, $0.8 million for Entergy Mississippi, $0.1 million for Entergy New Orleans, and $0.3 million for Entergy Texas as of December 31, 2024.

The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$11.4(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$9.5(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$42.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$8.8(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$2.3(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($3.0)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$12.0(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$25.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$2.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$3.3(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$4.6(b)Entergy Texas
The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($1.2)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$28.2(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$64.1(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$5.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$11.1(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$5.8(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$2.3(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$0.5(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$38.9(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$41.2(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$4.4(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$12.1(b)Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market
participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following:

–quoted prices for similar assets or liabilities in active markets;
–quoted prices for identical assets or liabilities in inactive markets;
–inputs other than quoted prices that are observable for the asset or liability; or
–inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps valued using observable inputs.

•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight.  The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer.  The Accounting group reports to the Chief Accounting Officer.

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2025 and December 31, 2024.  The assessment of
the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels.
2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$1,012 $— $— $1,012 
Decommissioning trust funds (a):
Equity securities48 — — 48 
Debt securities857 1,250 — 2,107 
Common trusts (b)3,678 
Securitization recovery trust account1 — — 1 
Storm reserve escrow accounts303 — — 303 
Financial transmission rights— — 48 48 
$2,221 $1,250 $48 $7,197 
Liabilities:
Natural gas swaps$— $— $3 $3 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:    
Temporary cash investments$811 $— $— $811 
Decommissioning trust funds (a):
Equity securities30 — — 30 
Debt securities848 1,199 — 2,047 
Common trusts (b)3,486 
Securitization recovery trust account4 — — 4 
Storm reserve escrow accounts340 — — 340 
Natural gas swaps2 — — 2 
Financial transmission rights— — 20 20 
 $2,035 $1,199 $20 $6,740 
Liabilities:    
Financial transmission rights$— $— $1 $1 

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.
(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025 and 2024:
20252024
(In Millions)
Balance as of April 1,$7 $9 
Issuances of financial transmission rights49 53 
Gains included as a regulatory liability/asset58 34 
Settlements(66)(47)
Balance as of June 30,$48 $49 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025 and 2024:
20252024
(In Millions)
Balance as of January 1,$20 $21 
Issuances of financial transmission rights49 53 
Gains included as a regulatory liability/asset93 75 
Settlements(114)(100)
Balance as of June 30,$48 $49 

The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO.

The following tables set forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2025 and December 31, 2024.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels.

Entergy Arkansas

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$182.4 $— $— $182.4 
Decommissioning trust funds (a):
Equity securities23.3 — — 23.3 
Debt securities266.3 327.8 — 594.1 
Common trusts (b)1,069.3 
Financial transmission rights— — 11.1 11.1 
$472.0 $327.8 $11.1 $1,880.2 
2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$3.4 $— $— $3.4 
Decommissioning trust funds (a):
Equity securities12.9 — — 12.9 
Debt securities259.9 319.1 — 579.0 
Common trusts (b)1,012.5 
Financial transmission rights— — 8.5 8.5 
$276.2 $319.1 $8.5 $1,616.3 

Entergy Louisiana

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$298.3 $— $— $298.3 
Decommissioning trust funds (a):
Equity securities20.8 — — 20.8 
Debt securities332.4 598.9 — 931.3 
Common trusts (b)1,588.4 
Storm reserve escrow account228.4 — — 228.4 
Financial transmission rights— — 28.3 28.3 
$879.9 $598.9 $28.3 $3,095.5 

2024Level 1Level 2Level 3Total
 (In Millions)
Assets:    
Temporary cash investments$326.8 $— $— $326.8 
Decommissioning trust funds (a):
Equity securities14.5 — — 14.5 
Debt securities326.0 582.1 — 908.1 
Common trusts (b)1,506.5 
Storm reserve escrow account256.7 — — 256.7 
Financial transmission rights— — 8.6 8.6 
 $924.0 $582.1 $8.6 $3,021.2 
Entergy Mississippi

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$401.3 $— $— $401.3 
Financial transmission rights— — 1.4 1.4 
$401.3 $— $1.4 $402.7 
Liabilities:
Natural gas swaps$— $— $3.0 $3.0 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$155.5 $— $— $155.5 
Natural gas swaps1.6 — — 1.6 
 $157.1 $— $— $157.1 
Liabilities:
Financial transmission rights$— $— $0.5 $0.5 

Entergy New Orleans

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Storm reserve escrow account$75.1 $— $— $75.1 
Financial transmission rights— — 3.0 3.0 
$75.1 $— $3.0 $78.1 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$31.4 $— $— $31.4 
Securitization recovery trust account1.6 — — 1.6 
Storm reserve escrow account83.7 — — 83.7 
Financial transmission rights— — 1.3 1.3 
$116.7 $— $1.3 $118.0 
Entergy Texas

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$17.7 $— $— $17.7 
Securitization recovery trust account1.0 — — 1.0 
Financial transmission rights— — 3.9 3.9 
$18.7 $— $3.9 $22.6 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$184.7 $— $— $184.7 
Securitization recovery trust account2.7 — — 2.7 
Financial transmission rights— — 1.9 1.9 
$187.4 $— $1.9 $189.3 

System Energy

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$31.7 $— $— $31.7 
Decommissioning trust funds (a):
Equity securities4.1 — — 4.1 
Debt securities258.6 323.5 — 582.1 
Common trusts (b)1,020.1 
$294.4 $323.5 $— $1,638.0 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$28.5 $— $— $28.5 
Decommissioning trust funds (a):
Equity securities2.4 — — 2.4 
Debt securities262.4 297.4 — 559.8 
Common trusts (b)966.9 
$293.3 $297.4 $— $1,557.6 

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.
(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$3.0 $3.4 ($0.1)$0.4 $0.4 
Issuances of financial transmission rights11.8 28.7 1.5 3.0 4.0 
Gains included as a regulatory liability/asset5.8 38.2 3.1 8.4 1.8 
Settlements(9.5)(42.0)(3.1)(8.8)(2.3)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$2.8 $4.1 $0.6 $0.5 $1.2 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset7.7 19.1 1.2 2.6 2.7 
Settlements(12.0)(25.0)(2.1)(3.3)(4.6)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$8.6 $8.6 ($0.5)$1.3 $1.9 
Issuances of financial transmission rights11.8 28.7 1.5 2.9 4.0 
Gains included as a regulatory liability/asset18.9 55.1 5.5 9.9 3.8 
Settlements(28.2)(64.1)(5.1)(11.1)(5.8)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$6.0 $9.8 $1.4 $1.1 $2.4 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset31.4 29.6 1.4 3.1 9.0 
Settlements(38.9)(41.2)(3.1)(4.4)(12.1)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 
Entergy Mississippi [Member]  
Derivative Instruments and Hedging Activities Disclosure [Text Block] RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Market Risk

In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk associated with the price of fuel.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use commodity and financial instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

Derivatives

Entergy designates a significant portion of its derivative instruments as normal purchase/normal sale transactions due to their physical settlement provisions, including power purchase and sales agreements, fuel purchase agreements, and capacity contracts. Certain derivative instruments do not qualify for designation as normal purchase/normal sale transactions due to their financial settlement provisions. See further discussion below regarding the accounting for these derivative instruments.

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps as of June 30, 2025 is 9 months for Entergy Mississippi. The total volume of natural gas swaps outstanding as of June 30, 2025 is 9,493,000 MMBtu for Entergy and Entergy Mississippi. As of June 30, 2025, Entergy Louisiana and Entergy New Orleans had no outstanding natural gas swaps. Credit support for these natural gas swaps is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.
During the second quarter 2025, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2025 through May 31, 2026. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by the non-utility operations are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of June 30, 2025 is 102,393 GWh for Entergy, including 20,804 GWh for Entergy Arkansas, 55,064 GWh for Entergy Louisiana, 11,361 GWh for Entergy Mississippi, 3,660 GWh for Entergy New Orleans, and 11,505 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy’s non-utility operations business is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for the non-utility operations business as of June 30, 2025 and December 31, 2024. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of June 30, 2025 and for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2024.

The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of June 30, 2025 and December 31, 2024 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$49($1)$48
Liabilities:
Natural gas swapsOther current liabilities$3$—$3
2024
Assets:
Natural gas swapsPrepayments and other$2$—$2
Financial transmission rightsPrepayments and other$21($1)$20
Liabilities:
Financial transmission rightsOther current liabilities($—)$1$1

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $6 million as of June 30, 2025 and $2 million as of December 31, 2024
The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement
Location
Amount of gain
recorded in the income statement
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$11
Financial transmission rightsPurchased power expense(b)$66
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$3
Financial transmission rightsPurchased power expense(b)$47

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement
Location		Amount of gain (loss)
recorded in the income statement
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($1)
Financial transmission rightsPurchased power expense(b)$114
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($3)
Financial transmission rightsPurchased power expense(b)$100

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2025 and December 31, 2024 are shown in the tables below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$11.1$—$11.1Entergy Arkansas
Financial transmission rightsPrepayments and other$28.6($0.3)$28.3Entergy Louisiana
Financial transmission rightsPrepayments and other$1.5($0.1)$1.4Entergy Mississippi
Financial transmission rightsPrepayments and other$3.0$—$3.0Entergy New Orleans
Financial transmission rightsPrepayments and other$4.5($0.6)$3.9Entergy Texas
Liabilities:
Natural gas swapsOther current liabilities$3.0$—$3.0Entergy Mississippi

InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2024
Assets:
Natural gas swapsPrepayments and other$1.6$—$1.6Entergy Mississippi
Financial transmission rightsPrepayments and other$8.6($0.1)$8.5Entergy Arkansas
Financial transmission rightsPrepayments and other$8.7($0.1)$8.6Entergy Louisiana
Financial transmission rightsPrepayments and other$1.3$—$1.3Entergy New Orleans
Financial transmission rightsPrepayments and other$2.0($0.1)$1.9Entergy Texas
Liabilities:
Financial transmission rightsOther current liabilities($0.4)$0.9$0.5Entergy Mississippi

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi,
and $0.6 million for Entergy Texas as of June 30, 2025 and in the amount of $0.5 million for Entergy Arkansas, $0.1 million for Entergy Louisiana, $0.8 million for Entergy Mississippi, $0.1 million for Entergy New Orleans, and $0.3 million for Entergy Texas as of December 31, 2024.

The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$11.4(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$9.5(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$42.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$8.8(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$2.3(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($3.0)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$12.0(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$25.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$2.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$3.3(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$4.6(b)Entergy Texas
The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($1.2)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$28.2(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$64.1(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$5.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$11.1(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$5.8(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$2.3(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$0.5(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$38.9(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$41.2(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$4.4(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$12.1(b)Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market
participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following:

–quoted prices for similar assets or liabilities in active markets;
–quoted prices for identical assets or liabilities in inactive markets;
–inputs other than quoted prices that are observable for the asset or liability; or
–inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps valued using observable inputs.

•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight.  The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer.  The Accounting group reports to the Chief Accounting Officer.

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2025 and December 31, 2024.  The assessment of
the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels.
2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$1,012 $— $— $1,012 
Decommissioning trust funds (a):
Equity securities48 — — 48 
Debt securities857 1,250 — 2,107 
Common trusts (b)3,678 
Securitization recovery trust account1 — — 1 
Storm reserve escrow accounts303 — — 303 
Financial transmission rights— — 48 48 
$2,221 $1,250 $48 $7,197 
Liabilities:
Natural gas swaps$— $— $3 $3 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:    
Temporary cash investments$811 $— $— $811 
Decommissioning trust funds (a):
Equity securities30 — — 30 
Debt securities848 1,199 — 2,047 
Common trusts (b)3,486 
Securitization recovery trust account4 — — 4 
Storm reserve escrow accounts340 — — 340 
Natural gas swaps2 — — 2 
Financial transmission rights— — 20 20 
 $2,035 $1,199 $20 $6,740 
Liabilities:    
Financial transmission rights$— $— $1 $1 

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.
(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025 and 2024:
20252024
(In Millions)
Balance as of April 1,$7 $9 
Issuances of financial transmission rights49 53 
Gains included as a regulatory liability/asset58 34 
Settlements(66)(47)
Balance as of June 30,$48 $49 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025 and 2024:
20252024
(In Millions)
Balance as of January 1,$20 $21 
Issuances of financial transmission rights49 53 
Gains included as a regulatory liability/asset93 75 
Settlements(114)(100)
Balance as of June 30,$48 $49 

The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO.

The following tables set forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2025 and December 31, 2024.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels.

Entergy Arkansas

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$182.4 $— $— $182.4 
Decommissioning trust funds (a):
Equity securities23.3 — — 23.3 
Debt securities266.3 327.8 — 594.1 
Common trusts (b)1,069.3 
Financial transmission rights— — 11.1 11.1 
$472.0 $327.8 $11.1 $1,880.2 
2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$3.4 $— $— $3.4 
Decommissioning trust funds (a):
Equity securities12.9 — — 12.9 
Debt securities259.9 319.1 — 579.0 
Common trusts (b)1,012.5 
Financial transmission rights— — 8.5 8.5 
$276.2 $319.1 $8.5 $1,616.3 

Entergy Louisiana

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$298.3 $— $— $298.3 
Decommissioning trust funds (a):
Equity securities20.8 — — 20.8 
Debt securities332.4 598.9 — 931.3 
Common trusts (b)1,588.4 
Storm reserve escrow account228.4 — — 228.4 
Financial transmission rights— — 28.3 28.3 
$879.9 $598.9 $28.3 $3,095.5 

2024Level 1Level 2Level 3Total
 (In Millions)
Assets:    
Temporary cash investments$326.8 $— $— $326.8 
Decommissioning trust funds (a):
Equity securities14.5 — — 14.5 
Debt securities326.0 582.1 — 908.1 
Common trusts (b)1,506.5 
Storm reserve escrow account256.7 — — 256.7 
Financial transmission rights— — 8.6 8.6 
 $924.0 $582.1 $8.6 $3,021.2 
Entergy Mississippi

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$401.3 $— $— $401.3 
Financial transmission rights— — 1.4 1.4 
$401.3 $— $1.4 $402.7 
Liabilities:
Natural gas swaps$— $— $3.0 $3.0 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$155.5 $— $— $155.5 
Natural gas swaps1.6 — — 1.6 
 $157.1 $— $— $157.1 
Liabilities:
Financial transmission rights$— $— $0.5 $0.5 

Entergy New Orleans

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Storm reserve escrow account$75.1 $— $— $75.1 
Financial transmission rights— — 3.0 3.0 
$75.1 $— $3.0 $78.1 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$31.4 $— $— $31.4 
Securitization recovery trust account1.6 — — 1.6 
Storm reserve escrow account83.7 — — 83.7 
Financial transmission rights— — 1.3 1.3 
$116.7 $— $1.3 $118.0 
Entergy Texas

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$17.7 $— $— $17.7 
Securitization recovery trust account1.0 — — 1.0 
Financial transmission rights— — 3.9 3.9 
$18.7 $— $3.9 $22.6 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$184.7 $— $— $184.7 
Securitization recovery trust account2.7 — — 2.7 
Financial transmission rights— — 1.9 1.9 
$187.4 $— $1.9 $189.3 

System Energy

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$31.7 $— $— $31.7 
Decommissioning trust funds (a):
Equity securities4.1 — — 4.1 
Debt securities258.6 323.5 — 582.1 
Common trusts (b)1,020.1 
$294.4 $323.5 $— $1,638.0 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$28.5 $— $— $28.5 
Decommissioning trust funds (a):
Equity securities2.4 — — 2.4 
Debt securities262.4 297.4 — 559.8 
Common trusts (b)966.9 
$293.3 $297.4 $— $1,557.6 

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.
(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$3.0 $3.4 ($0.1)$0.4 $0.4 
Issuances of financial transmission rights11.8 28.7 1.5 3.0 4.0 
Gains included as a regulatory liability/asset5.8 38.2 3.1 8.4 1.8 
Settlements(9.5)(42.0)(3.1)(8.8)(2.3)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$2.8 $4.1 $0.6 $0.5 $1.2 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset7.7 19.1 1.2 2.6 2.7 
Settlements(12.0)(25.0)(2.1)(3.3)(4.6)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$8.6 $8.6 ($0.5)$1.3 $1.9 
Issuances of financial transmission rights11.8 28.7 1.5 2.9 4.0 
Gains included as a regulatory liability/asset18.9 55.1 5.5 9.9 3.8 
Settlements(28.2)(64.1)(5.1)(11.1)(5.8)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$6.0 $9.8 $1.4 $1.1 $2.4 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset31.4 29.6 1.4 3.1 9.0 
Settlements(38.9)(41.2)(3.1)(4.4)(12.1)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 
Entergy New Orleans [Member]  
Derivative Instruments and Hedging Activities Disclosure [Text Block] RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Market Risk

In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk associated with the price of fuel.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use commodity and financial instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

Derivatives

Entergy designates a significant portion of its derivative instruments as normal purchase/normal sale transactions due to their physical settlement provisions, including power purchase and sales agreements, fuel purchase agreements, and capacity contracts. Certain derivative instruments do not qualify for designation as normal purchase/normal sale transactions due to their financial settlement provisions. See further discussion below regarding the accounting for these derivative instruments.

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps as of June 30, 2025 is 9 months for Entergy Mississippi. The total volume of natural gas swaps outstanding as of June 30, 2025 is 9,493,000 MMBtu for Entergy and Entergy Mississippi. As of June 30, 2025, Entergy Louisiana and Entergy New Orleans had no outstanding natural gas swaps. Credit support for these natural gas swaps is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.
During the second quarter 2025, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2025 through May 31, 2026. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by the non-utility operations are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of June 30, 2025 is 102,393 GWh for Entergy, including 20,804 GWh for Entergy Arkansas, 55,064 GWh for Entergy Louisiana, 11,361 GWh for Entergy Mississippi, 3,660 GWh for Entergy New Orleans, and 11,505 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy’s non-utility operations business is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for the non-utility operations business as of June 30, 2025 and December 31, 2024. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of June 30, 2025 and for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2024.

The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of June 30, 2025 and December 31, 2024 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$49($1)$48
Liabilities:
Natural gas swapsOther current liabilities$3$—$3
2024
Assets:
Natural gas swapsPrepayments and other$2$—$2
Financial transmission rightsPrepayments and other$21($1)$20
Liabilities:
Financial transmission rightsOther current liabilities($—)$1$1

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $6 million as of June 30, 2025 and $2 million as of December 31, 2024
The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement
Location
Amount of gain
recorded in the income statement
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$11
Financial transmission rightsPurchased power expense(b)$66
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$3
Financial transmission rightsPurchased power expense(b)$47

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement
Location		Amount of gain (loss)
recorded in the income statement
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($1)
Financial transmission rightsPurchased power expense(b)$114
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($3)
Financial transmission rightsPurchased power expense(b)$100

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2025 and December 31, 2024 are shown in the tables below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$11.1$—$11.1Entergy Arkansas
Financial transmission rightsPrepayments and other$28.6($0.3)$28.3Entergy Louisiana
Financial transmission rightsPrepayments and other$1.5($0.1)$1.4Entergy Mississippi
Financial transmission rightsPrepayments and other$3.0$—$3.0Entergy New Orleans
Financial transmission rightsPrepayments and other$4.5($0.6)$3.9Entergy Texas
Liabilities:
Natural gas swapsOther current liabilities$3.0$—$3.0Entergy Mississippi

InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2024
Assets:
Natural gas swapsPrepayments and other$1.6$—$1.6Entergy Mississippi
Financial transmission rightsPrepayments and other$8.6($0.1)$8.5Entergy Arkansas
Financial transmission rightsPrepayments and other$8.7($0.1)$8.6Entergy Louisiana
Financial transmission rightsPrepayments and other$1.3$—$1.3Entergy New Orleans
Financial transmission rightsPrepayments and other$2.0($0.1)$1.9Entergy Texas
Liabilities:
Financial transmission rightsOther current liabilities($0.4)$0.9$0.5Entergy Mississippi

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi,
and $0.6 million for Entergy Texas as of June 30, 2025 and in the amount of $0.5 million for Entergy Arkansas, $0.1 million for Entergy Louisiana, $0.8 million for Entergy Mississippi, $0.1 million for Entergy New Orleans, and $0.3 million for Entergy Texas as of December 31, 2024.

The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$11.4(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$9.5(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$42.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$8.8(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$2.3(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($3.0)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$12.0(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$25.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$2.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$3.3(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$4.6(b)Entergy Texas
The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($1.2)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$28.2(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$64.1(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$5.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$11.1(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$5.8(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$2.3(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$0.5(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$38.9(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$41.2(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$4.4(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$12.1(b)Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market
participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following:

–quoted prices for similar assets or liabilities in active markets;
–quoted prices for identical assets or liabilities in inactive markets;
–inputs other than quoted prices that are observable for the asset or liability; or
–inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps valued using observable inputs.

•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight.  The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer.  The Accounting group reports to the Chief Accounting Officer.

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2025 and December 31, 2024.  The assessment of
the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels.
2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$1,012 $— $— $1,012 
Decommissioning trust funds (a):
Equity securities48 — — 48 
Debt securities857 1,250 — 2,107 
Common trusts (b)3,678 
Securitization recovery trust account1 — — 1 
Storm reserve escrow accounts303 — — 303 
Financial transmission rights— — 48 48 
$2,221 $1,250 $48 $7,197 
Liabilities:
Natural gas swaps$— $— $3 $3 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:    
Temporary cash investments$811 $— $— $811 
Decommissioning trust funds (a):
Equity securities30 — — 30 
Debt securities848 1,199 — 2,047 
Common trusts (b)3,486 
Securitization recovery trust account4 — — 4 
Storm reserve escrow accounts340 — — 340 
Natural gas swaps2 — — 2 
Financial transmission rights— — 20 20 
 $2,035 $1,199 $20 $6,740 
Liabilities:    
Financial transmission rights$— $— $1 $1 

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.
(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025 and 2024:
20252024
(In Millions)
Balance as of April 1,$7 $9 
Issuances of financial transmission rights49 53 
Gains included as a regulatory liability/asset58 34 
Settlements(66)(47)
Balance as of June 30,$48 $49 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025 and 2024:
20252024
(In Millions)
Balance as of January 1,$20 $21 
Issuances of financial transmission rights49 53 
Gains included as a regulatory liability/asset93 75 
Settlements(114)(100)
Balance as of June 30,$48 $49 

The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO.

The following tables set forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2025 and December 31, 2024.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels.

Entergy Arkansas

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$182.4 $— $— $182.4 
Decommissioning trust funds (a):
Equity securities23.3 — — 23.3 
Debt securities266.3 327.8 — 594.1 
Common trusts (b)1,069.3 
Financial transmission rights— — 11.1 11.1 
$472.0 $327.8 $11.1 $1,880.2 
2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$3.4 $— $— $3.4 
Decommissioning trust funds (a):
Equity securities12.9 — — 12.9 
Debt securities259.9 319.1 — 579.0 
Common trusts (b)1,012.5 
Financial transmission rights— — 8.5 8.5 
$276.2 $319.1 $8.5 $1,616.3 

Entergy Louisiana

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$298.3 $— $— $298.3 
Decommissioning trust funds (a):
Equity securities20.8 — — 20.8 
Debt securities332.4 598.9 — 931.3 
Common trusts (b)1,588.4 
Storm reserve escrow account228.4 — — 228.4 
Financial transmission rights— — 28.3 28.3 
$879.9 $598.9 $28.3 $3,095.5 

2024Level 1Level 2Level 3Total
 (In Millions)
Assets:    
Temporary cash investments$326.8 $— $— $326.8 
Decommissioning trust funds (a):
Equity securities14.5 — — 14.5 
Debt securities326.0 582.1 — 908.1 
Common trusts (b)1,506.5 
Storm reserve escrow account256.7 — — 256.7 
Financial transmission rights— — 8.6 8.6 
 $924.0 $582.1 $8.6 $3,021.2 
Entergy Mississippi

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$401.3 $— $— $401.3 
Financial transmission rights— — 1.4 1.4 
$401.3 $— $1.4 $402.7 
Liabilities:
Natural gas swaps$— $— $3.0 $3.0 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$155.5 $— $— $155.5 
Natural gas swaps1.6 — — 1.6 
 $157.1 $— $— $157.1 
Liabilities:
Financial transmission rights$— $— $0.5 $0.5 

Entergy New Orleans

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Storm reserve escrow account$75.1 $— $— $75.1 
Financial transmission rights— — 3.0 3.0 
$75.1 $— $3.0 $78.1 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$31.4 $— $— $31.4 
Securitization recovery trust account1.6 — — 1.6 
Storm reserve escrow account83.7 — — 83.7 
Financial transmission rights— — 1.3 1.3 
$116.7 $— $1.3 $118.0 
Entergy Texas

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$17.7 $— $— $17.7 
Securitization recovery trust account1.0 — — 1.0 
Financial transmission rights— — 3.9 3.9 
$18.7 $— $3.9 $22.6 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$184.7 $— $— $184.7 
Securitization recovery trust account2.7 — — 2.7 
Financial transmission rights— — 1.9 1.9 
$187.4 $— $1.9 $189.3 

System Energy

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$31.7 $— $— $31.7 
Decommissioning trust funds (a):
Equity securities4.1 — — 4.1 
Debt securities258.6 323.5 — 582.1 
Common trusts (b)1,020.1 
$294.4 $323.5 $— $1,638.0 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$28.5 $— $— $28.5 
Decommissioning trust funds (a):
Equity securities2.4 — — 2.4 
Debt securities262.4 297.4 — 559.8 
Common trusts (b)966.9 
$293.3 $297.4 $— $1,557.6 

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.
(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$3.0 $3.4 ($0.1)$0.4 $0.4 
Issuances of financial transmission rights11.8 28.7 1.5 3.0 4.0 
Gains included as a regulatory liability/asset5.8 38.2 3.1 8.4 1.8 
Settlements(9.5)(42.0)(3.1)(8.8)(2.3)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$2.8 $4.1 $0.6 $0.5 $1.2 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset7.7 19.1 1.2 2.6 2.7 
Settlements(12.0)(25.0)(2.1)(3.3)(4.6)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$8.6 $8.6 ($0.5)$1.3 $1.9 
Issuances of financial transmission rights11.8 28.7 1.5 2.9 4.0 
Gains included as a regulatory liability/asset18.9 55.1 5.5 9.9 3.8 
Settlements(28.2)(64.1)(5.1)(11.1)(5.8)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$6.0 $9.8 $1.4 $1.1 $2.4 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset31.4 29.6 1.4 3.1 9.0 
Settlements(38.9)(41.2)(3.1)(4.4)(12.1)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 
Entergy Texas [Member]  
Derivative Instruments and Hedging Activities Disclosure [Text Block] RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Market Risk

In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk associated with the price of fuel.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use commodity and financial instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

Derivatives

Entergy designates a significant portion of its derivative instruments as normal purchase/normal sale transactions due to their physical settlement provisions, including power purchase and sales agreements, fuel purchase agreements, and capacity contracts. Certain derivative instruments do not qualify for designation as normal purchase/normal sale transactions due to their financial settlement provisions. See further discussion below regarding the accounting for these derivative instruments.

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps as of June 30, 2025 is 9 months for Entergy Mississippi. The total volume of natural gas swaps outstanding as of June 30, 2025 is 9,493,000 MMBtu for Entergy and Entergy Mississippi. As of June 30, 2025, Entergy Louisiana and Entergy New Orleans had no outstanding natural gas swaps. Credit support for these natural gas swaps is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.
During the second quarter 2025, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2025 through May 31, 2026. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by the non-utility operations are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of June 30, 2025 is 102,393 GWh for Entergy, including 20,804 GWh for Entergy Arkansas, 55,064 GWh for Entergy Louisiana, 11,361 GWh for Entergy Mississippi, 3,660 GWh for Entergy New Orleans, and 11,505 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy’s non-utility operations business is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for the non-utility operations business as of June 30, 2025 and December 31, 2024. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of June 30, 2025 and for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2024.

The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of June 30, 2025 and December 31, 2024 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$49($1)$48
Liabilities:
Natural gas swapsOther current liabilities$3$—$3
2024
Assets:
Natural gas swapsPrepayments and other$2$—$2
Financial transmission rightsPrepayments and other$21($1)$20
Liabilities:
Financial transmission rightsOther current liabilities($—)$1$1

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $6 million as of June 30, 2025 and $2 million as of December 31, 2024
The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement
Location
Amount of gain
recorded in the income statement
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$11
Financial transmission rightsPurchased power expense(b)$66
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$3
Financial transmission rightsPurchased power expense(b)$47

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement
Location		Amount of gain (loss)
recorded in the income statement
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($1)
Financial transmission rightsPurchased power expense(b)$114
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($3)
Financial transmission rightsPurchased power expense(b)$100

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2025 and December 31, 2024 are shown in the tables below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$11.1$—$11.1Entergy Arkansas
Financial transmission rightsPrepayments and other$28.6($0.3)$28.3Entergy Louisiana
Financial transmission rightsPrepayments and other$1.5($0.1)$1.4Entergy Mississippi
Financial transmission rightsPrepayments and other$3.0$—$3.0Entergy New Orleans
Financial transmission rightsPrepayments and other$4.5($0.6)$3.9Entergy Texas
Liabilities:
Natural gas swapsOther current liabilities$3.0$—$3.0Entergy Mississippi

InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2024
Assets:
Natural gas swapsPrepayments and other$1.6$—$1.6Entergy Mississippi
Financial transmission rightsPrepayments and other$8.6($0.1)$8.5Entergy Arkansas
Financial transmission rightsPrepayments and other$8.7($0.1)$8.6Entergy Louisiana
Financial transmission rightsPrepayments and other$1.3$—$1.3Entergy New Orleans
Financial transmission rightsPrepayments and other$2.0($0.1)$1.9Entergy Texas
Liabilities:
Financial transmission rightsOther current liabilities($0.4)$0.9$0.5Entergy Mississippi

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi,
and $0.6 million for Entergy Texas as of June 30, 2025 and in the amount of $0.5 million for Entergy Arkansas, $0.1 million for Entergy Louisiana, $0.8 million for Entergy Mississippi, $0.1 million for Entergy New Orleans, and $0.3 million for Entergy Texas as of December 31, 2024.

The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$11.4(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$9.5(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$42.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$8.8(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$2.3(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($3.0)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$12.0(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$25.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$2.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$3.3(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$4.6(b)Entergy Texas
The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($1.2)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$28.2(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$64.1(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$5.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$11.1(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$5.8(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$2.3(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$0.5(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$38.9(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$41.2(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$4.4(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$12.1(b)Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market
participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following:

–quoted prices for similar assets or liabilities in active markets;
–quoted prices for identical assets or liabilities in inactive markets;
–inputs other than quoted prices that are observable for the asset or liability; or
–inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps valued using observable inputs.

•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight.  The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer.  The Accounting group reports to the Chief Accounting Officer.

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2025 and December 31, 2024.  The assessment of
the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels.
2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$1,012 $— $— $1,012 
Decommissioning trust funds (a):
Equity securities48 — — 48 
Debt securities857 1,250 — 2,107 
Common trusts (b)3,678 
Securitization recovery trust account1 — — 1 
Storm reserve escrow accounts303 — — 303 
Financial transmission rights— — 48 48 
$2,221 $1,250 $48 $7,197 
Liabilities:
Natural gas swaps$— $— $3 $3 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:    
Temporary cash investments$811 $— $— $811 
Decommissioning trust funds (a):
Equity securities30 — — 30 
Debt securities848 1,199 — 2,047 
Common trusts (b)3,486 
Securitization recovery trust account4 — — 4 
Storm reserve escrow accounts340 — — 340 
Natural gas swaps2 — — 2 
Financial transmission rights— — 20 20 
 $2,035 $1,199 $20 $6,740 
Liabilities:    
Financial transmission rights$— $— $1 $1 

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.
(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025 and 2024:
20252024
(In Millions)
Balance as of April 1,$7 $9 
Issuances of financial transmission rights49 53 
Gains included as a regulatory liability/asset58 34 
Settlements(66)(47)
Balance as of June 30,$48 $49 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025 and 2024:
20252024
(In Millions)
Balance as of January 1,$20 $21 
Issuances of financial transmission rights49 53 
Gains included as a regulatory liability/asset93 75 
Settlements(114)(100)
Balance as of June 30,$48 $49 

The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO.

The following tables set forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2025 and December 31, 2024.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels.

Entergy Arkansas

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$182.4 $— $— $182.4 
Decommissioning trust funds (a):
Equity securities23.3 — — 23.3 
Debt securities266.3 327.8 — 594.1 
Common trusts (b)1,069.3 
Financial transmission rights— — 11.1 11.1 
$472.0 $327.8 $11.1 $1,880.2 
2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$3.4 $— $— $3.4 
Decommissioning trust funds (a):
Equity securities12.9 — — 12.9 
Debt securities259.9 319.1 — 579.0 
Common trusts (b)1,012.5 
Financial transmission rights— — 8.5 8.5 
$276.2 $319.1 $8.5 $1,616.3 

Entergy Louisiana

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$298.3 $— $— $298.3 
Decommissioning trust funds (a):
Equity securities20.8 — — 20.8 
Debt securities332.4 598.9 — 931.3 
Common trusts (b)1,588.4 
Storm reserve escrow account228.4 — — 228.4 
Financial transmission rights— — 28.3 28.3 
$879.9 $598.9 $28.3 $3,095.5 

2024Level 1Level 2Level 3Total
 (In Millions)
Assets:    
Temporary cash investments$326.8 $— $— $326.8 
Decommissioning trust funds (a):
Equity securities14.5 — — 14.5 
Debt securities326.0 582.1 — 908.1 
Common trusts (b)1,506.5 
Storm reserve escrow account256.7 — — 256.7 
Financial transmission rights— — 8.6 8.6 
 $924.0 $582.1 $8.6 $3,021.2 
Entergy Mississippi

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$401.3 $— $— $401.3 
Financial transmission rights— — 1.4 1.4 
$401.3 $— $1.4 $402.7 
Liabilities:
Natural gas swaps$— $— $3.0 $3.0 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$155.5 $— $— $155.5 
Natural gas swaps1.6 — — 1.6 
 $157.1 $— $— $157.1 
Liabilities:
Financial transmission rights$— $— $0.5 $0.5 

Entergy New Orleans

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Storm reserve escrow account$75.1 $— $— $75.1 
Financial transmission rights— — 3.0 3.0 
$75.1 $— $3.0 $78.1 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$31.4 $— $— $31.4 
Securitization recovery trust account1.6 — — 1.6 
Storm reserve escrow account83.7 — — 83.7 
Financial transmission rights— — 1.3 1.3 
$116.7 $— $1.3 $118.0 
Entergy Texas

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$17.7 $— $— $17.7 
Securitization recovery trust account1.0 — — 1.0 
Financial transmission rights— — 3.9 3.9 
$18.7 $— $3.9 $22.6 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$184.7 $— $— $184.7 
Securitization recovery trust account2.7 — — 2.7 
Financial transmission rights— — 1.9 1.9 
$187.4 $— $1.9 $189.3 

System Energy

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$31.7 $— $— $31.7 
Decommissioning trust funds (a):
Equity securities4.1 — — 4.1 
Debt securities258.6 323.5 — 582.1 
Common trusts (b)1,020.1 
$294.4 $323.5 $— $1,638.0 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$28.5 $— $— $28.5 
Decommissioning trust funds (a):
Equity securities2.4 — — 2.4 
Debt securities262.4 297.4 — 559.8 
Common trusts (b)966.9 
$293.3 $297.4 $— $1,557.6 

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.
(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$3.0 $3.4 ($0.1)$0.4 $0.4 
Issuances of financial transmission rights11.8 28.7 1.5 3.0 4.0 
Gains included as a regulatory liability/asset5.8 38.2 3.1 8.4 1.8 
Settlements(9.5)(42.0)(3.1)(8.8)(2.3)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$2.8 $4.1 $0.6 $0.5 $1.2 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset7.7 19.1 1.2 2.6 2.7 
Settlements(12.0)(25.0)(2.1)(3.3)(4.6)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$8.6 $8.6 ($0.5)$1.3 $1.9 
Issuances of financial transmission rights11.8 28.7 1.5 2.9 4.0 
Gains included as a regulatory liability/asset18.9 55.1 5.5 9.9 3.8 
Settlements(28.2)(64.1)(5.1)(11.1)(5.8)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$6.0 $9.8 $1.4 $1.1 $2.4 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset31.4 29.6 1.4 3.1 9.0 
Settlements(38.9)(41.2)(3.1)(4.4)(12.1)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 
System Energy [Member]  
Derivative Instruments and Hedging Activities Disclosure [Text Block] RISK MANAGEMENT AND FAIR VALUES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Market Risk

In the normal course of business, Entergy is exposed to a number of market risks.  Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument.  All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk.  Entergy uses derivatives primarily to mitigate commodity price risk associated with the price of fuel.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation.  To the extent approved by their retail regulators, the Utility operating companies use commodity and financial instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

Derivatives

Entergy designates a significant portion of its derivative instruments as normal purchase/normal sale transactions due to their physical settlement provisions, including power purchase and sales agreements, fuel purchase agreements, and capacity contracts. Certain derivative instruments do not qualify for designation as normal purchase/normal sale transactions due to their financial settlement provisions. See further discussion below regarding the accounting for these derivative instruments.

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps as of June 30, 2025 is 9 months for Entergy Mississippi. The total volume of natural gas swaps outstanding as of June 30, 2025 is 9,493,000 MMBtu for Entergy and Entergy Mississippi. As of June 30, 2025, Entergy Louisiana and Entergy New Orleans had no outstanding natural gas swaps. Credit support for these natural gas swaps is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.
During the second quarter 2025, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2025 through May 31, 2026. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by the non-utility operations are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of June 30, 2025 is 102,393 GWh for Entergy, including 20,804 GWh for Entergy Arkansas, 55,064 GWh for Entergy Louisiana, 11,361 GWh for Entergy Mississippi, 3,660 GWh for Entergy New Orleans, and 11,505 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy’s non-utility operations business is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for the non-utility operations business as of June 30, 2025 and December 31, 2024. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of June 30, 2025 and for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2024.

The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of June 30, 2025 and December 31, 2024 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$49($1)$48
Liabilities:
Natural gas swapsOther current liabilities$3$—$3
2024
Assets:
Natural gas swapsPrepayments and other$2$—$2
Financial transmission rightsPrepayments and other$21($1)$20
Liabilities:
Financial transmission rightsOther current liabilities($—)$1$1

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $6 million as of June 30, 2025 and $2 million as of December 31, 2024
The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement
Location
Amount of gain
recorded in the income statement
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$11
Financial transmission rightsPurchased power expense(b)$66
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$3
Financial transmission rightsPurchased power expense(b)$47

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement
Location		Amount of gain (loss)
recorded in the income statement
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($1)
Financial transmission rightsPurchased power expense(b)$114
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($3)
Financial transmission rightsPurchased power expense(b)$100

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2025 and December 31, 2024 are shown in the tables below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$11.1$—$11.1Entergy Arkansas
Financial transmission rightsPrepayments and other$28.6($0.3)$28.3Entergy Louisiana
Financial transmission rightsPrepayments and other$1.5($0.1)$1.4Entergy Mississippi
Financial transmission rightsPrepayments and other$3.0$—$3.0Entergy New Orleans
Financial transmission rightsPrepayments and other$4.5($0.6)$3.9Entergy Texas
Liabilities:
Natural gas swapsOther current liabilities$3.0$—$3.0Entergy Mississippi

InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2024
Assets:
Natural gas swapsPrepayments and other$1.6$—$1.6Entergy Mississippi
Financial transmission rightsPrepayments and other$8.6($0.1)$8.5Entergy Arkansas
Financial transmission rightsPrepayments and other$8.7($0.1)$8.6Entergy Louisiana
Financial transmission rightsPrepayments and other$1.3$—$1.3Entergy New Orleans
Financial transmission rightsPrepayments and other$2.0($0.1)$1.9Entergy Texas
Liabilities:
Financial transmission rightsOther current liabilities($0.4)$0.9$0.5Entergy Mississippi

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi,
and $0.6 million for Entergy Texas as of June 30, 2025 and in the amount of $0.5 million for Entergy Arkansas, $0.1 million for Entergy Louisiana, $0.8 million for Entergy Mississippi, $0.1 million for Entergy New Orleans, and $0.3 million for Entergy Texas as of December 31, 2024.

The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$11.4(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$9.5(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$42.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$8.8(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$2.3(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($3.0)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$12.0(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$25.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$2.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$3.3(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$4.6(b)Entergy Texas
The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($1.2)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$28.2(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$64.1(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$5.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$11.1(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$5.8(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$2.3(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$0.5(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$38.9(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$41.2(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$4.4(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$12.1(b)Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling.  Considerable judgment is required in developing the estimates of fair value.  Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange.  Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market
participants at the date of measurement.  Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value.  The inputs can be readily observable, corroborated by market data, or generally unobservable.  Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value.  The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following:

–quoted prices for similar assets or liabilities in active markets;
–quoted prices for identical assets or liabilities in inactive markets;
–inputs other than quoted prices that are observable for the asset or liability; or
–inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps valued using observable inputs.

•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices.  They are classified as Level 3 assets and liabilities.  The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight.  The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer.  The Accounting group reports to the Chief Accounting Officer.

The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2025 and December 31, 2024.  The assessment of
the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels.
2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$1,012 $— $— $1,012 
Decommissioning trust funds (a):
Equity securities48 — — 48 
Debt securities857 1,250 — 2,107 
Common trusts (b)3,678 
Securitization recovery trust account1 — — 1 
Storm reserve escrow accounts303 — — 303 
Financial transmission rights— — 48 48 
$2,221 $1,250 $48 $7,197 
Liabilities:
Natural gas swaps$— $— $3 $3 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:    
Temporary cash investments$811 $— $— $811 
Decommissioning trust funds (a):
Equity securities30 — — 30 
Debt securities848 1,199 — 2,047 
Common trusts (b)3,486 
Securitization recovery trust account4 — — 4 
Storm reserve escrow accounts340 — — 340 
Natural gas swaps2 — — 2 
Financial transmission rights— — 20 20 
 $2,035 $1,199 $20 $6,740 
Liabilities:    
Financial transmission rights$— $— $1 $1 

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.
(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025 and 2024:
20252024
(In Millions)
Balance as of April 1,$7 $9 
Issuances of financial transmission rights49 53 
Gains included as a regulatory liability/asset58 34 
Settlements(66)(47)
Balance as of June 30,$48 $49 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025 and 2024:
20252024
(In Millions)
Balance as of January 1,$20 $21 
Issuances of financial transmission rights49 53 
Gains included as a regulatory liability/asset93 75 
Settlements(114)(100)
Balance as of June 30,$48 $49 

The fair values of the Level 3 financial transmission rights are based on unobservable inputs calculated internally and verified against historical pricing data published by MISO.

The following tables set forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2025 and December 31, 2024.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels.

Entergy Arkansas

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$182.4 $— $— $182.4 
Decommissioning trust funds (a):
Equity securities23.3 — — 23.3 
Debt securities266.3 327.8 — 594.1 
Common trusts (b)1,069.3 
Financial transmission rights— — 11.1 11.1 
$472.0 $327.8 $11.1 $1,880.2 
2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$3.4 $— $— $3.4 
Decommissioning trust funds (a):
Equity securities12.9 — — 12.9 
Debt securities259.9 319.1 — 579.0 
Common trusts (b)1,012.5 
Financial transmission rights— — 8.5 8.5 
$276.2 $319.1 $8.5 $1,616.3 

Entergy Louisiana

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$298.3 $— $— $298.3 
Decommissioning trust funds (a):
Equity securities20.8 — — 20.8 
Debt securities332.4 598.9 — 931.3 
Common trusts (b)1,588.4 
Storm reserve escrow account228.4 — — 228.4 
Financial transmission rights— — 28.3 28.3 
$879.9 $598.9 $28.3 $3,095.5 

2024Level 1Level 2Level 3Total
 (In Millions)
Assets:    
Temporary cash investments$326.8 $— $— $326.8 
Decommissioning trust funds (a):
Equity securities14.5 — — 14.5 
Debt securities326.0 582.1 — 908.1 
Common trusts (b)1,506.5 
Storm reserve escrow account256.7 — — 256.7 
Financial transmission rights— — 8.6 8.6 
 $924.0 $582.1 $8.6 $3,021.2 
Entergy Mississippi

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$401.3 $— $— $401.3 
Financial transmission rights— — 1.4 1.4 
$401.3 $— $1.4 $402.7 
Liabilities:
Natural gas swaps$— $— $3.0 $3.0 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$155.5 $— $— $155.5 
Natural gas swaps1.6 — — 1.6 
 $157.1 $— $— $157.1 
Liabilities:
Financial transmission rights$— $— $0.5 $0.5 

Entergy New Orleans

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Storm reserve escrow account$75.1 $— $— $75.1 
Financial transmission rights— — 3.0 3.0 
$75.1 $— $3.0 $78.1 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$31.4 $— $— $31.4 
Securitization recovery trust account1.6 — — 1.6 
Storm reserve escrow account83.7 — — 83.7 
Financial transmission rights— — 1.3 1.3 
$116.7 $— $1.3 $118.0 
Entergy Texas

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$17.7 $— $— $17.7 
Securitization recovery trust account1.0 — — 1.0 
Financial transmission rights— — 3.9 3.9 
$18.7 $— $3.9 $22.6 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$184.7 $— $— $184.7 
Securitization recovery trust account2.7 — — 2.7 
Financial transmission rights— — 1.9 1.9 
$187.4 $— $1.9 $189.3 

System Energy

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$31.7 $— $— $31.7 
Decommissioning trust funds (a):
Equity securities4.1 — — 4.1 
Debt securities258.6 323.5 — 582.1 
Common trusts (b)1,020.1 
$294.4 $323.5 $— $1,638.0 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$28.5 $— $— $28.5 
Decommissioning trust funds (a):
Equity securities2.4 — — 2.4 
Debt securities262.4 297.4 — 559.8 
Common trusts (b)966.9 
$293.3 $297.4 $— $1,557.6 

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.
(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$3.0 $3.4 ($0.1)$0.4 $0.4 
Issuances of financial transmission rights11.8 28.7 1.5 3.0 4.0 
Gains included as a regulatory liability/asset5.8 38.2 3.1 8.4 1.8 
Settlements(9.5)(42.0)(3.1)(8.8)(2.3)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$2.8 $4.1 $0.6 $0.5 $1.2 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset7.7 19.1 1.2 2.6 2.7 
Settlements(12.0)(25.0)(2.1)(3.3)(4.6)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$8.6 $8.6 ($0.5)$1.3 $1.9 
Issuances of financial transmission rights11.8 28.7 1.5 2.9 4.0 
Gains included as a regulatory liability/asset18.9 55.1 5.5 9.9 3.8 
Settlements(28.2)(64.1)(5.1)(11.1)(5.8)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$6.0 $9.8 $1.4 $1.1 $2.4 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset31.4 29.6 1.4 3.1 9.0 
Settlements(38.9)(41.2)(3.1)(4.4)(12.1)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 
v3.25.2
Decommissioning Trust Funds
 6 Months Ended
Jun. 30, 2025
Decommissioning Trust Fund [Text Block] DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)
The NRC requires certain of the Utility operating companies and System Energy to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1 and 2, River Bend, Waterford 3, and Grand Gulf. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents.

Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets.  For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other long-term liabilities on the consolidated balance sheets of Entergy and Entergy Louisiana for the unrealized trust earnings not currently expected to be needed to decommission the plant. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2025 on equity securities still held as of June 30, 2025 were $536 million and $513 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds that are designed to approximate or somewhat exceed the return of the Wilshire 4500 Index. The debt securities are generally held in individual government and credit issuances.

The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$2,107 $2,047 
Unrealized gains$20 $7 
Unrealized losses$60 $80 

As of June 30, 2025 and December 31, 2024, there were no deferred taxes on unrealized gains/(losses). The amortized cost of available-for-sale debt securities was $2,148 million as of June 30, 2025 and $2,121 million as of December 31, 2024.  As of June 30, 2025, available-for-sale debt securities had an average coupon rate of
approximately 4.14%, an average duration of approximately 6.39 years, and an average maturity of approximately 10.81 years.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$565 $17 $1,102 $24 
More than 12 months438 43 510 56 
Total$1,003 $60 $1,612 $80 

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
20252024
(In Millions)
Less than 1 year$29 $36 
1 year - 5 years541 574 
5 years - 10 years672 629 
10 years - 15 years195 166 
15 years - 20 years197 218 
20 years+473 424 
Total$2,107 $2,047 

The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$227 $161 $489 $330 
Realized gains$1 $— $2 $1 
Realized losses$4 $14 $8 $20 

During the three and six months ended June 30, 2025 and 2024, gross gains and gross losses related to available-for-sale debt securities were reclassified out of other regulatory liabilities/assets into earnings.
Entergy Arkansas

Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$594.1 $579.0 
Unrealized gains$5.4 $1.2 
Unrealized losses$17.5 $25.8 

The amortized cost of available-for-sale debt securities was $606.1 million as of June 30, 2025 and $603.5 million as of December 31, 2024.  As of June 30, 2025, the available-for-sale debt securities had an average coupon rate of approximately 3.75%, an average duration of approximately 6.20 years, and an average maturity of approximately 8.46 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2025 on equity securities still held as of June 30, 2025 were $138 million and $126.7 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds that are designed to approximate or somewhat exceed the return of the Wilshire 4500 Index. The debt securities are generally held in individual government and credit issuances.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$141.8 $4.6 $282.8 $8.2 
More than 12 months174.0 12.9 195.0 17.6 
Total$315.8 $17.5 $477.8 $25.8 

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
 20252024
 (In Millions)
Less than 1 year$26.3 $31.7 
1 year - 5 years159.2 142.5 
5 years - 10 years251.7 231.0 
10 years - 15 years37.4 62.2 
15 years - 20 years43.1 62.8 
20 years+76.4 48.8 
Total$594.1 $579.0 
The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$— $5.5 $— $17.9 
Realized gains$— $0.1 $— $0.1 
Realized losses$— $0.4 $— $0.9 

During three and six months ended June 30, 2025 and 2024, gross gains and gross losses related to available-for-sale debt securities were reclassified out of other regulatory liabilities/assets into earnings.

Entergy Louisiana

Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$931.3 $908.1 
Unrealized gains$8.1 $3.6 
Unrealized losses$24.1 $26.9 

The amortized cost of available-for-sale debt securities was $947.3 million as of June 30, 2025 and $931.5 million as of December 31, 2024.  As of June 30, 2025, the available-for-sale debt securities had an average coupon rate of approximately 4.40%, an average duration of approximately 6.57 years, and an average maturity of approximately 12.38 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2025 on equity securities still held as of June 30, 2025 were $267.9 million and $254.6 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds that are designed to approximate or somewhat exceed the return of the Wilshire 4500 Index. The debt securities are generally held in individual government and credit issuances.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$318.7 $9.4 $543.8 $8.8 
More than 12 months150.6 14.7 178.4 18.1 
Total$469.3 $24.1 $722.2 $26.9 
The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
20252024
(In Millions)
Less than 1 year$2.4 $4.4 
1 year - 5 years212.3 188.2 
5 years - 10 years214.3 259.4 
10 years - 15 years115.0 80.9 
15 years - 20 years107.6 106.1 
20 years+279.7 269.1 
Total$931.3 $908.1 

The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$71.5 $62.5 $181.5 $110.9 
Realized gains$0.1 $0.1 $0.2 $0.2 
Realized losses$2.4 $4.8 $4.0 $7.7 

During the three and six months ended June 30, 2025 and 2024, gross gains and gross losses related to available-for-sale debt securities were reclassified out of other regulatory liabilities/assets into earnings.

System Energy

System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$582.1 $559.8 
Unrealized gains$6.1 $1.9 
Unrealized losses$19.0 $27.6 

The amortized cost of available-for-sale debt securities was $595 million as of June 30, 2025 and $585.5 million as of December 31, 2024.  As of June 30, 2025, the available-for-sale debt securities had an average coupon rate of approximately 4.13%, an average duration of approximately 6.27 years, and an average maturity of approximately 10.73 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2025 on equity securities still held as of June 30, 2025 were $130.5 million and $131.3 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds that are designed to approximate or somewhat exceed the return of the Wilshire 4500 Index. The debt securities are generally held in individual government and credit issuances.
The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$104.2 $3.3 $275.6 $6.8 
More than 12 months113.8 15.7 136.8 20.8 
Total$218.0 $19.0 $412.4 $27.6 

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
20252024
(In Millions)
Less than 1 year$0.2 $0.2 
1 year - 5 years169.2 243.7 
5 years - 10 years206.4 138.9 
10 years - 15 years42.5 22.7 
15 years - 20 years46.4 49.4 
20 years+117.4 104.9 
Total$582.1 $559.8 

The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$155.3 $93.5 $307.6 $201.5 
Realized gains$0.8 $— $1.3 $0.2 
Realized losses$1.4 $8.4 $4.0 $11.9 

During the three and six months ended June 30, 2025 and 2024, gross gains and gross losses related to available-for-sale debt securities were reclassified out of other regulatory liabilities/assets into earnings.
Entergy Arkansas [Member]  
Decommissioning Trust Fund [Text Block] DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)
The NRC requires certain of the Utility operating companies and System Energy to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1 and 2, River Bend, Waterford 3, and Grand Gulf. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents.

Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets.  For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other long-term liabilities on the consolidated balance sheets of Entergy and Entergy Louisiana for the unrealized trust earnings not currently expected to be needed to decommission the plant. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2025 on equity securities still held as of June 30, 2025 were $536 million and $513 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds that are designed to approximate or somewhat exceed the return of the Wilshire 4500 Index. The debt securities are generally held in individual government and credit issuances.

The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$2,107 $2,047 
Unrealized gains$20 $7 
Unrealized losses$60 $80 

As of June 30, 2025 and December 31, 2024, there were no deferred taxes on unrealized gains/(losses). The amortized cost of available-for-sale debt securities was $2,148 million as of June 30, 2025 and $2,121 million as of December 31, 2024.  As of June 30, 2025, available-for-sale debt securities had an average coupon rate of
approximately 4.14%, an average duration of approximately 6.39 years, and an average maturity of approximately 10.81 years.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$565 $17 $1,102 $24 
More than 12 months438 43 510 56 
Total$1,003 $60 $1,612 $80 

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
20252024
(In Millions)
Less than 1 year$29 $36 
1 year - 5 years541 574 
5 years - 10 years672 629 
10 years - 15 years195 166 
15 years - 20 years197 218 
20 years+473 424 
Total$2,107 $2,047 

The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$227 $161 $489 $330 
Realized gains$1 $— $2 $1 
Realized losses$4 $14 $8 $20 

During the three and six months ended June 30, 2025 and 2024, gross gains and gross losses related to available-for-sale debt securities were reclassified out of other regulatory liabilities/assets into earnings.
Entergy Arkansas

Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$594.1 $579.0 
Unrealized gains$5.4 $1.2 
Unrealized losses$17.5 $25.8 

The amortized cost of available-for-sale debt securities was $606.1 million as of June 30, 2025 and $603.5 million as of December 31, 2024.  As of June 30, 2025, the available-for-sale debt securities had an average coupon rate of approximately 3.75%, an average duration of approximately 6.20 years, and an average maturity of approximately 8.46 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2025 on equity securities still held as of June 30, 2025 were $138 million and $126.7 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds that are designed to approximate or somewhat exceed the return of the Wilshire 4500 Index. The debt securities are generally held in individual government and credit issuances.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$141.8 $4.6 $282.8 $8.2 
More than 12 months174.0 12.9 195.0 17.6 
Total$315.8 $17.5 $477.8 $25.8 

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
 20252024
 (In Millions)
Less than 1 year$26.3 $31.7 
1 year - 5 years159.2 142.5 
5 years - 10 years251.7 231.0 
10 years - 15 years37.4 62.2 
15 years - 20 years43.1 62.8 
20 years+76.4 48.8 
Total$594.1 $579.0 
The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$— $5.5 $— $17.9 
Realized gains$— $0.1 $— $0.1 
Realized losses$— $0.4 $— $0.9 

During three and six months ended June 30, 2025 and 2024, gross gains and gross losses related to available-for-sale debt securities were reclassified out of other regulatory liabilities/assets into earnings.

Entergy Louisiana

Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$931.3 $908.1 
Unrealized gains$8.1 $3.6 
Unrealized losses$24.1 $26.9 

The amortized cost of available-for-sale debt securities was $947.3 million as of June 30, 2025 and $931.5 million as of December 31, 2024.  As of June 30, 2025, the available-for-sale debt securities had an average coupon rate of approximately 4.40%, an average duration of approximately 6.57 years, and an average maturity of approximately 12.38 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2025 on equity securities still held as of June 30, 2025 were $267.9 million and $254.6 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds that are designed to approximate or somewhat exceed the return of the Wilshire 4500 Index. The debt securities are generally held in individual government and credit issuances.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$318.7 $9.4 $543.8 $8.8 
More than 12 months150.6 14.7 178.4 18.1 
Total$469.3 $24.1 $722.2 $26.9 
The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
20252024
(In Millions)
Less than 1 year$2.4 $4.4 
1 year - 5 years212.3 188.2 
5 years - 10 years214.3 259.4 
10 years - 15 years115.0 80.9 
15 years - 20 years107.6 106.1 
20 years+279.7 269.1 
Total$931.3 $908.1 

The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$71.5 $62.5 $181.5 $110.9 
Realized gains$0.1 $0.1 $0.2 $0.2 
Realized losses$2.4 $4.8 $4.0 $7.7 

During the three and six months ended June 30, 2025 and 2024, gross gains and gross losses related to available-for-sale debt securities were reclassified out of other regulatory liabilities/assets into earnings.

System Energy

System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$582.1 $559.8 
Unrealized gains$6.1 $1.9 
Unrealized losses$19.0 $27.6 

The amortized cost of available-for-sale debt securities was $595 million as of June 30, 2025 and $585.5 million as of December 31, 2024.  As of June 30, 2025, the available-for-sale debt securities had an average coupon rate of approximately 4.13%, an average duration of approximately 6.27 years, and an average maturity of approximately 10.73 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2025 on equity securities still held as of June 30, 2025 were $130.5 million and $131.3 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds that are designed to approximate or somewhat exceed the return of the Wilshire 4500 Index. The debt securities are generally held in individual government and credit issuances.
The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$104.2 $3.3 $275.6 $6.8 
More than 12 months113.8 15.7 136.8 20.8 
Total$218.0 $19.0 $412.4 $27.6 

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
20252024
(In Millions)
Less than 1 year$0.2 $0.2 
1 year - 5 years169.2 243.7 
5 years - 10 years206.4 138.9 
10 years - 15 years42.5 22.7 
15 years - 20 years46.4 49.4 
20 years+117.4 104.9 
Total$582.1 $559.8 

The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$155.3 $93.5 $307.6 $201.5 
Realized gains$0.8 $— $1.3 $0.2 
Realized losses$1.4 $8.4 $4.0 $11.9 

During the three and six months ended June 30, 2025 and 2024, gross gains and gross losses related to available-for-sale debt securities were reclassified out of other regulatory liabilities/assets into earnings.
Entergy Louisiana [Member]  
Decommissioning Trust Fund [Text Block] DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)
The NRC requires certain of the Utility operating companies and System Energy to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1 and 2, River Bend, Waterford 3, and Grand Gulf. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents.

Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets.  For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other long-term liabilities on the consolidated balance sheets of Entergy and Entergy Louisiana for the unrealized trust earnings not currently expected to be needed to decommission the plant. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2025 on equity securities still held as of June 30, 2025 were $536 million and $513 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds that are designed to approximate or somewhat exceed the return of the Wilshire 4500 Index. The debt securities are generally held in individual government and credit issuances.

The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$2,107 $2,047 
Unrealized gains$20 $7 
Unrealized losses$60 $80 

As of June 30, 2025 and December 31, 2024, there were no deferred taxes on unrealized gains/(losses). The amortized cost of available-for-sale debt securities was $2,148 million as of June 30, 2025 and $2,121 million as of December 31, 2024.  As of June 30, 2025, available-for-sale debt securities had an average coupon rate of
approximately 4.14%, an average duration of approximately 6.39 years, and an average maturity of approximately 10.81 years.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$565 $17 $1,102 $24 
More than 12 months438 43 510 56 
Total$1,003 $60 $1,612 $80 

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
20252024
(In Millions)
Less than 1 year$29 $36 
1 year - 5 years541 574 
5 years - 10 years672 629 
10 years - 15 years195 166 
15 years - 20 years197 218 
20 years+473 424 
Total$2,107 $2,047 

The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$227 $161 $489 $330 
Realized gains$1 $— $2 $1 
Realized losses$4 $14 $8 $20 

During the three and six months ended June 30, 2025 and 2024, gross gains and gross losses related to available-for-sale debt securities were reclassified out of other regulatory liabilities/assets into earnings.
Entergy Arkansas

Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$594.1 $579.0 
Unrealized gains$5.4 $1.2 
Unrealized losses$17.5 $25.8 

The amortized cost of available-for-sale debt securities was $606.1 million as of June 30, 2025 and $603.5 million as of December 31, 2024.  As of June 30, 2025, the available-for-sale debt securities had an average coupon rate of approximately 3.75%, an average duration of approximately 6.20 years, and an average maturity of approximately 8.46 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2025 on equity securities still held as of June 30, 2025 were $138 million and $126.7 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds that are designed to approximate or somewhat exceed the return of the Wilshire 4500 Index. The debt securities are generally held in individual government and credit issuances.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$141.8 $4.6 $282.8 $8.2 
More than 12 months174.0 12.9 195.0 17.6 
Total$315.8 $17.5 $477.8 $25.8 

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
 20252024
 (In Millions)
Less than 1 year$26.3 $31.7 
1 year - 5 years159.2 142.5 
5 years - 10 years251.7 231.0 
10 years - 15 years37.4 62.2 
15 years - 20 years43.1 62.8 
20 years+76.4 48.8 
Total$594.1 $579.0 
The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$— $5.5 $— $17.9 
Realized gains$— $0.1 $— $0.1 
Realized losses$— $0.4 $— $0.9 

During three and six months ended June 30, 2025 and 2024, gross gains and gross losses related to available-for-sale debt securities were reclassified out of other regulatory liabilities/assets into earnings.

Entergy Louisiana

Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$931.3 $908.1 
Unrealized gains$8.1 $3.6 
Unrealized losses$24.1 $26.9 

The amortized cost of available-for-sale debt securities was $947.3 million as of June 30, 2025 and $931.5 million as of December 31, 2024.  As of June 30, 2025, the available-for-sale debt securities had an average coupon rate of approximately 4.40%, an average duration of approximately 6.57 years, and an average maturity of approximately 12.38 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2025 on equity securities still held as of June 30, 2025 were $267.9 million and $254.6 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds that are designed to approximate or somewhat exceed the return of the Wilshire 4500 Index. The debt securities are generally held in individual government and credit issuances.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$318.7 $9.4 $543.8 $8.8 
More than 12 months150.6 14.7 178.4 18.1 
Total$469.3 $24.1 $722.2 $26.9 
The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
20252024
(In Millions)
Less than 1 year$2.4 $4.4 
1 year - 5 years212.3 188.2 
5 years - 10 years214.3 259.4 
10 years - 15 years115.0 80.9 
15 years - 20 years107.6 106.1 
20 years+279.7 269.1 
Total$931.3 $908.1 

The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$71.5 $62.5 $181.5 $110.9 
Realized gains$0.1 $0.1 $0.2 $0.2 
Realized losses$2.4 $4.8 $4.0 $7.7 

During the three and six months ended June 30, 2025 and 2024, gross gains and gross losses related to available-for-sale debt securities were reclassified out of other regulatory liabilities/assets into earnings.

System Energy

System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$582.1 $559.8 
Unrealized gains$6.1 $1.9 
Unrealized losses$19.0 $27.6 

The amortized cost of available-for-sale debt securities was $595 million as of June 30, 2025 and $585.5 million as of December 31, 2024.  As of June 30, 2025, the available-for-sale debt securities had an average coupon rate of approximately 4.13%, an average duration of approximately 6.27 years, and an average maturity of approximately 10.73 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2025 on equity securities still held as of June 30, 2025 were $130.5 million and $131.3 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds that are designed to approximate or somewhat exceed the return of the Wilshire 4500 Index. The debt securities are generally held in individual government and credit issuances.
The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$104.2 $3.3 $275.6 $6.8 
More than 12 months113.8 15.7 136.8 20.8 
Total$218.0 $19.0 $412.4 $27.6 

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
20252024
(In Millions)
Less than 1 year$0.2 $0.2 
1 year - 5 years169.2 243.7 
5 years - 10 years206.4 138.9 
10 years - 15 years42.5 22.7 
15 years - 20 years46.4 49.4 
20 years+117.4 104.9 
Total$582.1 $559.8 

The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$155.3 $93.5 $307.6 $201.5 
Realized gains$0.8 $— $1.3 $0.2 
Realized losses$1.4 $8.4 $4.0 $11.9 

During the three and six months ended June 30, 2025 and 2024, gross gains and gross losses related to available-for-sale debt securities were reclassified out of other regulatory liabilities/assets into earnings.
System Energy [Member]  
Decommissioning Trust Fund [Text Block] DECOMMISSIONING TRUST FUNDS (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, and System Energy)
The NRC requires certain of the Utility operating companies and System Energy to maintain nuclear decommissioning trusts to fund the costs of decommissioning ANO 1 and 2, River Bend, Waterford 3, and Grand Gulf. Entergy’s nuclear decommissioning trust funds invest in equity securities, fixed-rate debt securities, and cash and cash equivalents.

Entergy records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, for unrealized gains/(losses) on investment securities, the Registrant Subsidiaries record an offsetting amount in other regulatory liabilities/assets.  For the 30% interest in River Bend formerly owned by Cajun, Entergy Louisiana records an offsetting amount in other long-term liabilities on the consolidated balance sheets of Entergy and Entergy Louisiana for the unrealized trust earnings not currently expected to be needed to decommission the plant. Generally, Entergy records gains and losses on its debt and equity securities using the specific identification method to determine the cost basis of its securities.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2025 on equity securities still held as of June 30, 2025 were $536 million and $513 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index.  A relatively small percentage of the equity securities are held in funds that are designed to approximate or somewhat exceed the return of the Wilshire 4500 Index. The debt securities are generally held in individual government and credit issuances.

The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$2,107 $2,047 
Unrealized gains$20 $7 
Unrealized losses$60 $80 

As of June 30, 2025 and December 31, 2024, there were no deferred taxes on unrealized gains/(losses). The amortized cost of available-for-sale debt securities was $2,148 million as of June 30, 2025 and $2,121 million as of December 31, 2024.  As of June 30, 2025, available-for-sale debt securities had an average coupon rate of
approximately 4.14%, an average duration of approximately 6.39 years, and an average maturity of approximately 10.81 years.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$565 $17 $1,102 $24 
More than 12 months438 43 510 56 
Total$1,003 $60 $1,612 $80 

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
20252024
(In Millions)
Less than 1 year$29 $36 
1 year - 5 years541 574 
5 years - 10 years672 629 
10 years - 15 years195 166 
15 years - 20 years197 218 
20 years+473 424 
Total$2,107 $2,047 

The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$227 $161 $489 $330 
Realized gains$1 $— $2 $1 
Realized losses$4 $14 $8 $20 

During the three and six months ended June 30, 2025 and 2024, gross gains and gross losses related to available-for-sale debt securities were reclassified out of other regulatory liabilities/assets into earnings.
Entergy Arkansas

Entergy Arkansas holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$594.1 $579.0 
Unrealized gains$5.4 $1.2 
Unrealized losses$17.5 $25.8 

The amortized cost of available-for-sale debt securities was $606.1 million as of June 30, 2025 and $603.5 million as of December 31, 2024.  As of June 30, 2025, the available-for-sale debt securities had an average coupon rate of approximately 3.75%, an average duration of approximately 6.20 years, and an average maturity of approximately 8.46 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2025 on equity securities still held as of June 30, 2025 were $138 million and $126.7 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds that are designed to approximate or somewhat exceed the return of the Wilshire 4500 Index. The debt securities are generally held in individual government and credit issuances.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$141.8 $4.6 $282.8 $8.2 
More than 12 months174.0 12.9 195.0 17.6 
Total$315.8 $17.5 $477.8 $25.8 

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
 20252024
 (In Millions)
Less than 1 year$26.3 $31.7 
1 year - 5 years159.2 142.5 
5 years - 10 years251.7 231.0 
10 years - 15 years37.4 62.2 
15 years - 20 years43.1 62.8 
20 years+76.4 48.8 
Total$594.1 $579.0 
The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$— $5.5 $— $17.9 
Realized gains$— $0.1 $— $0.1 
Realized losses$— $0.4 $— $0.9 

During three and six months ended June 30, 2025 and 2024, gross gains and gross losses related to available-for-sale debt securities were reclassified out of other regulatory liabilities/assets into earnings.

Entergy Louisiana

Entergy Louisiana holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$931.3 $908.1 
Unrealized gains$8.1 $3.6 
Unrealized losses$24.1 $26.9 

The amortized cost of available-for-sale debt securities was $947.3 million as of June 30, 2025 and $931.5 million as of December 31, 2024.  As of June 30, 2025, the available-for-sale debt securities had an average coupon rate of approximately 4.40%, an average duration of approximately 6.57 years, and an average maturity of approximately 12.38 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2025 on equity securities still held as of June 30, 2025 were $267.9 million and $254.6 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds that are designed to approximate or somewhat exceed the return of the Wilshire 4500 Index. The debt securities are generally held in individual government and credit issuances.

The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$318.7 $9.4 $543.8 $8.8 
More than 12 months150.6 14.7 178.4 18.1 
Total$469.3 $24.1 $722.2 $26.9 
The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
20252024
(In Millions)
Less than 1 year$2.4 $4.4 
1 year - 5 years212.3 188.2 
5 years - 10 years214.3 259.4 
10 years - 15 years115.0 80.9 
15 years - 20 years107.6 106.1 
20 years+279.7 269.1 
Total$931.3 $908.1 

The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$71.5 $62.5 $181.5 $110.9 
Realized gains$0.1 $0.1 $0.2 $0.2 
Realized losses$2.4 $4.8 $4.0 $7.7 

During the three and six months ended June 30, 2025 and 2024, gross gains and gross losses related to available-for-sale debt securities were reclassified out of other regulatory liabilities/assets into earnings.

System Energy

System Energy holds equity securities and available-for-sale debt securities in nuclear decommissioning trust accounts.  The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$582.1 $559.8 
Unrealized gains$6.1 $1.9 
Unrealized losses$19.0 $27.6 

The amortized cost of available-for-sale debt securities was $595 million as of June 30, 2025 and $585.5 million as of December 31, 2024.  As of June 30, 2025, the available-for-sale debt securities had an average coupon rate of approximately 4.13%, an average duration of approximately 6.27 years, and an average maturity of approximately 10.73 years.

The unrealized gains/(losses) recognized during the three and six months ended June 30, 2025 on equity securities still held as of June 30, 2025 were $130.5 million and $131.3 million, respectively. The equity securities are generally held in funds that are designed to approximate or somewhat exceed the return of the Standard & Poor’s 500 Index. A relatively small percentage of the equity securities are held in funds that are designed to approximate or somewhat exceed the return of the Wilshire 4500 Index. The debt securities are generally held in individual government and credit issuances.
The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$104.2 $3.3 $275.6 $6.8 
More than 12 months113.8 15.7 136.8 20.8 
Total$218.0 $19.0 $412.4 $27.6 

The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
20252024
(In Millions)
Less than 1 year$0.2 $0.2 
1 year - 5 years169.2 243.7 
5 years - 10 years206.4 138.9 
10 years - 15 years42.5 22.7 
15 years - 20 years46.4 49.4 
20 years+117.4 104.9 
Total$582.1 $559.8 

The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$155.3 $93.5 $307.6 $201.5 
Realized gains$0.8 $— $1.3 $0.2 
Realized losses$1.4 $8.4 $4.0 $11.9 

During the three and six months ended June 30, 2025 and 2024, gross gains and gross losses related to available-for-sale debt securities were reclassified out of other regulatory liabilities/assets into earnings.
v3.25.2
Income Taxes
 6 Months Ended
Jun. 30, 2025
Income Tax Disclosure [Text Block] INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion.

Other Tax Matters

Inflation Reduction Act of 2022

As discussed in the Note 3 to the financial statements in the Form 10-K, the Inflation Reduction Act, signed into law on August 16, 2022, significantly expanded federal tax incentives for clean energy production, including the extension of production tax credits to solar projects and certain qualified nuclear power facilities. Entergy Arkansas, Entergy Louisiana, and System Energy have the potential to generate zero-emission nuclear power production tax credits for electricity generated by their respective nuclear power facilities. Due to the uncertainty of the value, if any, of credits Entergy Arkansas, Entergy Louisiana, or System Energy may receive, such credits for the nuclear power produced in 2024 were not recognized as of December 31, 2024.

In second quarter 2025, Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy determined, based on current analysis and evolving regulatory developments, that it was appropriate to record zero-emission nuclear power production tax credits for electricity generated in 2024 by their respective nuclear power facilities and the credits are expected to be claimed on the Entergy 2024 federal income tax return. Because the U.S. Treasury and the IRS have not issued final guidance on the application of Internal Revenue Code section 45U, including the definition of “gross receipts,” Entergy considers the tax position associated with these credits to be uncertain under the provisions of income tax accounting standards. As such, the recognition of the credits included a corresponding provision for uncertain tax positions for the full amount of the credits recognized.

The value of the credits was calculated based on the amount of electricity generated and sold by each nuclear generating unit owned by Entergy Arkansas, Entergy Louisiana, and System Energy during 2024, multiplied by the applicable credit rate (i.e. dollars per kW). The applicable credit rate included the incremental amount of credit for meeting the “prevailing wages” criteria under the Inflation Reduction Act. Entergy also applied the statutorily required reduction amount in arriving at the value of the credits. This reduction amount was driven by the “Gross receipts” received by each unit for its 2024 energy production. Entergy Arkansas, Entergy Louisiana, and System Energy recognized production tax credits of $221.4 million, $208.9 million, and $140.9 million, respectively, resulting in an Entergy consolidated production tax credit of $571.2 million. To the extent future guidance allows Entergy to realize the value of the credits under the provisions of income tax accounting standards, the monetized value of the credits are expected to be shared with customers.

Entergy Arkansas, Entergy Louisiana, and System Energy expect to transfer the credits to third parties for cash (including a reasonable discount) prior to the filing of the Entergy 2024 federal income tax return. As such, Entergy Arkansas, Entergy Louisiana, System Energy, and the relevant affiliates are preparing or have submitted filings with the FERC and their respective retail regulators to determine a fair and reasonable approach, including risk sharing and timing, to incorporate the net cash proceeds received for these credits into future customer rates, particularly in light of the related provision for uncertain tax position. Entergy will continue to monitor developments and reassess its tax position as additional guidance or other information emerges.

Sale of Natural Gas Distribution Businesses

See Note 13 to the financial statements herein for discussion of the sale of Entergy New Orleans’ and Entergy Louisiana’s natural gas distribution businesses on July 1, 2025. Entergy is expected to recognize a gain of approximately $335 million for tax purposes, with Entergy Louisiana and Entergy New Orleans recognizing
$150 million and $185 million, respectively. Both Entergy and Entergy Louisiana have sufficient federal tax net operating loss carryforwards to offset their respective gains. Accordingly, Entergy does not have a resulting federal income tax obligation as a result of the transaction, nor will Entergy Louisiana be required to make a federal tax payment under the terms of the intercompany income tax allocation agreement. Entergy New Orleans is expected to fully absorb its federal tax net operating loss carryforward in 2025, and its resulting federal tax payment under the intercompany income tax allocation agreement will be dependent on its results of operations for the remainder of the year. Estimated state tax payments for Entergy, Entergy Louisiana, and Entergy New Orleans are not anticipated to be significant.
Entergy Arkansas [Member]  
Income Tax Disclosure [Text Block] INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion.

Other Tax Matters

Inflation Reduction Act of 2022

As discussed in the Note 3 to the financial statements in the Form 10-K, the Inflation Reduction Act, signed into law on August 16, 2022, significantly expanded federal tax incentives for clean energy production, including the extension of production tax credits to solar projects and certain qualified nuclear power facilities. Entergy Arkansas, Entergy Louisiana, and System Energy have the potential to generate zero-emission nuclear power production tax credits for electricity generated by their respective nuclear power facilities. Due to the uncertainty of the value, if any, of credits Entergy Arkansas, Entergy Louisiana, or System Energy may receive, such credits for the nuclear power produced in 2024 were not recognized as of December 31, 2024.

In second quarter 2025, Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy determined, based on current analysis and evolving regulatory developments, that it was appropriate to record zero-emission nuclear power production tax credits for electricity generated in 2024 by their respective nuclear power facilities and the credits are expected to be claimed on the Entergy 2024 federal income tax return. Because the U.S. Treasury and the IRS have not issued final guidance on the application of Internal Revenue Code section 45U, including the definition of “gross receipts,” Entergy considers the tax position associated with these credits to be uncertain under the provisions of income tax accounting standards. As such, the recognition of the credits included a corresponding provision for uncertain tax positions for the full amount of the credits recognized.

The value of the credits was calculated based on the amount of electricity generated and sold by each nuclear generating unit owned by Entergy Arkansas, Entergy Louisiana, and System Energy during 2024, multiplied by the applicable credit rate (i.e. dollars per kW). The applicable credit rate included the incremental amount of credit for meeting the “prevailing wages” criteria under the Inflation Reduction Act. Entergy also applied the statutorily required reduction amount in arriving at the value of the credits. This reduction amount was driven by the “Gross receipts” received by each unit for its 2024 energy production. Entergy Arkansas, Entergy Louisiana, and System Energy recognized production tax credits of $221.4 million, $208.9 million, and $140.9 million, respectively, resulting in an Entergy consolidated production tax credit of $571.2 million. To the extent future guidance allows Entergy to realize the value of the credits under the provisions of income tax accounting standards, the monetized value of the credits are expected to be shared with customers.

Entergy Arkansas, Entergy Louisiana, and System Energy expect to transfer the credits to third parties for cash (including a reasonable discount) prior to the filing of the Entergy 2024 federal income tax return. As such, Entergy Arkansas, Entergy Louisiana, System Energy, and the relevant affiliates are preparing or have submitted filings with the FERC and their respective retail regulators to determine a fair and reasonable approach, including risk sharing and timing, to incorporate the net cash proceeds received for these credits into future customer rates, particularly in light of the related provision for uncertain tax position. Entergy will continue to monitor developments and reassess its tax position as additional guidance or other information emerges.

Sale of Natural Gas Distribution Businesses

See Note 13 to the financial statements herein for discussion of the sale of Entergy New Orleans’ and Entergy Louisiana’s natural gas distribution businesses on July 1, 2025. Entergy is expected to recognize a gain of approximately $335 million for tax purposes, with Entergy Louisiana and Entergy New Orleans recognizing
$150 million and $185 million, respectively. Both Entergy and Entergy Louisiana have sufficient federal tax net operating loss carryforwards to offset their respective gains. Accordingly, Entergy does not have a resulting federal income tax obligation as a result of the transaction, nor will Entergy Louisiana be required to make a federal tax payment under the terms of the intercompany income tax allocation agreement. Entergy New Orleans is expected to fully absorb its federal tax net operating loss carryforward in 2025, and its resulting federal tax payment under the intercompany income tax allocation agreement will be dependent on its results of operations for the remainder of the year. Estimated state tax payments for Entergy, Entergy Louisiana, and Entergy New Orleans are not anticipated to be significant.
Entergy Louisiana [Member]  
Income Tax Disclosure [Text Block] INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion.

Other Tax Matters

Inflation Reduction Act of 2022

As discussed in the Note 3 to the financial statements in the Form 10-K, the Inflation Reduction Act, signed into law on August 16, 2022, significantly expanded federal tax incentives for clean energy production, including the extension of production tax credits to solar projects and certain qualified nuclear power facilities. Entergy Arkansas, Entergy Louisiana, and System Energy have the potential to generate zero-emission nuclear power production tax credits for electricity generated by their respective nuclear power facilities. Due to the uncertainty of the value, if any, of credits Entergy Arkansas, Entergy Louisiana, or System Energy may receive, such credits for the nuclear power produced in 2024 were not recognized as of December 31, 2024.

In second quarter 2025, Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy determined, based on current analysis and evolving regulatory developments, that it was appropriate to record zero-emission nuclear power production tax credits for electricity generated in 2024 by their respective nuclear power facilities and the credits are expected to be claimed on the Entergy 2024 federal income tax return. Because the U.S. Treasury and the IRS have not issued final guidance on the application of Internal Revenue Code section 45U, including the definition of “gross receipts,” Entergy considers the tax position associated with these credits to be uncertain under the provisions of income tax accounting standards. As such, the recognition of the credits included a corresponding provision for uncertain tax positions for the full amount of the credits recognized.

The value of the credits was calculated based on the amount of electricity generated and sold by each nuclear generating unit owned by Entergy Arkansas, Entergy Louisiana, and System Energy during 2024, multiplied by the applicable credit rate (i.e. dollars per kW). The applicable credit rate included the incremental amount of credit for meeting the “prevailing wages” criteria under the Inflation Reduction Act. Entergy also applied the statutorily required reduction amount in arriving at the value of the credits. This reduction amount was driven by the “Gross receipts” received by each unit for its 2024 energy production. Entergy Arkansas, Entergy Louisiana, and System Energy recognized production tax credits of $221.4 million, $208.9 million, and $140.9 million, respectively, resulting in an Entergy consolidated production tax credit of $571.2 million. To the extent future guidance allows Entergy to realize the value of the credits under the provisions of income tax accounting standards, the monetized value of the credits are expected to be shared with customers.

Entergy Arkansas, Entergy Louisiana, and System Energy expect to transfer the credits to third parties for cash (including a reasonable discount) prior to the filing of the Entergy 2024 federal income tax return. As such, Entergy Arkansas, Entergy Louisiana, System Energy, and the relevant affiliates are preparing or have submitted filings with the FERC and their respective retail regulators to determine a fair and reasonable approach, including risk sharing and timing, to incorporate the net cash proceeds received for these credits into future customer rates, particularly in light of the related provision for uncertain tax position. Entergy will continue to monitor developments and reassess its tax position as additional guidance or other information emerges.

Sale of Natural Gas Distribution Businesses

See Note 13 to the financial statements herein for discussion of the sale of Entergy New Orleans’ and Entergy Louisiana’s natural gas distribution businesses on July 1, 2025. Entergy is expected to recognize a gain of approximately $335 million for tax purposes, with Entergy Louisiana and Entergy New Orleans recognizing
$150 million and $185 million, respectively. Both Entergy and Entergy Louisiana have sufficient federal tax net operating loss carryforwards to offset their respective gains. Accordingly, Entergy does not have a resulting federal income tax obligation as a result of the transaction, nor will Entergy Louisiana be required to make a federal tax payment under the terms of the intercompany income tax allocation agreement. Entergy New Orleans is expected to fully absorb its federal tax net operating loss carryforward in 2025, and its resulting federal tax payment under the intercompany income tax allocation agreement will be dependent on its results of operations for the remainder of the year. Estimated state tax payments for Entergy, Entergy Louisiana, and Entergy New Orleans are not anticipated to be significant.
Entergy Mississippi [Member]  
Income Tax Disclosure [Text Block] INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion.

Other Tax Matters

Inflation Reduction Act of 2022

As discussed in the Note 3 to the financial statements in the Form 10-K, the Inflation Reduction Act, signed into law on August 16, 2022, significantly expanded federal tax incentives for clean energy production, including the extension of production tax credits to solar projects and certain qualified nuclear power facilities. Entergy Arkansas, Entergy Louisiana, and System Energy have the potential to generate zero-emission nuclear power production tax credits for electricity generated by their respective nuclear power facilities. Due to the uncertainty of the value, if any, of credits Entergy Arkansas, Entergy Louisiana, or System Energy may receive, such credits for the nuclear power produced in 2024 were not recognized as of December 31, 2024.

In second quarter 2025, Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy determined, based on current analysis and evolving regulatory developments, that it was appropriate to record zero-emission nuclear power production tax credits for electricity generated in 2024 by their respective nuclear power facilities and the credits are expected to be claimed on the Entergy 2024 federal income tax return. Because the U.S. Treasury and the IRS have not issued final guidance on the application of Internal Revenue Code section 45U, including the definition of “gross receipts,” Entergy considers the tax position associated with these credits to be uncertain under the provisions of income tax accounting standards. As such, the recognition of the credits included a corresponding provision for uncertain tax positions for the full amount of the credits recognized.

The value of the credits was calculated based on the amount of electricity generated and sold by each nuclear generating unit owned by Entergy Arkansas, Entergy Louisiana, and System Energy during 2024, multiplied by the applicable credit rate (i.e. dollars per kW). The applicable credit rate included the incremental amount of credit for meeting the “prevailing wages” criteria under the Inflation Reduction Act. Entergy also applied the statutorily required reduction amount in arriving at the value of the credits. This reduction amount was driven by the “Gross receipts” received by each unit for its 2024 energy production. Entergy Arkansas, Entergy Louisiana, and System Energy recognized production tax credits of $221.4 million, $208.9 million, and $140.9 million, respectively, resulting in an Entergy consolidated production tax credit of $571.2 million. To the extent future guidance allows Entergy to realize the value of the credits under the provisions of income tax accounting standards, the monetized value of the credits are expected to be shared with customers.

Entergy Arkansas, Entergy Louisiana, and System Energy expect to transfer the credits to third parties for cash (including a reasonable discount) prior to the filing of the Entergy 2024 federal income tax return. As such, Entergy Arkansas, Entergy Louisiana, System Energy, and the relevant affiliates are preparing or have submitted filings with the FERC and their respective retail regulators to determine a fair and reasonable approach, including risk sharing and timing, to incorporate the net cash proceeds received for these credits into future customer rates, particularly in light of the related provision for uncertain tax position. Entergy will continue to monitor developments and reassess its tax position as additional guidance or other information emerges.

Sale of Natural Gas Distribution Businesses

See Note 13 to the financial statements herein for discussion of the sale of Entergy New Orleans’ and Entergy Louisiana’s natural gas distribution businesses on July 1, 2025. Entergy is expected to recognize a gain of approximately $335 million for tax purposes, with Entergy Louisiana and Entergy New Orleans recognizing
$150 million and $185 million, respectively. Both Entergy and Entergy Louisiana have sufficient federal tax net operating loss carryforwards to offset their respective gains. Accordingly, Entergy does not have a resulting federal income tax obligation as a result of the transaction, nor will Entergy Louisiana be required to make a federal tax payment under the terms of the intercompany income tax allocation agreement. Entergy New Orleans is expected to fully absorb its federal tax net operating loss carryforward in 2025, and its resulting federal tax payment under the intercompany income tax allocation agreement will be dependent on its results of operations for the remainder of the year. Estimated state tax payments for Entergy, Entergy Louisiana, and Entergy New Orleans are not anticipated to be significant.
Entergy New Orleans [Member]  
Income Tax Disclosure [Text Block] INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion.

Other Tax Matters

Inflation Reduction Act of 2022

As discussed in the Note 3 to the financial statements in the Form 10-K, the Inflation Reduction Act, signed into law on August 16, 2022, significantly expanded federal tax incentives for clean energy production, including the extension of production tax credits to solar projects and certain qualified nuclear power facilities. Entergy Arkansas, Entergy Louisiana, and System Energy have the potential to generate zero-emission nuclear power production tax credits for electricity generated by their respective nuclear power facilities. Due to the uncertainty of the value, if any, of credits Entergy Arkansas, Entergy Louisiana, or System Energy may receive, such credits for the nuclear power produced in 2024 were not recognized as of December 31, 2024.

In second quarter 2025, Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy determined, based on current analysis and evolving regulatory developments, that it was appropriate to record zero-emission nuclear power production tax credits for electricity generated in 2024 by their respective nuclear power facilities and the credits are expected to be claimed on the Entergy 2024 federal income tax return. Because the U.S. Treasury and the IRS have not issued final guidance on the application of Internal Revenue Code section 45U, including the definition of “gross receipts,” Entergy considers the tax position associated with these credits to be uncertain under the provisions of income tax accounting standards. As such, the recognition of the credits included a corresponding provision for uncertain tax positions for the full amount of the credits recognized.

The value of the credits was calculated based on the amount of electricity generated and sold by each nuclear generating unit owned by Entergy Arkansas, Entergy Louisiana, and System Energy during 2024, multiplied by the applicable credit rate (i.e. dollars per kW). The applicable credit rate included the incremental amount of credit for meeting the “prevailing wages” criteria under the Inflation Reduction Act. Entergy also applied the statutorily required reduction amount in arriving at the value of the credits. This reduction amount was driven by the “Gross receipts” received by each unit for its 2024 energy production. Entergy Arkansas, Entergy Louisiana, and System Energy recognized production tax credits of $221.4 million, $208.9 million, and $140.9 million, respectively, resulting in an Entergy consolidated production tax credit of $571.2 million. To the extent future guidance allows Entergy to realize the value of the credits under the provisions of income tax accounting standards, the monetized value of the credits are expected to be shared with customers.

Entergy Arkansas, Entergy Louisiana, and System Energy expect to transfer the credits to third parties for cash (including a reasonable discount) prior to the filing of the Entergy 2024 federal income tax return. As such, Entergy Arkansas, Entergy Louisiana, System Energy, and the relevant affiliates are preparing or have submitted filings with the FERC and their respective retail regulators to determine a fair and reasonable approach, including risk sharing and timing, to incorporate the net cash proceeds received for these credits into future customer rates, particularly in light of the related provision for uncertain tax position. Entergy will continue to monitor developments and reassess its tax position as additional guidance or other information emerges.

Sale of Natural Gas Distribution Businesses

See Note 13 to the financial statements herein for discussion of the sale of Entergy New Orleans’ and Entergy Louisiana’s natural gas distribution businesses on July 1, 2025. Entergy is expected to recognize a gain of approximately $335 million for tax purposes, with Entergy Louisiana and Entergy New Orleans recognizing
$150 million and $185 million, respectively. Both Entergy and Entergy Louisiana have sufficient federal tax net operating loss carryforwards to offset their respective gains. Accordingly, Entergy does not have a resulting federal income tax obligation as a result of the transaction, nor will Entergy Louisiana be required to make a federal tax payment under the terms of the intercompany income tax allocation agreement. Entergy New Orleans is expected to fully absorb its federal tax net operating loss carryforward in 2025, and its resulting federal tax payment under the intercompany income tax allocation agreement will be dependent on its results of operations for the remainder of the year. Estimated state tax payments for Entergy, Entergy Louisiana, and Entergy New Orleans are not anticipated to be significant.
Entergy Texas [Member]  
Income Tax Disclosure [Text Block] INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion.

Other Tax Matters

Inflation Reduction Act of 2022

As discussed in the Note 3 to the financial statements in the Form 10-K, the Inflation Reduction Act, signed into law on August 16, 2022, significantly expanded federal tax incentives for clean energy production, including the extension of production tax credits to solar projects and certain qualified nuclear power facilities. Entergy Arkansas, Entergy Louisiana, and System Energy have the potential to generate zero-emission nuclear power production tax credits for electricity generated by their respective nuclear power facilities. Due to the uncertainty of the value, if any, of credits Entergy Arkansas, Entergy Louisiana, or System Energy may receive, such credits for the nuclear power produced in 2024 were not recognized as of December 31, 2024.

In second quarter 2025, Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy determined, based on current analysis and evolving regulatory developments, that it was appropriate to record zero-emission nuclear power production tax credits for electricity generated in 2024 by their respective nuclear power facilities and the credits are expected to be claimed on the Entergy 2024 federal income tax return. Because the U.S. Treasury and the IRS have not issued final guidance on the application of Internal Revenue Code section 45U, including the definition of “gross receipts,” Entergy considers the tax position associated with these credits to be uncertain under the provisions of income tax accounting standards. As such, the recognition of the credits included a corresponding provision for uncertain tax positions for the full amount of the credits recognized.

The value of the credits was calculated based on the amount of electricity generated and sold by each nuclear generating unit owned by Entergy Arkansas, Entergy Louisiana, and System Energy during 2024, multiplied by the applicable credit rate (i.e. dollars per kW). The applicable credit rate included the incremental amount of credit for meeting the “prevailing wages” criteria under the Inflation Reduction Act. Entergy also applied the statutorily required reduction amount in arriving at the value of the credits. This reduction amount was driven by the “Gross receipts” received by each unit for its 2024 energy production. Entergy Arkansas, Entergy Louisiana, and System Energy recognized production tax credits of $221.4 million, $208.9 million, and $140.9 million, respectively, resulting in an Entergy consolidated production tax credit of $571.2 million. To the extent future guidance allows Entergy to realize the value of the credits under the provisions of income tax accounting standards, the monetized value of the credits are expected to be shared with customers.

Entergy Arkansas, Entergy Louisiana, and System Energy expect to transfer the credits to third parties for cash (including a reasonable discount) prior to the filing of the Entergy 2024 federal income tax return. As such, Entergy Arkansas, Entergy Louisiana, System Energy, and the relevant affiliates are preparing or have submitted filings with the FERC and their respective retail regulators to determine a fair and reasonable approach, including risk sharing and timing, to incorporate the net cash proceeds received for these credits into future customer rates, particularly in light of the related provision for uncertain tax position. Entergy will continue to monitor developments and reassess its tax position as additional guidance or other information emerges.

Sale of Natural Gas Distribution Businesses

See Note 13 to the financial statements herein for discussion of the sale of Entergy New Orleans’ and Entergy Louisiana’s natural gas distribution businesses on July 1, 2025. Entergy is expected to recognize a gain of approximately $335 million for tax purposes, with Entergy Louisiana and Entergy New Orleans recognizing
$150 million and $185 million, respectively. Both Entergy and Entergy Louisiana have sufficient federal tax net operating loss carryforwards to offset their respective gains. Accordingly, Entergy does not have a resulting federal income tax obligation as a result of the transaction, nor will Entergy Louisiana be required to make a federal tax payment under the terms of the intercompany income tax allocation agreement. Entergy New Orleans is expected to fully absorb its federal tax net operating loss carryforward in 2025, and its resulting federal tax payment under the intercompany income tax allocation agreement will be dependent on its results of operations for the remainder of the year. Estimated state tax payments for Entergy, Entergy Louisiana, and Entergy New Orleans are not anticipated to be significant.
System Energy [Member]  
Income Tax Disclosure [Text Block] INCOME TAXES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
See “Income Tax Audits” and “Other Tax Matters” in Note 3 to the financial statements in the Form 10-K for a discussion of income tax audits, the Tax Cuts and Jobs Act, and other income tax matters involving Entergy. The following are updates to that discussion.

Other Tax Matters

Inflation Reduction Act of 2022

As discussed in the Note 3 to the financial statements in the Form 10-K, the Inflation Reduction Act, signed into law on August 16, 2022, significantly expanded federal tax incentives for clean energy production, including the extension of production tax credits to solar projects and certain qualified nuclear power facilities. Entergy Arkansas, Entergy Louisiana, and System Energy have the potential to generate zero-emission nuclear power production tax credits for electricity generated by their respective nuclear power facilities. Due to the uncertainty of the value, if any, of credits Entergy Arkansas, Entergy Louisiana, or System Energy may receive, such credits for the nuclear power produced in 2024 were not recognized as of December 31, 2024.

In second quarter 2025, Entergy, Entergy Arkansas, Entergy Louisiana, and System Energy determined, based on current analysis and evolving regulatory developments, that it was appropriate to record zero-emission nuclear power production tax credits for electricity generated in 2024 by their respective nuclear power facilities and the credits are expected to be claimed on the Entergy 2024 federal income tax return. Because the U.S. Treasury and the IRS have not issued final guidance on the application of Internal Revenue Code section 45U, including the definition of “gross receipts,” Entergy considers the tax position associated with these credits to be uncertain under the provisions of income tax accounting standards. As such, the recognition of the credits included a corresponding provision for uncertain tax positions for the full amount of the credits recognized.

The value of the credits was calculated based on the amount of electricity generated and sold by each nuclear generating unit owned by Entergy Arkansas, Entergy Louisiana, and System Energy during 2024, multiplied by the applicable credit rate (i.e. dollars per kW). The applicable credit rate included the incremental amount of credit for meeting the “prevailing wages” criteria under the Inflation Reduction Act. Entergy also applied the statutorily required reduction amount in arriving at the value of the credits. This reduction amount was driven by the “Gross receipts” received by each unit for its 2024 energy production. Entergy Arkansas, Entergy Louisiana, and System Energy recognized production tax credits of $221.4 million, $208.9 million, and $140.9 million, respectively, resulting in an Entergy consolidated production tax credit of $571.2 million. To the extent future guidance allows Entergy to realize the value of the credits under the provisions of income tax accounting standards, the monetized value of the credits are expected to be shared with customers.

Entergy Arkansas, Entergy Louisiana, and System Energy expect to transfer the credits to third parties for cash (including a reasonable discount) prior to the filing of the Entergy 2024 federal income tax return. As such, Entergy Arkansas, Entergy Louisiana, System Energy, and the relevant affiliates are preparing or have submitted filings with the FERC and their respective retail regulators to determine a fair and reasonable approach, including risk sharing and timing, to incorporate the net cash proceeds received for these credits into future customer rates, particularly in light of the related provision for uncertain tax position. Entergy will continue to monitor developments and reassess its tax position as additional guidance or other information emerges.

Sale of Natural Gas Distribution Businesses

See Note 13 to the financial statements herein for discussion of the sale of Entergy New Orleans’ and Entergy Louisiana’s natural gas distribution businesses on July 1, 2025. Entergy is expected to recognize a gain of approximately $335 million for tax purposes, with Entergy Louisiana and Entergy New Orleans recognizing
$150 million and $185 million, respectively. Both Entergy and Entergy Louisiana have sufficient federal tax net operating loss carryforwards to offset their respective gains. Accordingly, Entergy does not have a resulting federal income tax obligation as a result of the transaction, nor will Entergy Louisiana be required to make a federal tax payment under the terms of the intercompany income tax allocation agreement. Entergy New Orleans is expected to fully absorb its federal tax net operating loss carryforward in 2025, and its resulting federal tax payment under the intercompany income tax allocation agreement will be dependent on its results of operations for the remainder of the year. Estimated state tax payments for Entergy, Entergy Louisiana, and Entergy New Orleans are not anticipated to be significant.
v3.25.2
Variable Interest Entities
 6 Months Ended
Jun. 30, 2025
Variable Interest Entity Disclosure [Text Block] VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities (VIEs).  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. See Note 6 to the financial statements in the Form 10-K for discussion of noncontrolling interests.

Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2025 and December 31, 2024, the primary asset held by the storm trust I was $2.8 billion and $2.9 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust I is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $28.9 million as of June 30, 2025 and $28.8 million as of December 31, 2024.

Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2025 and December 31, 2024, the primary asset held by the storm trust II was $1.3 billion and $1.4 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust II is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $14.1 million as of June 30, 2025 and $13.9 million as of December 31, 2024.

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the six months ended June 30, 2025 and the six months ended June 30, 2024.

AR Searcy Partnership, LLC is a tax equity partnership that qualifies as a VIE, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. As of June 30, 2025, AR Searcy Partnership, LLC recorded assets equal to $127.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $114 million. As of December 31, 2024, AR Searcy Partnership, LLC recorded assets equal to $129.7 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $113.2 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Arkansas.

MS Sunflower Partnership, LLC is a tax equity partnership that qualifies as a VIE, which Entergy Mississippi is required to consolidate as it is the primary beneficiary. As of June 30, 2025, MS Sunflower Partnership, LLC recorded assets equal to $155.4 million, primarily consisting of property, plant, and equipment,
and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $136.9 million. As of December 31, 2024, MS Sunflower Partnership, LLC recorded assets equal to $157.8 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $132.7 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Mississippi.
Entergy Arkansas [Member]  
Variable Interest Entity Disclosure [Text Block] VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities (VIEs).  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. See Note 6 to the financial statements in the Form 10-K for discussion of noncontrolling interests.

Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2025 and December 31, 2024, the primary asset held by the storm trust I was $2.8 billion and $2.9 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust I is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $28.9 million as of June 30, 2025 and $28.8 million as of December 31, 2024.

Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2025 and December 31, 2024, the primary asset held by the storm trust II was $1.3 billion and $1.4 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust II is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $14.1 million as of June 30, 2025 and $13.9 million as of December 31, 2024.

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the six months ended June 30, 2025 and the six months ended June 30, 2024.

AR Searcy Partnership, LLC is a tax equity partnership that qualifies as a VIE, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. As of June 30, 2025, AR Searcy Partnership, LLC recorded assets equal to $127.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $114 million. As of December 31, 2024, AR Searcy Partnership, LLC recorded assets equal to $129.7 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $113.2 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Arkansas.

MS Sunflower Partnership, LLC is a tax equity partnership that qualifies as a VIE, which Entergy Mississippi is required to consolidate as it is the primary beneficiary. As of June 30, 2025, MS Sunflower Partnership, LLC recorded assets equal to $155.4 million, primarily consisting of property, plant, and equipment,
and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $136.9 million. As of December 31, 2024, MS Sunflower Partnership, LLC recorded assets equal to $157.8 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $132.7 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Mississippi.
Entergy Louisiana [Member]  
Variable Interest Entity Disclosure [Text Block] VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities (VIEs).  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. See Note 6 to the financial statements in the Form 10-K for discussion of noncontrolling interests.

Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2025 and December 31, 2024, the primary asset held by the storm trust I was $2.8 billion and $2.9 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust I is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $28.9 million as of June 30, 2025 and $28.8 million as of December 31, 2024.

Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2025 and December 31, 2024, the primary asset held by the storm trust II was $1.3 billion and $1.4 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust II is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $14.1 million as of June 30, 2025 and $13.9 million as of December 31, 2024.

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the six months ended June 30, 2025 and the six months ended June 30, 2024.

AR Searcy Partnership, LLC is a tax equity partnership that qualifies as a VIE, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. As of June 30, 2025, AR Searcy Partnership, LLC recorded assets equal to $127.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $114 million. As of December 31, 2024, AR Searcy Partnership, LLC recorded assets equal to $129.7 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $113.2 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Arkansas.

MS Sunflower Partnership, LLC is a tax equity partnership that qualifies as a VIE, which Entergy Mississippi is required to consolidate as it is the primary beneficiary. As of June 30, 2025, MS Sunflower Partnership, LLC recorded assets equal to $155.4 million, primarily consisting of property, plant, and equipment,
and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $136.9 million. As of December 31, 2024, MS Sunflower Partnership, LLC recorded assets equal to $157.8 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $132.7 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Mississippi.
Entergy Mississippi [Member]  
Variable Interest Entity Disclosure [Text Block] VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities (VIEs).  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. See Note 6 to the financial statements in the Form 10-K for discussion of noncontrolling interests.

Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2025 and December 31, 2024, the primary asset held by the storm trust I was $2.8 billion and $2.9 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust I is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $28.9 million as of June 30, 2025 and $28.8 million as of December 31, 2024.

Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2025 and December 31, 2024, the primary asset held by the storm trust II was $1.3 billion and $1.4 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust II is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $14.1 million as of June 30, 2025 and $13.9 million as of December 31, 2024.

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the six months ended June 30, 2025 and the six months ended June 30, 2024.

AR Searcy Partnership, LLC is a tax equity partnership that qualifies as a VIE, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. As of June 30, 2025, AR Searcy Partnership, LLC recorded assets equal to $127.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $114 million. As of December 31, 2024, AR Searcy Partnership, LLC recorded assets equal to $129.7 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $113.2 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Arkansas.

MS Sunflower Partnership, LLC is a tax equity partnership that qualifies as a VIE, which Entergy Mississippi is required to consolidate as it is the primary beneficiary. As of June 30, 2025, MS Sunflower Partnership, LLC recorded assets equal to $155.4 million, primarily consisting of property, plant, and equipment,
and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $136.9 million. As of December 31, 2024, MS Sunflower Partnership, LLC recorded assets equal to $157.8 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $132.7 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Mississippi.
Entergy New Orleans [Member]  
Variable Interest Entity Disclosure [Text Block] VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities (VIEs).  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. See Note 6 to the financial statements in the Form 10-K for discussion of noncontrolling interests.

Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2025 and December 31, 2024, the primary asset held by the storm trust I was $2.8 billion and $2.9 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust I is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $28.9 million as of June 30, 2025 and $28.8 million as of December 31, 2024.

Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2025 and December 31, 2024, the primary asset held by the storm trust II was $1.3 billion and $1.4 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust II is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $14.1 million as of June 30, 2025 and $13.9 million as of December 31, 2024.

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the six months ended June 30, 2025 and the six months ended June 30, 2024.

AR Searcy Partnership, LLC is a tax equity partnership that qualifies as a VIE, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. As of June 30, 2025, AR Searcy Partnership, LLC recorded assets equal to $127.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $114 million. As of December 31, 2024, AR Searcy Partnership, LLC recorded assets equal to $129.7 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $113.2 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Arkansas.

MS Sunflower Partnership, LLC is a tax equity partnership that qualifies as a VIE, which Entergy Mississippi is required to consolidate as it is the primary beneficiary. As of June 30, 2025, MS Sunflower Partnership, LLC recorded assets equal to $155.4 million, primarily consisting of property, plant, and equipment,
and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $136.9 million. As of December 31, 2024, MS Sunflower Partnership, LLC recorded assets equal to $157.8 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $132.7 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Mississippi.
Entergy Texas [Member]  
Variable Interest Entity Disclosure [Text Block] VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities (VIEs).  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. See Note 6 to the financial statements in the Form 10-K for discussion of noncontrolling interests.

Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2025 and December 31, 2024, the primary asset held by the storm trust I was $2.8 billion and $2.9 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust I is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $28.9 million as of June 30, 2025 and $28.8 million as of December 31, 2024.

Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2025 and December 31, 2024, the primary asset held by the storm trust II was $1.3 billion and $1.4 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust II is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $14.1 million as of June 30, 2025 and $13.9 million as of December 31, 2024.

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the six months ended June 30, 2025 and the six months ended June 30, 2024.

AR Searcy Partnership, LLC is a tax equity partnership that qualifies as a VIE, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. As of June 30, 2025, AR Searcy Partnership, LLC recorded assets equal to $127.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $114 million. As of December 31, 2024, AR Searcy Partnership, LLC recorded assets equal to $129.7 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $113.2 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Arkansas.

MS Sunflower Partnership, LLC is a tax equity partnership that qualifies as a VIE, which Entergy Mississippi is required to consolidate as it is the primary beneficiary. As of June 30, 2025, MS Sunflower Partnership, LLC recorded assets equal to $155.4 million, primarily consisting of property, plant, and equipment,
and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $136.9 million. As of December 31, 2024, MS Sunflower Partnership, LLC recorded assets equal to $157.8 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $132.7 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Mississippi.
System Energy [Member]  
Variable Interest Entity Disclosure [Text Block] VARIABLE INTEREST ENTITIES (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
See Note 17 to the financial statements in the Form 10-K for a discussion of variable interest entities (VIEs).  See Note 4 to the financial statements herein for details of the nuclear fuel companies’ credit facilities, commercial paper borrowings, and long-term debt. See Note 6 to the financial statements in the Form 10-K for discussion of noncontrolling interests.

Restoration Law Trust I (the storm trust I), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2025 and December 31, 2024, the primary asset held by the storm trust I was $2.8 billion and $2.9 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust I is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $28.9 million as of June 30, 2025 and $28.8 million as of December 31, 2024.

Restoration Law Trust II (the storm trust II), a trust consolidated by Entergy Louisiana, is a VIE and Entergy Louisiana is the primary beneficiary. As of June 30, 2025 and December 31, 2024, the primary asset held by the storm trust II was $1.3 billion and $1.4 billion, respectively, of outstanding Entergy Finance Company preferred membership interests, which is reflected as an investment in affiliate preferred membership interests on the consolidated balance sheets of Entergy Louisiana. The LURC’s 1% beneficial interest in the storm trust II is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Louisiana, with balances of $14.1 million as of June 30, 2025 and $13.9 million as of December 31, 2024.

System Energy is considered to hold a variable interest in the lessor from which it leases an undivided interest in the Grand Gulf nuclear plant. System Energy is the lessee under this arrangement, which is described in more detail in Note 5 to the financial statements in the Form 10-K. System Energy made payments under this arrangement, including interest, of $8.6 million in each of the six months ended June 30, 2025 and the six months ended June 30, 2024.

AR Searcy Partnership, LLC is a tax equity partnership that qualifies as a VIE, which Entergy Arkansas is required to consolidate as it is the primary beneficiary. As of June 30, 2025, AR Searcy Partnership, LLC recorded assets equal to $127.5 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $114 million. As of December 31, 2024, AR Searcy Partnership, LLC recorded assets equal to $129.7 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Arkansas’s ownership interest in the partnership was approximately $113.2 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Arkansas.

MS Sunflower Partnership, LLC is a tax equity partnership that qualifies as a VIE, which Entergy Mississippi is required to consolidate as it is the primary beneficiary. As of June 30, 2025, MS Sunflower Partnership, LLC recorded assets equal to $155.4 million, primarily consisting of property, plant, and equipment,
and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $136.9 million. As of December 31, 2024, MS Sunflower Partnership, LLC recorded assets equal to $157.8 million, primarily consisting of property, plant, and equipment, and the carrying value of Entergy Mississippi’s ownership interest in the partnership was approximately $132.7 million. The tax equity investor’s ownership interest is recorded as noncontrolling interest on the consolidated balance sheets of Entergy and Entergy Mississippi.
v3.25.2
Revenue
 6 Months Ended
Jun. 30, 2025
Revenue from Contract with Customer [Text Block] REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Operating Revenues

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended June 30, 2025 and 2024 were as follows:
20252024
(In Thousands)
Utility:
Residential$1,091,035 $1,009,836 
Commercial771,097 713,282 
Industrial945,901 792,721 
Governmental70,623 65,861 
Total billed retail2,878,656 2,581,700 
Sales for resale (a)146,457 54,579 
Other electric revenues (b)246,674 257,813 
Revenues from contracts with customers3,271,787 2,894,092 
Other Utility revenues (c)3,158 11,955 
Electric revenues3,274,945 2,906,047 
Natural gas revenues40,778 35,357 
Other revenues (d)13,126 12,216 
Total operating revenues$3,328,849 $2,953,620 
Entergy’s total revenues for the six months ended June 30, 2025 and 2024 were as follows:
20252024
(In Thousands)
Utility:
Residential$2,204,340 $2,080,177 
Commercial1,455,104 1,405,133 
Industrial1,720,020 1,541,679 
Governmental133,441 131,172 
Total billed retail5,512,905 5,158,161 
Sales for resale (a)198,330 133,583 
Other electric revenues (b)322,892 293,847 
Revenues from contracts with customers6,034,127 5,585,591 
Other Utility revenues (c)(1,316)26,962 
Electric revenues6,032,811 5,612,553 
Natural gas revenues112,509 101,024 
Other revenues (d)30,403 34,671 
Total operating revenues$6,175,723 $5,748,248 

The Utility operating companies’ total revenues for the three months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$212,265 $408,293 $172,575 $73,279 $224,623 
Commercial141,468 306,916 147,052 58,133 117,528 
Industrial174,555 570,303 53,629 7,800 139,614 
Governmental4,911 23,622 14,544 20,656 6,890 
Total billed retail533,199 1,309,134 387,800 159,868 488,655 
Sales for resale (a)84,533 109,243 61,713 10,027 5,195 
Other electric revenues (b)78,808 75,871 41,739 13,779 37,761 
Revenues from contracts with customers696,540 1,494,248 491,252 183,674 531,611 
Other revenues (c)1,147 1,256 623 107 30 
Electric revenues697,687 1,495,504 491,875 183,781 531,641 
Natural gas revenues— 14,559 — 26,219 — 
Total operating revenues$697,687 $1,510,063 $491,875 $210,000 $531,641 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$204,822 $353,975 $163,049 $71,842 $216,148 
Commercial132,950 265,869 142,173 57,360 114,930 
Industrial138,786 458,420 49,180 7,602 138,733 
Governmental4,433 21,223 14,061 19,167 6,977 
Total billed retail480,991 1,099,487 368,463 155,971 476,788 
Sales for resale (a)43,842 80,823 21,260 8,575 3,015 
Other electric revenues (b)81,733 74,670 50,718 12,811 39,224 
Revenues from contracts with customers606,566 1,254,980 440,441 177,357 519,027 
Other revenues (c)2,232 6,464 2,453 1,307 50 
Electric revenues608,798 1,261,444 442,894 178,664 519,077 
Natural gas revenues— 14,680 — 20,677 — 
Total operating revenues$608,798 $1,276,124 $442,894 $199,341 $519,077 

The Utility operating companies’ total revenues for the six months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$486,871 $786,531 $358,883 $138,969 $433,086 
Commercial273,085 570,116 282,925 105,755 223,223 
Industrial323,620 1,036,010 100,974 13,454 245,962 
Governmental9,130 45,290 28,234 37,185 13,602 
Total billed retail1,092,706 2,437,947 771,016 295,363 915,873 
Sales for resale (a)121,262 220,791 89,810 13,917 7,590 
Other electric revenues (b)94,884 113,861 53,538 13,214 50,057 
Revenues from contracts with customers1,308,852 2,772,599 914,364 322,494 973,520 
Other revenues (c)2,346 (5,149)1,220 212 60 
Electric revenues1,311,198 2,767,450 915,584 322,706 973,580 
Natural gas revenues— 44,160 — 68,349 — 
Total operating revenues$1,311,198 $2,811,610 $915,584 $391,055 $973,580 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$480,574 $699,003 $341,666 $139,520 $419,414 
Commercial274,258 522,565 274,491 110,585 223,234 
Industrial288,193 880,017 95,607 14,580 263,282 
Governmental9,133 43,044 27,390 37,521 14,084 
Total billed retail1,052,158 2,144,629 739,154 302,206 920,014 
Sales for resale (a)82,807 163,551 69,193 21,075 4,922 
Other electric revenues (b)91,074 112,615 44,516 9,592 38,736 
Revenues from contracts with customers1,226,039 2,420,795 852,863 332,873 963,672 
Other revenues (c)4,804 13,442 4,887 2,732 (104)
Electric revenues1,230,843 2,434,237 857,750 335,605 963,568 
Natural gas revenues— 44,327 — 56,697 — 
Total operating revenues$1,230,843 $2,478,564 $857,750 $392,302 $963,568 

(a)Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues.
(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators.
(c)Other Utility revenues include the occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
(d)Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, and operation and management services fees.
Entergy Arkansas [Member]  
Revenue from Contract with Customer [Text Block] REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Operating Revenues

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended June 30, 2025 and 2024 were as follows:
20252024
(In Thousands)
Utility:
Residential$1,091,035 $1,009,836 
Commercial771,097 713,282 
Industrial945,901 792,721 
Governmental70,623 65,861 
Total billed retail2,878,656 2,581,700 
Sales for resale (a)146,457 54,579 
Other electric revenues (b)246,674 257,813 
Revenues from contracts with customers3,271,787 2,894,092 
Other Utility revenues (c)3,158 11,955 
Electric revenues3,274,945 2,906,047 
Natural gas revenues40,778 35,357 
Other revenues (d)13,126 12,216 
Total operating revenues$3,328,849 $2,953,620 
Entergy’s total revenues for the six months ended June 30, 2025 and 2024 were as follows:
20252024
(In Thousands)
Utility:
Residential$2,204,340 $2,080,177 
Commercial1,455,104 1,405,133 
Industrial1,720,020 1,541,679 
Governmental133,441 131,172 
Total billed retail5,512,905 5,158,161 
Sales for resale (a)198,330 133,583 
Other electric revenues (b)322,892 293,847 
Revenues from contracts with customers6,034,127 5,585,591 
Other Utility revenues (c)(1,316)26,962 
Electric revenues6,032,811 5,612,553 
Natural gas revenues112,509 101,024 
Other revenues (d)30,403 34,671 
Total operating revenues$6,175,723 $5,748,248 

The Utility operating companies’ total revenues for the three months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$212,265 $408,293 $172,575 $73,279 $224,623 
Commercial141,468 306,916 147,052 58,133 117,528 
Industrial174,555 570,303 53,629 7,800 139,614 
Governmental4,911 23,622 14,544 20,656 6,890 
Total billed retail533,199 1,309,134 387,800 159,868 488,655 
Sales for resale (a)84,533 109,243 61,713 10,027 5,195 
Other electric revenues (b)78,808 75,871 41,739 13,779 37,761 
Revenues from contracts with customers696,540 1,494,248 491,252 183,674 531,611 
Other revenues (c)1,147 1,256 623 107 30 
Electric revenues697,687 1,495,504 491,875 183,781 531,641 
Natural gas revenues— 14,559 — 26,219 — 
Total operating revenues$697,687 $1,510,063 $491,875 $210,000 $531,641 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$204,822 $353,975 $163,049 $71,842 $216,148 
Commercial132,950 265,869 142,173 57,360 114,930 
Industrial138,786 458,420 49,180 7,602 138,733 
Governmental4,433 21,223 14,061 19,167 6,977 
Total billed retail480,991 1,099,487 368,463 155,971 476,788 
Sales for resale (a)43,842 80,823 21,260 8,575 3,015 
Other electric revenues (b)81,733 74,670 50,718 12,811 39,224 
Revenues from contracts with customers606,566 1,254,980 440,441 177,357 519,027 
Other revenues (c)2,232 6,464 2,453 1,307 50 
Electric revenues608,798 1,261,444 442,894 178,664 519,077 
Natural gas revenues— 14,680 — 20,677 — 
Total operating revenues$608,798 $1,276,124 $442,894 $199,341 $519,077 

The Utility operating companies’ total revenues for the six months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$486,871 $786,531 $358,883 $138,969 $433,086 
Commercial273,085 570,116 282,925 105,755 223,223 
Industrial323,620 1,036,010 100,974 13,454 245,962 
Governmental9,130 45,290 28,234 37,185 13,602 
Total billed retail1,092,706 2,437,947 771,016 295,363 915,873 
Sales for resale (a)121,262 220,791 89,810 13,917 7,590 
Other electric revenues (b)94,884 113,861 53,538 13,214 50,057 
Revenues from contracts with customers1,308,852 2,772,599 914,364 322,494 973,520 
Other revenues (c)2,346 (5,149)1,220 212 60 
Electric revenues1,311,198 2,767,450 915,584 322,706 973,580 
Natural gas revenues— 44,160 — 68,349 — 
Total operating revenues$1,311,198 $2,811,610 $915,584 $391,055 $973,580 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$480,574 $699,003 $341,666 $139,520 $419,414 
Commercial274,258 522,565 274,491 110,585 223,234 
Industrial288,193 880,017 95,607 14,580 263,282 
Governmental9,133 43,044 27,390 37,521 14,084 
Total billed retail1,052,158 2,144,629 739,154 302,206 920,014 
Sales for resale (a)82,807 163,551 69,193 21,075 4,922 
Other electric revenues (b)91,074 112,615 44,516 9,592 38,736 
Revenues from contracts with customers1,226,039 2,420,795 852,863 332,873 963,672 
Other revenues (c)4,804 13,442 4,887 2,732 (104)
Electric revenues1,230,843 2,434,237 857,750 335,605 963,568 
Natural gas revenues— 44,327 — 56,697 — 
Total operating revenues$1,230,843 $2,478,564 $857,750 $392,302 $963,568 

(a)Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues.
(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators.
(c)Other Utility revenues include the occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
(d)Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, and operation and management services fees.
Entergy Louisiana [Member]  
Revenue from Contract with Customer [Text Block] REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Operating Revenues

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended June 30, 2025 and 2024 were as follows:
20252024
(In Thousands)
Utility:
Residential$1,091,035 $1,009,836 
Commercial771,097 713,282 
Industrial945,901 792,721 
Governmental70,623 65,861 
Total billed retail2,878,656 2,581,700 
Sales for resale (a)146,457 54,579 
Other electric revenues (b)246,674 257,813 
Revenues from contracts with customers3,271,787 2,894,092 
Other Utility revenues (c)3,158 11,955 
Electric revenues3,274,945 2,906,047 
Natural gas revenues40,778 35,357 
Other revenues (d)13,126 12,216 
Total operating revenues$3,328,849 $2,953,620 
Entergy’s total revenues for the six months ended June 30, 2025 and 2024 were as follows:
20252024
(In Thousands)
Utility:
Residential$2,204,340 $2,080,177 
Commercial1,455,104 1,405,133 
Industrial1,720,020 1,541,679 
Governmental133,441 131,172 
Total billed retail5,512,905 5,158,161 
Sales for resale (a)198,330 133,583 
Other electric revenues (b)322,892 293,847 
Revenues from contracts with customers6,034,127 5,585,591 
Other Utility revenues (c)(1,316)26,962 
Electric revenues6,032,811 5,612,553 
Natural gas revenues112,509 101,024 
Other revenues (d)30,403 34,671 
Total operating revenues$6,175,723 $5,748,248 

The Utility operating companies’ total revenues for the three months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$212,265 $408,293 $172,575 $73,279 $224,623 
Commercial141,468 306,916 147,052 58,133 117,528 
Industrial174,555 570,303 53,629 7,800 139,614 
Governmental4,911 23,622 14,544 20,656 6,890 
Total billed retail533,199 1,309,134 387,800 159,868 488,655 
Sales for resale (a)84,533 109,243 61,713 10,027 5,195 
Other electric revenues (b)78,808 75,871 41,739 13,779 37,761 
Revenues from contracts with customers696,540 1,494,248 491,252 183,674 531,611 
Other revenues (c)1,147 1,256 623 107 30 
Electric revenues697,687 1,495,504 491,875 183,781 531,641 
Natural gas revenues— 14,559 — 26,219 — 
Total operating revenues$697,687 $1,510,063 $491,875 $210,000 $531,641 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$204,822 $353,975 $163,049 $71,842 $216,148 
Commercial132,950 265,869 142,173 57,360 114,930 
Industrial138,786 458,420 49,180 7,602 138,733 
Governmental4,433 21,223 14,061 19,167 6,977 
Total billed retail480,991 1,099,487 368,463 155,971 476,788 
Sales for resale (a)43,842 80,823 21,260 8,575 3,015 
Other electric revenues (b)81,733 74,670 50,718 12,811 39,224 
Revenues from contracts with customers606,566 1,254,980 440,441 177,357 519,027 
Other revenues (c)2,232 6,464 2,453 1,307 50 
Electric revenues608,798 1,261,444 442,894 178,664 519,077 
Natural gas revenues— 14,680 — 20,677 — 
Total operating revenues$608,798 $1,276,124 $442,894 $199,341 $519,077 

The Utility operating companies’ total revenues for the six months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$486,871 $786,531 $358,883 $138,969 $433,086 
Commercial273,085 570,116 282,925 105,755 223,223 
Industrial323,620 1,036,010 100,974 13,454 245,962 
Governmental9,130 45,290 28,234 37,185 13,602 
Total billed retail1,092,706 2,437,947 771,016 295,363 915,873 
Sales for resale (a)121,262 220,791 89,810 13,917 7,590 
Other electric revenues (b)94,884 113,861 53,538 13,214 50,057 
Revenues from contracts with customers1,308,852 2,772,599 914,364 322,494 973,520 
Other revenues (c)2,346 (5,149)1,220 212 60 
Electric revenues1,311,198 2,767,450 915,584 322,706 973,580 
Natural gas revenues— 44,160 — 68,349 — 
Total operating revenues$1,311,198 $2,811,610 $915,584 $391,055 $973,580 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$480,574 $699,003 $341,666 $139,520 $419,414 
Commercial274,258 522,565 274,491 110,585 223,234 
Industrial288,193 880,017 95,607 14,580 263,282 
Governmental9,133 43,044 27,390 37,521 14,084 
Total billed retail1,052,158 2,144,629 739,154 302,206 920,014 
Sales for resale (a)82,807 163,551 69,193 21,075 4,922 
Other electric revenues (b)91,074 112,615 44,516 9,592 38,736 
Revenues from contracts with customers1,226,039 2,420,795 852,863 332,873 963,672 
Other revenues (c)4,804 13,442 4,887 2,732 (104)
Electric revenues1,230,843 2,434,237 857,750 335,605 963,568 
Natural gas revenues— 44,327 — 56,697 — 
Total operating revenues$1,230,843 $2,478,564 $857,750 $392,302 $963,568 

(a)Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues.
(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators.
(c)Other Utility revenues include the occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
(d)Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, and operation and management services fees.
Entergy Mississippi [Member]  
Revenue from Contract with Customer [Text Block] REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Operating Revenues

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended June 30, 2025 and 2024 were as follows:
20252024
(In Thousands)
Utility:
Residential$1,091,035 $1,009,836 
Commercial771,097 713,282 
Industrial945,901 792,721 
Governmental70,623 65,861 
Total billed retail2,878,656 2,581,700 
Sales for resale (a)146,457 54,579 
Other electric revenues (b)246,674 257,813 
Revenues from contracts with customers3,271,787 2,894,092 
Other Utility revenues (c)3,158 11,955 
Electric revenues3,274,945 2,906,047 
Natural gas revenues40,778 35,357 
Other revenues (d)13,126 12,216 
Total operating revenues$3,328,849 $2,953,620 
Entergy’s total revenues for the six months ended June 30, 2025 and 2024 were as follows:
20252024
(In Thousands)
Utility:
Residential$2,204,340 $2,080,177 
Commercial1,455,104 1,405,133 
Industrial1,720,020 1,541,679 
Governmental133,441 131,172 
Total billed retail5,512,905 5,158,161 
Sales for resale (a)198,330 133,583 
Other electric revenues (b)322,892 293,847 
Revenues from contracts with customers6,034,127 5,585,591 
Other Utility revenues (c)(1,316)26,962 
Electric revenues6,032,811 5,612,553 
Natural gas revenues112,509 101,024 
Other revenues (d)30,403 34,671 
Total operating revenues$6,175,723 $5,748,248 

The Utility operating companies’ total revenues for the three months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$212,265 $408,293 $172,575 $73,279 $224,623 
Commercial141,468 306,916 147,052 58,133 117,528 
Industrial174,555 570,303 53,629 7,800 139,614 
Governmental4,911 23,622 14,544 20,656 6,890 
Total billed retail533,199 1,309,134 387,800 159,868 488,655 
Sales for resale (a)84,533 109,243 61,713 10,027 5,195 
Other electric revenues (b)78,808 75,871 41,739 13,779 37,761 
Revenues from contracts with customers696,540 1,494,248 491,252 183,674 531,611 
Other revenues (c)1,147 1,256 623 107 30 
Electric revenues697,687 1,495,504 491,875 183,781 531,641 
Natural gas revenues— 14,559 — 26,219 — 
Total operating revenues$697,687 $1,510,063 $491,875 $210,000 $531,641 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$204,822 $353,975 $163,049 $71,842 $216,148 
Commercial132,950 265,869 142,173 57,360 114,930 
Industrial138,786 458,420 49,180 7,602 138,733 
Governmental4,433 21,223 14,061 19,167 6,977 
Total billed retail480,991 1,099,487 368,463 155,971 476,788 
Sales for resale (a)43,842 80,823 21,260 8,575 3,015 
Other electric revenues (b)81,733 74,670 50,718 12,811 39,224 
Revenues from contracts with customers606,566 1,254,980 440,441 177,357 519,027 
Other revenues (c)2,232 6,464 2,453 1,307 50 
Electric revenues608,798 1,261,444 442,894 178,664 519,077 
Natural gas revenues— 14,680 — 20,677 — 
Total operating revenues$608,798 $1,276,124 $442,894 $199,341 $519,077 

The Utility operating companies’ total revenues for the six months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$486,871 $786,531 $358,883 $138,969 $433,086 
Commercial273,085 570,116 282,925 105,755 223,223 
Industrial323,620 1,036,010 100,974 13,454 245,962 
Governmental9,130 45,290 28,234 37,185 13,602 
Total billed retail1,092,706 2,437,947 771,016 295,363 915,873 
Sales for resale (a)121,262 220,791 89,810 13,917 7,590 
Other electric revenues (b)94,884 113,861 53,538 13,214 50,057 
Revenues from contracts with customers1,308,852 2,772,599 914,364 322,494 973,520 
Other revenues (c)2,346 (5,149)1,220 212 60 
Electric revenues1,311,198 2,767,450 915,584 322,706 973,580 
Natural gas revenues— 44,160 — 68,349 — 
Total operating revenues$1,311,198 $2,811,610 $915,584 $391,055 $973,580 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$480,574 $699,003 $341,666 $139,520 $419,414 
Commercial274,258 522,565 274,491 110,585 223,234 
Industrial288,193 880,017 95,607 14,580 263,282 
Governmental9,133 43,044 27,390 37,521 14,084 
Total billed retail1,052,158 2,144,629 739,154 302,206 920,014 
Sales for resale (a)82,807 163,551 69,193 21,075 4,922 
Other electric revenues (b)91,074 112,615 44,516 9,592 38,736 
Revenues from contracts with customers1,226,039 2,420,795 852,863 332,873 963,672 
Other revenues (c)4,804 13,442 4,887 2,732 (104)
Electric revenues1,230,843 2,434,237 857,750 335,605 963,568 
Natural gas revenues— 44,327 — 56,697 — 
Total operating revenues$1,230,843 $2,478,564 $857,750 $392,302 $963,568 

(a)Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues.
(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators.
(c)Other Utility revenues include the occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
(d)Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, and operation and management services fees.
Entergy New Orleans [Member]  
Revenue from Contract with Customer [Text Block] REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Operating Revenues

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended June 30, 2025 and 2024 were as follows:
20252024
(In Thousands)
Utility:
Residential$1,091,035 $1,009,836 
Commercial771,097 713,282 
Industrial945,901 792,721 
Governmental70,623 65,861 
Total billed retail2,878,656 2,581,700 
Sales for resale (a)146,457 54,579 
Other electric revenues (b)246,674 257,813 
Revenues from contracts with customers3,271,787 2,894,092 
Other Utility revenues (c)3,158 11,955 
Electric revenues3,274,945 2,906,047 
Natural gas revenues40,778 35,357 
Other revenues (d)13,126 12,216 
Total operating revenues$3,328,849 $2,953,620 
Entergy’s total revenues for the six months ended June 30, 2025 and 2024 were as follows:
20252024
(In Thousands)
Utility:
Residential$2,204,340 $2,080,177 
Commercial1,455,104 1,405,133 
Industrial1,720,020 1,541,679 
Governmental133,441 131,172 
Total billed retail5,512,905 5,158,161 
Sales for resale (a)198,330 133,583 
Other electric revenues (b)322,892 293,847 
Revenues from contracts with customers6,034,127 5,585,591 
Other Utility revenues (c)(1,316)26,962 
Electric revenues6,032,811 5,612,553 
Natural gas revenues112,509 101,024 
Other revenues (d)30,403 34,671 
Total operating revenues$6,175,723 $5,748,248 

The Utility operating companies’ total revenues for the three months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$212,265 $408,293 $172,575 $73,279 $224,623 
Commercial141,468 306,916 147,052 58,133 117,528 
Industrial174,555 570,303 53,629 7,800 139,614 
Governmental4,911 23,622 14,544 20,656 6,890 
Total billed retail533,199 1,309,134 387,800 159,868 488,655 
Sales for resale (a)84,533 109,243 61,713 10,027 5,195 
Other electric revenues (b)78,808 75,871 41,739 13,779 37,761 
Revenues from contracts with customers696,540 1,494,248 491,252 183,674 531,611 
Other revenues (c)1,147 1,256 623 107 30 
Electric revenues697,687 1,495,504 491,875 183,781 531,641 
Natural gas revenues— 14,559 — 26,219 — 
Total operating revenues$697,687 $1,510,063 $491,875 $210,000 $531,641 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$204,822 $353,975 $163,049 $71,842 $216,148 
Commercial132,950 265,869 142,173 57,360 114,930 
Industrial138,786 458,420 49,180 7,602 138,733 
Governmental4,433 21,223 14,061 19,167 6,977 
Total billed retail480,991 1,099,487 368,463 155,971 476,788 
Sales for resale (a)43,842 80,823 21,260 8,575 3,015 
Other electric revenues (b)81,733 74,670 50,718 12,811 39,224 
Revenues from contracts with customers606,566 1,254,980 440,441 177,357 519,027 
Other revenues (c)2,232 6,464 2,453 1,307 50 
Electric revenues608,798 1,261,444 442,894 178,664 519,077 
Natural gas revenues— 14,680 — 20,677 — 
Total operating revenues$608,798 $1,276,124 $442,894 $199,341 $519,077 

The Utility operating companies’ total revenues for the six months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$486,871 $786,531 $358,883 $138,969 $433,086 
Commercial273,085 570,116 282,925 105,755 223,223 
Industrial323,620 1,036,010 100,974 13,454 245,962 
Governmental9,130 45,290 28,234 37,185 13,602 
Total billed retail1,092,706 2,437,947 771,016 295,363 915,873 
Sales for resale (a)121,262 220,791 89,810 13,917 7,590 
Other electric revenues (b)94,884 113,861 53,538 13,214 50,057 
Revenues from contracts with customers1,308,852 2,772,599 914,364 322,494 973,520 
Other revenues (c)2,346 (5,149)1,220 212 60 
Electric revenues1,311,198 2,767,450 915,584 322,706 973,580 
Natural gas revenues— 44,160 — 68,349 — 
Total operating revenues$1,311,198 $2,811,610 $915,584 $391,055 $973,580 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$480,574 $699,003 $341,666 $139,520 $419,414 
Commercial274,258 522,565 274,491 110,585 223,234 
Industrial288,193 880,017 95,607 14,580 263,282 
Governmental9,133 43,044 27,390 37,521 14,084 
Total billed retail1,052,158 2,144,629 739,154 302,206 920,014 
Sales for resale (a)82,807 163,551 69,193 21,075 4,922 
Other electric revenues (b)91,074 112,615 44,516 9,592 38,736 
Revenues from contracts with customers1,226,039 2,420,795 852,863 332,873 963,672 
Other revenues (c)4,804 13,442 4,887 2,732 (104)
Electric revenues1,230,843 2,434,237 857,750 335,605 963,568 
Natural gas revenues— 44,327 — 56,697 — 
Total operating revenues$1,230,843 $2,478,564 $857,750 $392,302 $963,568 

(a)Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues.
(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators.
(c)Other Utility revenues include the occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
(d)Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, and operation and management services fees.
Entergy Texas [Member]  
Revenue from Contract with Customer [Text Block] REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Operating Revenues

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended June 30, 2025 and 2024 were as follows:
20252024
(In Thousands)
Utility:
Residential$1,091,035 $1,009,836 
Commercial771,097 713,282 
Industrial945,901 792,721 
Governmental70,623 65,861 
Total billed retail2,878,656 2,581,700 
Sales for resale (a)146,457 54,579 
Other electric revenues (b)246,674 257,813 
Revenues from contracts with customers3,271,787 2,894,092 
Other Utility revenues (c)3,158 11,955 
Electric revenues3,274,945 2,906,047 
Natural gas revenues40,778 35,357 
Other revenues (d)13,126 12,216 
Total operating revenues$3,328,849 $2,953,620 
Entergy’s total revenues for the six months ended June 30, 2025 and 2024 were as follows:
20252024
(In Thousands)
Utility:
Residential$2,204,340 $2,080,177 
Commercial1,455,104 1,405,133 
Industrial1,720,020 1,541,679 
Governmental133,441 131,172 
Total billed retail5,512,905 5,158,161 
Sales for resale (a)198,330 133,583 
Other electric revenues (b)322,892 293,847 
Revenues from contracts with customers6,034,127 5,585,591 
Other Utility revenues (c)(1,316)26,962 
Electric revenues6,032,811 5,612,553 
Natural gas revenues112,509 101,024 
Other revenues (d)30,403 34,671 
Total operating revenues$6,175,723 $5,748,248 

The Utility operating companies’ total revenues for the three months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$212,265 $408,293 $172,575 $73,279 $224,623 
Commercial141,468 306,916 147,052 58,133 117,528 
Industrial174,555 570,303 53,629 7,800 139,614 
Governmental4,911 23,622 14,544 20,656 6,890 
Total billed retail533,199 1,309,134 387,800 159,868 488,655 
Sales for resale (a)84,533 109,243 61,713 10,027 5,195 
Other electric revenues (b)78,808 75,871 41,739 13,779 37,761 
Revenues from contracts with customers696,540 1,494,248 491,252 183,674 531,611 
Other revenues (c)1,147 1,256 623 107 30 
Electric revenues697,687 1,495,504 491,875 183,781 531,641 
Natural gas revenues— 14,559 — 26,219 — 
Total operating revenues$697,687 $1,510,063 $491,875 $210,000 $531,641 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$204,822 $353,975 $163,049 $71,842 $216,148 
Commercial132,950 265,869 142,173 57,360 114,930 
Industrial138,786 458,420 49,180 7,602 138,733 
Governmental4,433 21,223 14,061 19,167 6,977 
Total billed retail480,991 1,099,487 368,463 155,971 476,788 
Sales for resale (a)43,842 80,823 21,260 8,575 3,015 
Other electric revenues (b)81,733 74,670 50,718 12,811 39,224 
Revenues from contracts with customers606,566 1,254,980 440,441 177,357 519,027 
Other revenues (c)2,232 6,464 2,453 1,307 50 
Electric revenues608,798 1,261,444 442,894 178,664 519,077 
Natural gas revenues— 14,680 — 20,677 — 
Total operating revenues$608,798 $1,276,124 $442,894 $199,341 $519,077 

The Utility operating companies’ total revenues for the six months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$486,871 $786,531 $358,883 $138,969 $433,086 
Commercial273,085 570,116 282,925 105,755 223,223 
Industrial323,620 1,036,010 100,974 13,454 245,962 
Governmental9,130 45,290 28,234 37,185 13,602 
Total billed retail1,092,706 2,437,947 771,016 295,363 915,873 
Sales for resale (a)121,262 220,791 89,810 13,917 7,590 
Other electric revenues (b)94,884 113,861 53,538 13,214 50,057 
Revenues from contracts with customers1,308,852 2,772,599 914,364 322,494 973,520 
Other revenues (c)2,346 (5,149)1,220 212 60 
Electric revenues1,311,198 2,767,450 915,584 322,706 973,580 
Natural gas revenues— 44,160 — 68,349 — 
Total operating revenues$1,311,198 $2,811,610 $915,584 $391,055 $973,580 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$480,574 $699,003 $341,666 $139,520 $419,414 
Commercial274,258 522,565 274,491 110,585 223,234 
Industrial288,193 880,017 95,607 14,580 263,282 
Governmental9,133 43,044 27,390 37,521 14,084 
Total billed retail1,052,158 2,144,629 739,154 302,206 920,014 
Sales for resale (a)82,807 163,551 69,193 21,075 4,922 
Other electric revenues (b)91,074 112,615 44,516 9,592 38,736 
Revenues from contracts with customers1,226,039 2,420,795 852,863 332,873 963,672 
Other revenues (c)4,804 13,442 4,887 2,732 (104)
Electric revenues1,230,843 2,434,237 857,750 335,605 963,568 
Natural gas revenues— 44,327 — 56,697 — 
Total operating revenues$1,230,843 $2,478,564 $857,750 $392,302 $963,568 

(a)Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues.
(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators.
(c)Other Utility revenues include the occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
(d)Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, and operation and management services fees.
System Energy [Member]  
Revenue from Contract with Customer [Text Block] REVENUE (Entergy Corporation, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy)
Operating Revenues

See Note 19 to the financial statements in the Form 10-K for a discussion of revenue recognition.  Entergy’s total revenues for the three months ended June 30, 2025 and 2024 were as follows:
20252024
(In Thousands)
Utility:
Residential$1,091,035 $1,009,836 
Commercial771,097 713,282 
Industrial945,901 792,721 
Governmental70,623 65,861 
Total billed retail2,878,656 2,581,700 
Sales for resale (a)146,457 54,579 
Other electric revenues (b)246,674 257,813 
Revenues from contracts with customers3,271,787 2,894,092 
Other Utility revenues (c)3,158 11,955 
Electric revenues3,274,945 2,906,047 
Natural gas revenues40,778 35,357 
Other revenues (d)13,126 12,216 
Total operating revenues$3,328,849 $2,953,620 
Entergy’s total revenues for the six months ended June 30, 2025 and 2024 were as follows:
20252024
(In Thousands)
Utility:
Residential$2,204,340 $2,080,177 
Commercial1,455,104 1,405,133 
Industrial1,720,020 1,541,679 
Governmental133,441 131,172 
Total billed retail5,512,905 5,158,161 
Sales for resale (a)198,330 133,583 
Other electric revenues (b)322,892 293,847 
Revenues from contracts with customers6,034,127 5,585,591 
Other Utility revenues (c)(1,316)26,962 
Electric revenues6,032,811 5,612,553 
Natural gas revenues112,509 101,024 
Other revenues (d)30,403 34,671 
Total operating revenues$6,175,723 $5,748,248 

The Utility operating companies’ total revenues for the three months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$212,265 $408,293 $172,575 $73,279 $224,623 
Commercial141,468 306,916 147,052 58,133 117,528 
Industrial174,555 570,303 53,629 7,800 139,614 
Governmental4,911 23,622 14,544 20,656 6,890 
Total billed retail533,199 1,309,134 387,800 159,868 488,655 
Sales for resale (a)84,533 109,243 61,713 10,027 5,195 
Other electric revenues (b)78,808 75,871 41,739 13,779 37,761 
Revenues from contracts with customers696,540 1,494,248 491,252 183,674 531,611 
Other revenues (c)1,147 1,256 623 107 30 
Electric revenues697,687 1,495,504 491,875 183,781 531,641 
Natural gas revenues— 14,559 — 26,219 — 
Total operating revenues$697,687 $1,510,063 $491,875 $210,000 $531,641 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$204,822 $353,975 $163,049 $71,842 $216,148 
Commercial132,950 265,869 142,173 57,360 114,930 
Industrial138,786 458,420 49,180 7,602 138,733 
Governmental4,433 21,223 14,061 19,167 6,977 
Total billed retail480,991 1,099,487 368,463 155,971 476,788 
Sales for resale (a)43,842 80,823 21,260 8,575 3,015 
Other electric revenues (b)81,733 74,670 50,718 12,811 39,224 
Revenues from contracts with customers606,566 1,254,980 440,441 177,357 519,027 
Other revenues (c)2,232 6,464 2,453 1,307 50 
Electric revenues608,798 1,261,444 442,894 178,664 519,077 
Natural gas revenues— 14,680 — 20,677 — 
Total operating revenues$608,798 $1,276,124 $442,894 $199,341 $519,077 

The Utility operating companies’ total revenues for the six months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$486,871 $786,531 $358,883 $138,969 $433,086 
Commercial273,085 570,116 282,925 105,755 223,223 
Industrial323,620 1,036,010 100,974 13,454 245,962 
Governmental9,130 45,290 28,234 37,185 13,602 
Total billed retail1,092,706 2,437,947 771,016 295,363 915,873 
Sales for resale (a)121,262 220,791 89,810 13,917 7,590 
Other electric revenues (b)94,884 113,861 53,538 13,214 50,057 
Revenues from contracts with customers1,308,852 2,772,599 914,364 322,494 973,520 
Other revenues (c)2,346 (5,149)1,220 212 60 
Electric revenues1,311,198 2,767,450 915,584 322,706 973,580 
Natural gas revenues— 44,160 — 68,349 — 
Total operating revenues$1,311,198 $2,811,610 $915,584 $391,055 $973,580 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$480,574 $699,003 $341,666 $139,520 $419,414 
Commercial274,258 522,565 274,491 110,585 223,234 
Industrial288,193 880,017 95,607 14,580 263,282 
Governmental9,133 43,044 27,390 37,521 14,084 
Total billed retail1,052,158 2,144,629 739,154 302,206 920,014 
Sales for resale (a)82,807 163,551 69,193 21,075 4,922 
Other electric revenues (b)91,074 112,615 44,516 9,592 38,736 
Revenues from contracts with customers1,226,039 2,420,795 852,863 332,873 963,672 
Other revenues (c)4,804 13,442 4,887 2,732 (104)
Electric revenues1,230,843 2,434,237 857,750 335,605 963,568 
Natural gas revenues— 44,327 — 56,697 — 
Total operating revenues$1,230,843 $2,478,564 $857,750 $392,302 $963,568 

(a)Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues.
(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators.
(c)Other Utility revenues include the occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
(d)Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, and operation and management services fees.
v3.25.2
Acquisitions, Held for Sale, and Dispositions (Notes)
 6 Months Ended
Jun. 30, 2025
Mergers, Acquisitions and Dispositions Disclosures HELD FOR SALE AND DISPOSITIONS (Entergy Corporation, Entergy Louisiana, and Entergy New Orleans)
Natural Gas Distribution Businesses

See Note 14 to the financial statements in the Form 10-K for information regarding the planned sale of the Entergy New Orleans and Entergy Louisiana natural gas distribution businesses. The following are updates to that discussion.

On October 28, 2023, Entergy New Orleans and Entergy Louisiana each entered into separate purchase and sale agreements with respect to the sale of their respective regulated natural gas local distribution company businesses to two separate affiliates of Bernhard Capital Partners Management LP. Under the purchase and sale agreements, Entergy New Orleans agreed to sell its regulated natural gas local distribution company business that serves customers in the Parish of Orleans, Louisiana, and Entergy Louisiana agreed to sell its regulated natural gas local distribution company business that serves customers in the Parish of East Baton Rouge, Louisiana. The Entergy New Orleans and Entergy Louisiana natural gas distribution businesses are reflected in Entergy’s Utility reportable segment and in the respective single reportable segment for each of Entergy New Orleans and Entergy Louisiana through June 30, 2025.
Required regulatory approval was received from the LPSC and the City Council in August 2024 and December 2024, respectively. In February 2025 the Metropolitan Council of the Parish of East Baton Rouge approved the proposed sale of the Entergy Louisiana natural gas distribution business and also approved the assignment of the parish franchise from Entergy Louisiana to Delta Capital Gas Company, LLC (a Bernhard Capital Partners Management LP affiliate).

The transactions had two phases: (1) an “Initial Phase” prior to regulatory approvals in connection with both transactions; and (2) a “Second Phase” following regulatory approvals in connection with both transactions to the extent that certain conditions were satisfied or, where permissible, waived for both transactions. As described above, the transactions received all required regulatory approvals, and the Second Phase commenced on March 5, 2025.

The Entergy Louisiana and Entergy New Orleans natural gas distribution businesses first met the criteria to be classified as held for sale in the quarter ended December 31, 2024, and continued to meet such criteria as of June 30, 2025. As of June 30, 2025, neither Entergy Louisiana nor Entergy New Orleans had recognized any write downs of the natural gas distribution business assets as a result of their classification as held for sale, as neither sale was expected to result in a loss. The assets and liabilities of the Entergy Louisiana and Entergy New Orleans natural gas distribution businesses classified as held for sale on Entergy’s, Entergy Louisiana’s, and Entergy New Orleans’s consolidated balance sheets as of June 30, 2025 and December 31, 2024 included the following amounts:
June 30, 2025
December 31, 2024
EntergyEntergy LouisianaEntergy New OrleansEntergyEntergy LouisianaEntergy New Orleans
(In Thousands)(In Thousands)
Deferred fuel$5,829 $3,324 $2,505 $5,608 $727 $4,881 
Fuel inventory - at average cost4,828 295 4,5334,493 702 3,791
Materials and supplies7,6041,1726,4325,4511,0454,406
Prepayments and other1,341 54 1,28722 — 22
Total current assets held for sale$19,602 $4,845 $14,757 $15,574 $2,474 $13,100 
Property, plant, and equipment - natural gas$697,812 $311,898 $385,914 $679,502 $303,193 $376,309 
Construction work in progress2,710 1,730 980 2,959 1,085 1,874 
Less - accumulated depreciation and amortization(283,404)(141,818)(141,586)(276,388)(139,556)(136,832)
Other regulatory assets33,523 6,936 23,667 35,381 8,947 23,682 
Goodwill (a)6,517 — — 6,474 — — 
Pension and other postretirement assets15,171 — 19,952 14,663 — 19,499 
Other199 — 199 206 — 206 
Total non-current assets held for sale$472,528 $178,746 $289,126 $462,797 $173,669 $284,738 
Accounts payable$2,945 $295 $2,650 $702 $702 $— 
Customer deposits5,327 2,572 2,755 6,214 1,984 4,230 
Taxes accrued— — — 13 13 — 
Other1,352 536 816 1,401 589 812 
Total current liabilities held for sale (b)
$9,624 $3,403 $6,221 $8,330 $3,288 $5,042 
Regulatory liability for income taxes - net$28,438 $3,193 $25,245 $31,575 $4,981 $26,594 
Other regulatory liabilities2,579 945 1,634 1,611 1,214 397 
Pension and other postretirement liabilities4,236 4,643 1,610 3,976 4,525 1,197 
Other4,146 1,414 2,732 3,844 1,194 2,650 
Total non-current liabilities held for sale (c)
$39,399 $10,195 $31,221 $41,006 $11,914 $30,838 
(a)    Goodwill was allocated to the natural gas distribution business based on its relative fair value compared to the retained portion of the reporting unit.
(b)    Included within other current liabilities on the respective consolidated balance sheets.
(c)    Included within other non-current liabilities on the respective consolidated balance sheets.

Entergy Louisiana and Entergy New Orleans continued to recognize depreciation on the natural gas distribution businesses assets through June 30, 2025 since they received revenues through utility customer rates through the closing of the transaction, and because the final purchase price for the natural gas distribution businesses was adjusted by an amount equal to that depreciation, among other adjustments.

The pre-tax income for the Entergy Louisiana and Entergy New Orleans natural gas distribution businesses, excluding interest and corporate allocations, included in Entergy’s, Entergy Louisiana’s, and Entergy New Orleans’s consolidated income statements for the three and six months ended June 30, 2025 and 2024 is as follows:
Three Months EndedSix Months Ended
2025202420252024
(In Thousands)(In Thousands)
Entergy$9,484 $7,527 $31,500 $27,459 
Entergy Louisiana$2,272 $2,754 $12,047 $12,858 
Entergy New Orleans$7,212 $4,773 $19,453 $14,601 

On July 1, 2025, Entergy Louisiana and Entergy New Orleans completed the sale of their natural gas distribution businesses. The Entergy Louisiana natural gas distribution business was sold for a purchase price of $203 million and results in an expected gain of $12 million ($9 million net-of-tax), net of $20 million in transaction costs. The Entergy New Orleans natural gas distribution business was sold for a purchase price of $288 million and results in an expected gain of $5 million ($4 million net-of-tax), net of $19 million in transaction costs. The sale of the natural gas distribution businesses results in an expected gain of $11 million ($6 million net-of-tax) for Entergy, which includes goodwill of $7 million that was attributed to the businesses sold and derecognized following the completion of the sale. Entergy New Orleans deferred $4 million of its respective gain as a regulatory liability, which will be amortized over three years beginning September 2026, to be shared with electric utility customers, as required by the City Council. The sale price is subject to a true-up related to the estimated value of assets and liabilities transferred, which may result in subsequent adjustments to the gain recorded in third quarter 2025. Additionally, as a result of the sale, in third quarter 2025, Entergy New Orleans expects to write-off $12 million of natural gas plant assets that were not included in the sale to Delta Capital Gas Company, LLC, and which will not be recovered. See Note 10 to the financial statements herein for discussion of the tax accounting effects of the sale.
Entergy Louisiana [Member]  
Mergers, Acquisitions and Dispositions Disclosures HELD FOR SALE AND DISPOSITIONS (Entergy Corporation, Entergy Louisiana, and Entergy New Orleans)
Natural Gas Distribution Businesses

See Note 14 to the financial statements in the Form 10-K for information regarding the planned sale of the Entergy New Orleans and Entergy Louisiana natural gas distribution businesses. The following are updates to that discussion.

On October 28, 2023, Entergy New Orleans and Entergy Louisiana each entered into separate purchase and sale agreements with respect to the sale of their respective regulated natural gas local distribution company businesses to two separate affiliates of Bernhard Capital Partners Management LP. Under the purchase and sale agreements, Entergy New Orleans agreed to sell its regulated natural gas local distribution company business that serves customers in the Parish of Orleans, Louisiana, and Entergy Louisiana agreed to sell its regulated natural gas local distribution company business that serves customers in the Parish of East Baton Rouge, Louisiana. The Entergy New Orleans and Entergy Louisiana natural gas distribution businesses are reflected in Entergy’s Utility reportable segment and in the respective single reportable segment for each of Entergy New Orleans and Entergy Louisiana through June 30, 2025.
Required regulatory approval was received from the LPSC and the City Council in August 2024 and December 2024, respectively. In February 2025 the Metropolitan Council of the Parish of East Baton Rouge approved the proposed sale of the Entergy Louisiana natural gas distribution business and also approved the assignment of the parish franchise from Entergy Louisiana to Delta Capital Gas Company, LLC (a Bernhard Capital Partners Management LP affiliate).

The transactions had two phases: (1) an “Initial Phase” prior to regulatory approvals in connection with both transactions; and (2) a “Second Phase” following regulatory approvals in connection with both transactions to the extent that certain conditions were satisfied or, where permissible, waived for both transactions. As described above, the transactions received all required regulatory approvals, and the Second Phase commenced on March 5, 2025.

The Entergy Louisiana and Entergy New Orleans natural gas distribution businesses first met the criteria to be classified as held for sale in the quarter ended December 31, 2024, and continued to meet such criteria as of June 30, 2025. As of June 30, 2025, neither Entergy Louisiana nor Entergy New Orleans had recognized any write downs of the natural gas distribution business assets as a result of their classification as held for sale, as neither sale was expected to result in a loss. The assets and liabilities of the Entergy Louisiana and Entergy New Orleans natural gas distribution businesses classified as held for sale on Entergy’s, Entergy Louisiana’s, and Entergy New Orleans’s consolidated balance sheets as of June 30, 2025 and December 31, 2024 included the following amounts:
June 30, 2025
December 31, 2024
EntergyEntergy LouisianaEntergy New OrleansEntergyEntergy LouisianaEntergy New Orleans
(In Thousands)(In Thousands)
Deferred fuel$5,829 $3,324 $2,505 $5,608 $727 $4,881 
Fuel inventory - at average cost4,828 295 4,5334,493 702 3,791
Materials and supplies7,6041,1726,4325,4511,0454,406
Prepayments and other1,341 54 1,28722 — 22
Total current assets held for sale$19,602 $4,845 $14,757 $15,574 $2,474 $13,100 
Property, plant, and equipment - natural gas$697,812 $311,898 $385,914 $679,502 $303,193 $376,309 
Construction work in progress2,710 1,730 980 2,959 1,085 1,874 
Less - accumulated depreciation and amortization(283,404)(141,818)(141,586)(276,388)(139,556)(136,832)
Other regulatory assets33,523 6,936 23,667 35,381 8,947 23,682 
Goodwill (a)6,517 — — 6,474 — — 
Pension and other postretirement assets15,171 — 19,952 14,663 — 19,499 
Other199 — 199 206 — 206 
Total non-current assets held for sale$472,528 $178,746 $289,126 $462,797 $173,669 $284,738 
Accounts payable$2,945 $295 $2,650 $702 $702 $— 
Customer deposits5,327 2,572 2,755 6,214 1,984 4,230 
Taxes accrued— — — 13 13 — 
Other1,352 536 816 1,401 589 812 
Total current liabilities held for sale (b)
$9,624 $3,403 $6,221 $8,330 $3,288 $5,042 
Regulatory liability for income taxes - net$28,438 $3,193 $25,245 $31,575 $4,981 $26,594 
Other regulatory liabilities2,579 945 1,634 1,611 1,214 397 
Pension and other postretirement liabilities4,236 4,643 1,610 3,976 4,525 1,197 
Other4,146 1,414 2,732 3,844 1,194 2,650 
Total non-current liabilities held for sale (c)
$39,399 $10,195 $31,221 $41,006 $11,914 $30,838 
(a)    Goodwill was allocated to the natural gas distribution business based on its relative fair value compared to the retained portion of the reporting unit.
(b)    Included within other current liabilities on the respective consolidated balance sheets.
(c)    Included within other non-current liabilities on the respective consolidated balance sheets.

Entergy Louisiana and Entergy New Orleans continued to recognize depreciation on the natural gas distribution businesses assets through June 30, 2025 since they received revenues through utility customer rates through the closing of the transaction, and because the final purchase price for the natural gas distribution businesses was adjusted by an amount equal to that depreciation, among other adjustments.

The pre-tax income for the Entergy Louisiana and Entergy New Orleans natural gas distribution businesses, excluding interest and corporate allocations, included in Entergy’s, Entergy Louisiana’s, and Entergy New Orleans’s consolidated income statements for the three and six months ended June 30, 2025 and 2024 is as follows:
Three Months EndedSix Months Ended
2025202420252024
(In Thousands)(In Thousands)
Entergy$9,484 $7,527 $31,500 $27,459 
Entergy Louisiana$2,272 $2,754 $12,047 $12,858 
Entergy New Orleans$7,212 $4,773 $19,453 $14,601 

On July 1, 2025, Entergy Louisiana and Entergy New Orleans completed the sale of their natural gas distribution businesses. The Entergy Louisiana natural gas distribution business was sold for a purchase price of $203 million and results in an expected gain of $12 million ($9 million net-of-tax), net of $20 million in transaction costs. The Entergy New Orleans natural gas distribution business was sold for a purchase price of $288 million and results in an expected gain of $5 million ($4 million net-of-tax), net of $19 million in transaction costs. The sale of the natural gas distribution businesses results in an expected gain of $11 million ($6 million net-of-tax) for Entergy, which includes goodwill of $7 million that was attributed to the businesses sold and derecognized following the completion of the sale. Entergy New Orleans deferred $4 million of its respective gain as a regulatory liability, which will be amortized over three years beginning September 2026, to be shared with electric utility customers, as required by the City Council. The sale price is subject to a true-up related to the estimated value of assets and liabilities transferred, which may result in subsequent adjustments to the gain recorded in third quarter 2025. Additionally, as a result of the sale, in third quarter 2025, Entergy New Orleans expects to write-off $12 million of natural gas plant assets that were not included in the sale to Delta Capital Gas Company, LLC, and which will not be recovered. See Note 10 to the financial statements herein for discussion of the tax accounting effects of the sale.
Entergy New Orleans [Member]  
Mergers, Acquisitions and Dispositions Disclosures HELD FOR SALE AND DISPOSITIONS (Entergy Corporation, Entergy Louisiana, and Entergy New Orleans)
Natural Gas Distribution Businesses

See Note 14 to the financial statements in the Form 10-K for information regarding the planned sale of the Entergy New Orleans and Entergy Louisiana natural gas distribution businesses. The following are updates to that discussion.

On October 28, 2023, Entergy New Orleans and Entergy Louisiana each entered into separate purchase and sale agreements with respect to the sale of their respective regulated natural gas local distribution company businesses to two separate affiliates of Bernhard Capital Partners Management LP. Under the purchase and sale agreements, Entergy New Orleans agreed to sell its regulated natural gas local distribution company business that serves customers in the Parish of Orleans, Louisiana, and Entergy Louisiana agreed to sell its regulated natural gas local distribution company business that serves customers in the Parish of East Baton Rouge, Louisiana. The Entergy New Orleans and Entergy Louisiana natural gas distribution businesses are reflected in Entergy’s Utility reportable segment and in the respective single reportable segment for each of Entergy New Orleans and Entergy Louisiana through June 30, 2025.
Required regulatory approval was received from the LPSC and the City Council in August 2024 and December 2024, respectively. In February 2025 the Metropolitan Council of the Parish of East Baton Rouge approved the proposed sale of the Entergy Louisiana natural gas distribution business and also approved the assignment of the parish franchise from Entergy Louisiana to Delta Capital Gas Company, LLC (a Bernhard Capital Partners Management LP affiliate).

The transactions had two phases: (1) an “Initial Phase” prior to regulatory approvals in connection with both transactions; and (2) a “Second Phase” following regulatory approvals in connection with both transactions to the extent that certain conditions were satisfied or, where permissible, waived for both transactions. As described above, the transactions received all required regulatory approvals, and the Second Phase commenced on March 5, 2025.

The Entergy Louisiana and Entergy New Orleans natural gas distribution businesses first met the criteria to be classified as held for sale in the quarter ended December 31, 2024, and continued to meet such criteria as of June 30, 2025. As of June 30, 2025, neither Entergy Louisiana nor Entergy New Orleans had recognized any write downs of the natural gas distribution business assets as a result of their classification as held for sale, as neither sale was expected to result in a loss. The assets and liabilities of the Entergy Louisiana and Entergy New Orleans natural gas distribution businesses classified as held for sale on Entergy’s, Entergy Louisiana’s, and Entergy New Orleans’s consolidated balance sheets as of June 30, 2025 and December 31, 2024 included the following amounts:
June 30, 2025
December 31, 2024
EntergyEntergy LouisianaEntergy New OrleansEntergyEntergy LouisianaEntergy New Orleans
(In Thousands)(In Thousands)
Deferred fuel$5,829 $3,324 $2,505 $5,608 $727 $4,881 
Fuel inventory - at average cost4,828 295 4,5334,493 702 3,791
Materials and supplies7,6041,1726,4325,4511,0454,406
Prepayments and other1,341 54 1,28722 — 22
Total current assets held for sale$19,602 $4,845 $14,757 $15,574 $2,474 $13,100 
Property, plant, and equipment - natural gas$697,812 $311,898 $385,914 $679,502 $303,193 $376,309 
Construction work in progress2,710 1,730 980 2,959 1,085 1,874 
Less - accumulated depreciation and amortization(283,404)(141,818)(141,586)(276,388)(139,556)(136,832)
Other regulatory assets33,523 6,936 23,667 35,381 8,947 23,682 
Goodwill (a)6,517 — — 6,474 — — 
Pension and other postretirement assets15,171 — 19,952 14,663 — 19,499 
Other199 — 199 206 — 206 
Total non-current assets held for sale$472,528 $178,746 $289,126 $462,797 $173,669 $284,738 
Accounts payable$2,945 $295 $2,650 $702 $702 $— 
Customer deposits5,327 2,572 2,755 6,214 1,984 4,230 
Taxes accrued— — — 13 13 — 
Other1,352 536 816 1,401 589 812 
Total current liabilities held for sale (b)
$9,624 $3,403 $6,221 $8,330 $3,288 $5,042 
Regulatory liability for income taxes - net$28,438 $3,193 $25,245 $31,575 $4,981 $26,594 
Other regulatory liabilities2,579 945 1,634 1,611 1,214 397 
Pension and other postretirement liabilities4,236 4,643 1,610 3,976 4,525 1,197 
Other4,146 1,414 2,732 3,844 1,194 2,650 
Total non-current liabilities held for sale (c)
$39,399 $10,195 $31,221 $41,006 $11,914 $30,838 
(a)    Goodwill was allocated to the natural gas distribution business based on its relative fair value compared to the retained portion of the reporting unit.
(b)    Included within other current liabilities on the respective consolidated balance sheets.
(c)    Included within other non-current liabilities on the respective consolidated balance sheets.

Entergy Louisiana and Entergy New Orleans continued to recognize depreciation on the natural gas distribution businesses assets through June 30, 2025 since they received revenues through utility customer rates through the closing of the transaction, and because the final purchase price for the natural gas distribution businesses was adjusted by an amount equal to that depreciation, among other adjustments.

The pre-tax income for the Entergy Louisiana and Entergy New Orleans natural gas distribution businesses, excluding interest and corporate allocations, included in Entergy’s, Entergy Louisiana’s, and Entergy New Orleans’s consolidated income statements for the three and six months ended June 30, 2025 and 2024 is as follows:
Three Months EndedSix Months Ended
2025202420252024
(In Thousands)(In Thousands)
Entergy$9,484 $7,527 $31,500 $27,459 
Entergy Louisiana$2,272 $2,754 $12,047 $12,858 
Entergy New Orleans$7,212 $4,773 $19,453 $14,601 

On July 1, 2025, Entergy Louisiana and Entergy New Orleans completed the sale of their natural gas distribution businesses. The Entergy Louisiana natural gas distribution business was sold for a purchase price of $203 million and results in an expected gain of $12 million ($9 million net-of-tax), net of $20 million in transaction costs. The Entergy New Orleans natural gas distribution business was sold for a purchase price of $288 million and results in an expected gain of $5 million ($4 million net-of-tax), net of $19 million in transaction costs. The sale of the natural gas distribution businesses results in an expected gain of $11 million ($6 million net-of-tax) for Entergy, which includes goodwill of $7 million that was attributed to the businesses sold and derecognized following the completion of the sale. Entergy New Orleans deferred $4 million of its respective gain as a regulatory liability, which will be amortized over three years beginning September 2026, to be shared with electric utility customers, as required by the City Council. The sale price is subject to a true-up related to the estimated value of assets and liabilities transferred, which may result in subsequent adjustments to the gain recorded in third quarter 2025. Additionally, as a result of the sale, in third quarter 2025, Entergy New Orleans expects to write-off $12 million of natural gas plant assets that were not included in the sale to Delta Capital Gas Company, LLC, and which will not be recovered. See Note 10 to the financial statements herein for discussion of the tax accounting effects of the sale.
v3.25.2
Insider Trading Arrangements
 3 Months Ended
Jun. 30, 2025
Trading Arrangements, by Individual  
Material Terms of Trading Arrangement
No director or officer of Entergy or any of the Registrant Subsidiaries adopted, modified, or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement” during the three months ended June 30, 2025.
Rule 10b5-1 Arrangement Adopted false
Non-Rule 10b5-1 Arrangement Adopted false
Rule 10b5-1 Arrangement Terminated false
Non-Rule 10b5-1 Arrangement Terminated false
v3.25.2
Equity (Tables)
 6 Months Ended
Jun. 30, 2025
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]
The following tables present Entergy’s basic and diluted earnings per share calculations for the three and six months ended June 30, 2025 and 2024, included on the consolidated income statements:
For the Three Months Ended June 30,
20252024
(Dollars In Thousands, Except Per Share Data; Shares in Millions)
$/share$/share
Consolidated net income$471,954 $51,732 
Less: Preferred dividend requirements of subsidiaries and noncontrolling interests4,024 2,810 
Net income attributable to Entergy Corporation$467,930 $48,922 
Basic shares and earnings per average common share439.2 $1.07 427.2 $0.11 
Average dilutive effect of:
Stock options0.9 — 0.6 — 
Other equity plans1.2 — 1.0 — 
Equity forwards4.4 (0.02)— — 
Diluted shares and earnings per average common share445.7 $1.05 428.8 $0.11 

For the Six Months Ended June 30,
20252024
(Dollars In Thousands, Except Per Share Data; Shares in Millions)
$/share$/share
Consolidated net income$834,376 $128,268 
Less: Preferred dividend requirements of subsidiaries and noncontrolling interests5,686 4,065 
Net income attributable to Entergy Corporation$828,690 $124,203 
Basic shares and earnings per average common share434.8 $1.91 426.8 $0.29 
Average dilutive effect of:
Stock options1.0 — 0.5 — 
Other equity plans1.3 (0.01)1.0 — 
Equity forwards6.3 (0.03)— — 
Diluted shares and earnings per average common share443.4 $1.87 428.3 $0.29 

Earnings per share dilution resulting from stock options outstanding and other equity plans is determined under the treasury stock method. The calculation of diluted earnings per share excluded 366,136 stock options
outstanding for the three months ended June 30, 2025 and 1,448,982 stock options outstanding for the three months ended June 30, 2024 because their effect would have been antidilutive. The calculation of diluted earnings per share excluded 305,113 stock options outstanding for the six months ended June 30, 2025 and 1,471,220 stock options outstanding for the six months ended June 30, 2024 because their effect would have been antidilutive. Until settlement of the forward sale agreements discussed below in “Equity Distribution Program” and “Equity Forward Sale Agreements,” earnings per share dilution resulting from the agreements, if any, is determined under the treasury stock method. Share dilution occurs when the average market price of Entergy Corporation’s common stock is higher than the average forward sales price. The calculation of diluted earnings per share excluded 2,423,880 shares for the three months ended June 30, 2025 and 2,897,964 shares for the three months ended June 30, 2024 under forward sale agreements outstanding because their effect would have been antidilutive. The calculation of diluted earnings per share excluded 1,304,889 shares for the six months ended June 30, 2025 and 2,942,440 shares for the six months ended June 30, 2024 under forward sale agreements outstanding because their effect would have been antidilutive.
Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block] The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the three months ended June 30, 2025 and 2024:
Pension and Other Postretirement Plan Changes
20252024
(In Thousands)
Beginning balance, April 1,$39,040 ($166,128)
Amounts reclassified from accumulated other comprehensive income (loss)(4,602)246,489 
Net other comprehensive income (loss) for the period(4,602)246,489 
Ending balance, June 30,$34,438 $80,361 

The following table presents changes in accumulated other comprehensive income (loss) for Entergy for the six months ended June 30, 2025 and 2024:
Pension and Other Postretirement Plan Changes
20252024
(In Thousands)
Beginning balance, January 1,$42,769 ($162,460)
Amounts reclassified from accumulated other comprehensive income (loss)
(8,331)242,821 
Net other comprehensive income (loss) for the period(8,331)242,821 
Ending balance, June 30,$34,438 $80,361 
Reclassification out of Accumulated Other Comprehensive Income [Table Text Block]
Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the three months ended June 30, 2025 and 2024 are as follows:
Amounts reclassified from AOCIIncome Statement Location
20252024
(In Thousands)
Pension and other postretirement plan changes
   Amortization of prior service credit$3,462 $3,473 (a)
   Amortization of net gain2,551 1,641 (a)
   Settlement loss— (316,974)(a)
Total amortization and settlement loss6,013 (311,860)
Income taxes(1,411)65,371 Income taxes
Total amortization and settlement loss (net of tax)$4,602 ($246,489)
Total reclassifications for the period (net of tax)$4,602 ($246,489)

(a)These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.
Total reclassifications out of accumulated other comprehensive income (loss) (AOCI) for Entergy for the six months ended June 30, 2025 and 2024 are as follows:
Amounts reclassified from AOCIIncome Statement Location
20252024
(In Thousands)
Pension and other postretirement plan changes
   Amortization of prior service credit$6,924 $6,946 (a)
   Amortization of net gain5,102 3,037 (a)
   Settlement loss— (316,974)(a)
Total amortization and settlement loss12,026 (306,991)
Income taxes(3,695)64,170 Income taxes
Total amortization and settlement loss (net of tax)
$8,331 ($242,821)
Total reclassifications for the period (net of tax)$8,331 ($242,821)

(a)These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost. See Note 6 to the financial statements herein for additional details.
Schedule of Forward Sales Agreements
The following forward sale agreements were entered into by Entergy Corporation under its at the market equity distribution program during the six months ended June 30, 2025:
Effective DateShares of Common Stock per Forward Sale AgreementMaturity DateForward Sale Price per ShareGross Sales PriceForward Sellers Fees
(Dollars In Thousands, Except Per Share Data)
March 20252,713,790 August 2026$84.77 $232,216 $2,322 
Schedule of Forward Sales Agreements Settled
During the six months ended June 30, 2025, Entergy Corporation physically settled its obligations under the following forward sale agreements:
Effective Date of Forward Sale Agreements
Shares of Common Stock Issued
Gross Sales PriceForward Sellers FeesForward Sale Price per ShareCash Proceeds at Settlement
(Dollars In Thousands, Except Per Share Data)
Forward sale agreements settled in May 2025:
December 20235,506,492 $280,459 $2,805 
March 2024569,844 $29,318 $293 
March 20242,320,830 $119,153 $1,192 
May 20242,556,832 $142,387 $1,424 
May 20242,466,470 $134,396 $1,344 
June 20242,140,006 $114,540 $1,145 
Total15,560,474 $51.78 $805,669 
Entergy Louisiana [Member]  
Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block]
The following table presents changes in accumulated other comprehensive income for Entergy Louisiana for the three months ended June 30, 2025 and 2024:
Pension and Other Postretirement Plan Changes
20252024
(In Thousands)
Beginning balance, April 1,$52,687 $52,774 
Amounts reclassified from accumulated other comprehensive income(2,132)(2,023)
Net other comprehensive loss for the period(2,132)(2,023)
Ending balance, June 30,$50,555 $50,751 

The following table presents changes in accumulated other comprehensive income for Entergy Louisiana for the six months ended June 30, 2025 and 2024:
Pension and Other Postretirement Plan Changes
20252024
(In Thousands)
Beginning balance, January 1,$53,658 $54,798 
Amounts reclassified from accumulated other comprehensive income(3,103)(4,047)
Net other comprehensive loss for the period(3,103)(4,047)
Ending balance, June 30,$50,555 $50,751 
Reclassification out of Accumulated Other Comprehensive Income [Table Text Block]
Total reclassifications out of accumulated other comprehensive income (AOCI) for Entergy Louisiana for the three months ended June 30, 2025 and 2024 are as follows:
Amounts reclassified from AOCIIncome Statement Location
20252024
(In Thousands)
Pension and other postretirement plan changes
   Amortization of prior service credit$1,136 $1,136 (a)
   Amortization of net gain1,719 1,632 (a)
Total amortization2,855 2,768 
Income taxes(723)(745)Income taxes
Total amortization (net of tax)
2,132 2,023 
Total reclassifications for the period (net of tax)$2,132 $2,023 

(a)These accumulated other comprehensive income components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.
Total reclassifications out of accumulated other comprehensive income (AOCI) for Entergy Louisiana for the six months ended June 30, 2025 and 2024 are as follows:
Amounts reclassified from AOCIIncome Statement Location
20252024
(In Thousands)
Pension and other postretirement plan changes
   Amortization of prior service credit$2,272 $2,272 (a)
   Amortization of net gain3,438 3,266 (a)
Total amortization
5,710 5,538 
Income taxes(2,607)(1,491)Income taxes
Total amortization (net of tax)
$3,103 $4,047 
Total reclassifications for the period (net of tax)$3,103 $4,047 

(a)These accumulated other comprehensive income components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.
v3.25.2
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Tables)
 6 Months Ended
Jun. 30, 2025
Schedule of Line of Credit Facilities [Table Text Block] The following is a summary of the amounts outstanding and capacity available under the credit facility as of June 30, 2025:
Capacity BorrowingsLetters
of Credit		Capacity
Available
(In Millions)
$3,000$—$4$2,996
Schedule of Long-Term Debt Instruments [Table Text Block]
The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2025 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$29,929,838 $27,487,432 
Entergy Arkansas$5,438,033 $4,883,114 
Entergy Louisiana$10,399,823 $9,410,962 
Entergy Mississippi$3,020,687 $2,720,374 
Entergy New Orleans$737,560 $697,241 
Entergy Texas$4,038,417 $3,729,255 
System Energy$1,094,396 $1,101,434 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2024 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$27,991,595 $25,181,802 
Entergy Arkansas$5,122,494 $4,546,643 
Entergy Louisiana$9,866,453 $8,751,266 
Entergy Mississippi$2,427,073 $2,116,246 
Entergy New Orleans$735,467 $697,466 
Entergy Texas$3,552,443 $3,176,230 
System Energy$1,089,736 $1,063,946 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Arkansas [Member]  
Schedule of Line of Credit Facilities [Table Text Block]
Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2025 as follows:
CompanyExpiration
Date		Amount of
Facility		Interest Rate
(a)		Amount Drawn
as of
June 30, 2025		Letters of Credit
Outstanding as of
June 30, 2025
Entergy ArkansasApril 2026$25 million (b)6.28%$—$—
Entergy ArkansasJune 2030$300 million (c)5.55%$—$—
Entergy LouisianaJune 2030$400 million (c)5.68%$—$—
Entergy MississippiJune 2030$300 million (c)5.55%$—$—
Entergy New OrleansJune 2027$25 million (c)6.05%$—$—
Entergy TexasJune 2030$300 million (c)5.68%$—$1.1 million

(a)The interest rate is the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility.
(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.
(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $5 million for Entergy Mississippi; $10 million for Entergy New Orleans; and $25 million for Entergy Texas.
Schedule of uncommitted standby letter of credit facilities [Table Text Block] The following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2025:
CompanyAmount of
Uncommitted Facility		Letter of Credit Fee
Letters of Credit
Issued as of
June 30, 2025
(a)
Entergy Arkansas$25 million0.78%$23.6 million
Entergy Arkansas
$75 million0.50%$—
Entergy Louisiana$125 million 0.78%$74.3 million
Entergy Louisiana
$45 million 0.50%$—
Entergy Mississippi$65 million0.78%$47.3 million (b)
Entergy Mississippi
$65 million0.50%$—
Entergy New Orleans$1 million1.625%$0.5 million
Entergy Texas$150 million1.250%$54.0 million

(a)As of June 30, 2025, letters of credit posted with MISO covered financial transmission rights exposure of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.6 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
(b)As of June 30, 2025, the letters of credit issued for Entergy Mississippi include $46.0 million in MISO letters of credit and $1.3 million in non-MISO letters of credit outstanding under this facility.
Schedule of Short-Term Debt [Table Text Block] The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2025 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
 AuthorizedBorrowings
 (In Millions)
Entergy Arkansas$250$—
Entergy Louisiana $450 $—
Entergy Mississippi$200$—
Entergy New Orleans$150$21
Entergy Texas$200$—
System Energy$200$—
Schedule of nuclear fuel company VIE credit facilities [Table Text Block] To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of June 30, 2025:
CompanyExpiration
Date 		Amount
of
Facility		Weighted-
 Average Interest
 Rate on
 Borrowings (a)		Amount
Outstanding as of
June 30, 2025
(Dollars in Millions)
Entergy Arkansas VIEJune 2027$805.44%$33.2
Entergy Louisiana River Bend VIEJune 2027$1055.42%$69.5
Entergy Louisiana Waterford VIEJune 2027$1055.43%$61.0
System Energy VIEJune 2027$1205.43%$44.3

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.
Schedule of nuclear fuel company VIE notes payable [Table Text Block]
The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of June 30, 2025 as follows:
CompanyDescriptionAmount
Entergy Arkansas VIE
1.84% Series N due July 2026
$90 million
Entergy Arkansas VIE
5.54% Series O due May 2029
$70 million
Entergy Louisiana River Bend VIE
2.51% Series V due June 2027
$70 million
Entergy Louisiana Waterford VIE
5.94% Series J due September 2026
$70 million
System Energy VIE
2.05% Series K due September 2027
$90 million
Schedule of Long-Term Debt Instruments [Table Text Block]
The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2025 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$29,929,838 $27,487,432 
Entergy Arkansas$5,438,033 $4,883,114 
Entergy Louisiana$10,399,823 $9,410,962 
Entergy Mississippi$3,020,687 $2,720,374 
Entergy New Orleans$737,560 $697,241 
Entergy Texas$4,038,417 $3,729,255 
System Energy$1,094,396 $1,101,434 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2024 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$27,991,595 $25,181,802 
Entergy Arkansas$5,122,494 $4,546,643 
Entergy Louisiana$9,866,453 $8,751,266 
Entergy Mississippi$2,427,073 $2,116,246 
Entergy New Orleans$735,467 $697,466 
Entergy Texas$3,552,443 $3,176,230 
System Energy$1,089,736 $1,063,946 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Louisiana [Member]  
Schedule of Line of Credit Facilities [Table Text Block]
Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2025 as follows:
CompanyExpiration
Date		Amount of
Facility		Interest Rate
(a)		Amount Drawn
as of
June 30, 2025		Letters of Credit
Outstanding as of
June 30, 2025
Entergy ArkansasApril 2026$25 million (b)6.28%$—$—
Entergy ArkansasJune 2030$300 million (c)5.55%$—$—
Entergy LouisianaJune 2030$400 million (c)5.68%$—$—
Entergy MississippiJune 2030$300 million (c)5.55%$—$—
Entergy New OrleansJune 2027$25 million (c)6.05%$—$—
Entergy TexasJune 2030$300 million (c)5.68%$—$1.1 million

(a)The interest rate is the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility.
(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.
(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $5 million for Entergy Mississippi; $10 million for Entergy New Orleans; and $25 million for Entergy Texas.
Schedule of uncommitted standby letter of credit facilities [Table Text Block] The following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2025:
CompanyAmount of
Uncommitted Facility		Letter of Credit Fee
Letters of Credit
Issued as of
June 30, 2025
(a)
Entergy Arkansas$25 million0.78%$23.6 million
Entergy Arkansas
$75 million0.50%$—
Entergy Louisiana$125 million 0.78%$74.3 million
Entergy Louisiana
$45 million 0.50%$—
Entergy Mississippi$65 million0.78%$47.3 million (b)
Entergy Mississippi
$65 million0.50%$—
Entergy New Orleans$1 million1.625%$0.5 million
Entergy Texas$150 million1.250%$54.0 million

(a)As of June 30, 2025, letters of credit posted with MISO covered financial transmission rights exposure of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.6 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
(b)As of June 30, 2025, the letters of credit issued for Entergy Mississippi include $46.0 million in MISO letters of credit and $1.3 million in non-MISO letters of credit outstanding under this facility.
Schedule of Short-Term Debt [Table Text Block] The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2025 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
 AuthorizedBorrowings
 (In Millions)
Entergy Arkansas$250$—
Entergy Louisiana $450 $—
Entergy Mississippi$200$—
Entergy New Orleans$150$21
Entergy Texas$200$—
System Energy$200$—
Schedule of nuclear fuel company VIE credit facilities [Table Text Block] To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of June 30, 2025:
CompanyExpiration
Date 		Amount
of
Facility		Weighted-
 Average Interest
 Rate on
 Borrowings (a)		Amount
Outstanding as of
June 30, 2025
(Dollars in Millions)
Entergy Arkansas VIEJune 2027$805.44%$33.2
Entergy Louisiana River Bend VIEJune 2027$1055.42%$69.5
Entergy Louisiana Waterford VIEJune 2027$1055.43%$61.0
System Energy VIEJune 2027$1205.43%$44.3

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.
Schedule of nuclear fuel company VIE notes payable [Table Text Block]
The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of June 30, 2025 as follows:
CompanyDescriptionAmount
Entergy Arkansas VIE
1.84% Series N due July 2026
$90 million
Entergy Arkansas VIE
5.54% Series O due May 2029
$70 million
Entergy Louisiana River Bend VIE
2.51% Series V due June 2027
$70 million
Entergy Louisiana Waterford VIE
5.94% Series J due September 2026
$70 million
System Energy VIE
2.05% Series K due September 2027
$90 million
Schedule of Long-Term Debt Instruments [Table Text Block]
The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2025 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$29,929,838 $27,487,432 
Entergy Arkansas$5,438,033 $4,883,114 
Entergy Louisiana$10,399,823 $9,410,962 
Entergy Mississippi$3,020,687 $2,720,374 
Entergy New Orleans$737,560 $697,241 
Entergy Texas$4,038,417 $3,729,255 
System Energy$1,094,396 $1,101,434 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2024 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$27,991,595 $25,181,802 
Entergy Arkansas$5,122,494 $4,546,643 
Entergy Louisiana$9,866,453 $8,751,266 
Entergy Mississippi$2,427,073 $2,116,246 
Entergy New Orleans$735,467 $697,466 
Entergy Texas$3,552,443 $3,176,230 
System Energy$1,089,736 $1,063,946 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Mississippi [Member]  
Schedule of Line of Credit Facilities [Table Text Block]
Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2025 as follows:
CompanyExpiration
Date		Amount of
Facility		Interest Rate
(a)		Amount Drawn
as of
June 30, 2025		Letters of Credit
Outstanding as of
June 30, 2025
Entergy ArkansasApril 2026$25 million (b)6.28%$—$—
Entergy ArkansasJune 2030$300 million (c)5.55%$—$—
Entergy LouisianaJune 2030$400 million (c)5.68%$—$—
Entergy MississippiJune 2030$300 million (c)5.55%$—$—
Entergy New OrleansJune 2027$25 million (c)6.05%$—$—
Entergy TexasJune 2030$300 million (c)5.68%$—$1.1 million

(a)The interest rate is the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility.
(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.
(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $5 million for Entergy Mississippi; $10 million for Entergy New Orleans; and $25 million for Entergy Texas.
Schedule of uncommitted standby letter of credit facilities [Table Text Block] The following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2025:
CompanyAmount of
Uncommitted Facility		Letter of Credit Fee
Letters of Credit
Issued as of
June 30, 2025
(a)
Entergy Arkansas$25 million0.78%$23.6 million
Entergy Arkansas
$75 million0.50%$—
Entergy Louisiana$125 million 0.78%$74.3 million
Entergy Louisiana
$45 million 0.50%$—
Entergy Mississippi$65 million0.78%$47.3 million (b)
Entergy Mississippi
$65 million0.50%$—
Entergy New Orleans$1 million1.625%$0.5 million
Entergy Texas$150 million1.250%$54.0 million

(a)As of June 30, 2025, letters of credit posted with MISO covered financial transmission rights exposure of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.6 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
(b)As of June 30, 2025, the letters of credit issued for Entergy Mississippi include $46.0 million in MISO letters of credit and $1.3 million in non-MISO letters of credit outstanding under this facility.
Schedule of Short-Term Debt [Table Text Block] The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2025 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
 AuthorizedBorrowings
 (In Millions)
Entergy Arkansas$250$—
Entergy Louisiana $450 $—
Entergy Mississippi$200$—
Entergy New Orleans$150$21
Entergy Texas$200$—
System Energy$200$—
Schedule of Long-Term Debt Instruments [Table Text Block]
The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2025 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$29,929,838 $27,487,432 
Entergy Arkansas$5,438,033 $4,883,114 
Entergy Louisiana$10,399,823 $9,410,962 
Entergy Mississippi$3,020,687 $2,720,374 
Entergy New Orleans$737,560 $697,241 
Entergy Texas$4,038,417 $3,729,255 
System Energy$1,094,396 $1,101,434 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2024 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$27,991,595 $25,181,802 
Entergy Arkansas$5,122,494 $4,546,643 
Entergy Louisiana$9,866,453 $8,751,266 
Entergy Mississippi$2,427,073 $2,116,246 
Entergy New Orleans$735,467 $697,466 
Entergy Texas$3,552,443 $3,176,230 
System Energy$1,089,736 $1,063,946 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy New Orleans [Member]  
Schedule of Line of Credit Facilities [Table Text Block]
Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2025 as follows:
CompanyExpiration
Date		Amount of
Facility		Interest Rate
(a)		Amount Drawn
as of
June 30, 2025		Letters of Credit
Outstanding as of
June 30, 2025
Entergy ArkansasApril 2026$25 million (b)6.28%$—$—
Entergy ArkansasJune 2030$300 million (c)5.55%$—$—
Entergy LouisianaJune 2030$400 million (c)5.68%$—$—
Entergy MississippiJune 2030$300 million (c)5.55%$—$—
Entergy New OrleansJune 2027$25 million (c)6.05%$—$—
Entergy TexasJune 2030$300 million (c)5.68%$—$1.1 million

(a)The interest rate is the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility.
(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.
(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $5 million for Entergy Mississippi; $10 million for Entergy New Orleans; and $25 million for Entergy Texas.
Schedule of uncommitted standby letter of credit facilities [Table Text Block] The following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2025:
CompanyAmount of
Uncommitted Facility		Letter of Credit Fee
Letters of Credit
Issued as of
June 30, 2025
(a)
Entergy Arkansas$25 million0.78%$23.6 million
Entergy Arkansas
$75 million0.50%$—
Entergy Louisiana$125 million 0.78%$74.3 million
Entergy Louisiana
$45 million 0.50%$—
Entergy Mississippi$65 million0.78%$47.3 million (b)
Entergy Mississippi
$65 million0.50%$—
Entergy New Orleans$1 million1.625%$0.5 million
Entergy Texas$150 million1.250%$54.0 million

(a)As of June 30, 2025, letters of credit posted with MISO covered financial transmission rights exposure of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.6 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
(b)As of June 30, 2025, the letters of credit issued for Entergy Mississippi include $46.0 million in MISO letters of credit and $1.3 million in non-MISO letters of credit outstanding under this facility.
Schedule of Short-Term Debt [Table Text Block] The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2025 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
 AuthorizedBorrowings
 (In Millions)
Entergy Arkansas$250$—
Entergy Louisiana $450 $—
Entergy Mississippi$200$—
Entergy New Orleans$150$21
Entergy Texas$200$—
System Energy$200$—
Schedule of Long-Term Debt Instruments [Table Text Block]
The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2025 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$29,929,838 $27,487,432 
Entergy Arkansas$5,438,033 $4,883,114 
Entergy Louisiana$10,399,823 $9,410,962 
Entergy Mississippi$3,020,687 $2,720,374 
Entergy New Orleans$737,560 $697,241 
Entergy Texas$4,038,417 $3,729,255 
System Energy$1,094,396 $1,101,434 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2024 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$27,991,595 $25,181,802 
Entergy Arkansas$5,122,494 $4,546,643 
Entergy Louisiana$9,866,453 $8,751,266 
Entergy Mississippi$2,427,073 $2,116,246 
Entergy New Orleans$735,467 $697,466 
Entergy Texas$3,552,443 $3,176,230 
System Energy$1,089,736 $1,063,946 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
Entergy Texas [Member]  
Schedule of Line of Credit Facilities [Table Text Block]
Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of June 30, 2025 as follows:
CompanyExpiration
Date		Amount of
Facility		Interest Rate
(a)		Amount Drawn
as of
June 30, 2025		Letters of Credit
Outstanding as of
June 30, 2025
Entergy ArkansasApril 2026$25 million (b)6.28%$—$—
Entergy ArkansasJune 2030$300 million (c)5.55%$—$—
Entergy LouisianaJune 2030$400 million (c)5.68%$—$—
Entergy MississippiJune 2030$300 million (c)5.55%$—$—
Entergy New OrleansJune 2027$25 million (c)6.05%$—$—
Entergy TexasJune 2030$300 million (c)5.68%$—$1.1 million

(a)The interest rate is the estimated interest rate as of June 30, 2025 that would have been applied to outstanding borrowings under the facility.
(b)Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.
(c)The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $5 million for Entergy Mississippi; $10 million for Entergy New Orleans; and $25 million for Entergy Texas.
Schedule of uncommitted standby letter of credit facilities [Table Text Block] The following is a summary of the uncommitted standby letter of credit facilities as of June 30, 2025:
CompanyAmount of
Uncommitted Facility		Letter of Credit Fee
Letters of Credit
Issued as of
June 30, 2025
(a)
Entergy Arkansas$25 million0.78%$23.6 million
Entergy Arkansas
$75 million0.50%$—
Entergy Louisiana$125 million 0.78%$74.3 million
Entergy Louisiana
$45 million 0.50%$—
Entergy Mississippi$65 million0.78%$47.3 million (b)
Entergy Mississippi
$65 million0.50%$—
Entergy New Orleans$1 million1.625%$0.5 million
Entergy Texas$150 million1.250%$54.0 million

(a)As of June 30, 2025, letters of credit posted with MISO covered financial transmission rights exposure of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi, and $0.6 million for Entergy Texas. See Note 8 to the financial statements herein for discussion of financial transmission rights.
(b)As of June 30, 2025, the letters of credit issued for Entergy Mississippi include $46.0 million in MISO letters of credit and $1.3 million in non-MISO letters of credit outstanding under this facility.
Schedule of Short-Term Debt [Table Text Block] The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2025 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
 AuthorizedBorrowings
 (In Millions)
Entergy Arkansas$250$—
Entergy Louisiana $450 $—
Entergy Mississippi$200$—
Entergy New Orleans$150$21
Entergy Texas$200$—
System Energy$200$—
Schedule of Long-Term Debt Instruments [Table Text Block]
The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2025 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$29,929,838 $27,487,432 
Entergy Arkansas$5,438,033 $4,883,114 
Entergy Louisiana$10,399,823 $9,410,962 
Entergy Mississippi$3,020,687 $2,720,374 
Entergy New Orleans$737,560 $697,241 
Entergy Texas$4,038,417 $3,729,255 
System Energy$1,094,396 $1,101,434 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2024 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$27,991,595 $25,181,802 
Entergy Arkansas$5,122,494 $4,546,643 
Entergy Louisiana$9,866,453 $8,751,266 
Entergy Mississippi$2,427,073 $2,116,246 
Entergy New Orleans$735,467 $697,466 
Entergy Texas$3,552,443 $3,176,230 
System Energy$1,089,736 $1,063,946 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
System Energy [Member]  
Schedule of Short-Term Debt [Table Text Block] The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of June 30, 2025 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
 AuthorizedBorrowings
 (In Millions)
Entergy Arkansas$250$—
Entergy Louisiana $450 $—
Entergy Mississippi$200$—
Entergy New Orleans$150$21
Entergy Texas$200$—
System Energy$200$—
Schedule of nuclear fuel company VIE credit facilities [Table Text Block] To finance the acquisition and ownership of nuclear fuel, the nuclear fuel company VIEs have credit facilities and three of the four VIEs also issue commercial paper, details of which follow as of June 30, 2025:
CompanyExpiration
Date 		Amount
of
Facility		Weighted-
 Average Interest
 Rate on
 Borrowings (a)		Amount
Outstanding as of
June 30, 2025
(Dollars in Millions)
Entergy Arkansas VIEJune 2027$805.44%$33.2
Entergy Louisiana River Bend VIEJune 2027$1055.42%$69.5
Entergy Louisiana Waterford VIEJune 2027$1055.43%$61.0
System Energy VIEJune 2027$1205.43%$44.3

(a)Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company VIEs for Entergy Arkansas, Entergy Louisiana, and System Energy. The nuclear fuel company VIE for Entergy Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.
Schedule of nuclear fuel company VIE notes payable [Table Text Block]
The nuclear fuel company VIEs had notes payable that were included in debt on the respective balance sheets as of June 30, 2025 as follows:
CompanyDescriptionAmount
Entergy Arkansas VIE
1.84% Series N due July 2026
$90 million
Entergy Arkansas VIE
5.54% Series O due May 2029
$70 million
Entergy Louisiana River Bend VIE
2.51% Series V due June 2027
$70 million
Entergy Louisiana Waterford VIE
5.94% Series J due September 2026
$70 million
System Energy VIE
2.05% Series K due September 2027
$90 million
Schedule of Long-Term Debt Instruments [Table Text Block]
The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of June 30, 2025 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$29,929,838 $27,487,432 
Entergy Arkansas$5,438,033 $4,883,114 
Entergy Louisiana$10,399,823 $9,410,962 
Entergy Mississippi$3,020,687 $2,720,374 
Entergy New Orleans$737,560 $697,241 
Entergy Texas$4,038,417 $3,729,255 
System Energy$1,094,396 $1,101,434 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.

The book value and the fair value of long-term debt for Entergy and the Registrant Subsidiaries as of December 31, 2024 were as follows:
Book Value
of Long-Term Debt		Fair Value
of Long-Term Debt (a)
(In Thousands)
Entergy$27,991,595 $25,181,802 
Entergy Arkansas$5,122,494 $4,546,643 
Entergy Louisiana$9,866,453 $8,751,266 
Entergy Mississippi$2,427,073 $2,116,246 
Entergy New Orleans$735,467 $697,466 
Entergy Texas$3,552,443 $3,176,230 
System Energy$1,089,736 $1,063,946 

(a)Fair values were classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements herein.
v3.25.2
Stock-Based Compensation (Tables)
 6 Months Ended
Jun. 30, 2025
Employee Stock Option  
Share-Based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]  
Share-Based Payment Arrangement, Expensed and Capitalized, Amount [Table Text Block]
The following table includes financial information for stock options for the three months ended June 30, 2025 and 2024:
20252024
(In Millions)
Compensation expense included in Entergy’s consolidated net income$1.0 $1.1 
Tax benefit recognized in Entergy’s consolidated net income$0.2 $0.3 
Compensation cost capitalized as part of fixed assets and materials and supplies$0.5 $0.5 

The following table includes financial information for stock options for the six months ended June 30, 2025 and 2024:
20252024
(In Millions)
Compensation expense included in Entergy’s consolidated net income$2.1 $2.2 
Tax benefit recognized in Entergy’s consolidated net income$0.5 $0.6 
Compensation cost capitalized as part of fixed assets and materials and supplies$1.0 $1.0 
Other Equity Awards [Member]  
Share-Based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]  
Share-Based Payment Arrangement, Expensed and Capitalized, Amount [Table Text Block]
The following table includes financial information for other outstanding equity awards for the three months ended June 30, 2025 and 2024:
20252024
(In Millions)
Compensation expense included in Entergy’s consolidated net income$9.4 $9.8 
Tax benefit recognized in Entergy’s consolidated net income$2.3 $2.5 
Compensation cost capitalized as part of fixed assets and materials and supplies$4.7 $4.6 

The following table includes financial information for other equity awards for the six months ended June 30, 2025 and 2024:
20252024
(In Millions)
Compensation expense included in Entergy’s consolidated net income$19.4 $19.7 
Tax benefit recognized in Entergy’s consolidated net income$4.8 $5.0 
Compensation cost capitalized as part of fixed assets and materials and supplies$9.5 $9.1 
v3.25.2
Retirement And Other Postretirement Benefits (Tables)
 6 Months Ended
Jun. 30, 2025
Defined Benefit Plan Disclosure [Line Items]  
Schedule of reclassifications out of accumulated other comprehensive income [Table Text Block]
Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2025 and 2024:
2025Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $3,493 ($31)$3,462 
Amortization of net gain (loss)(411)3,070 (108)2,551 
($411)$6,563 ($139)$6,013 
Entergy Louisiana
Amortization of prior service credit$— $1,136 $— $1,136 
Amortization of net gain (loss)(91)1,811 (1)1,719 
($91)$2,947 ($1)$2,855 

2024Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $3,513 ($40)$3,473 
Amortization of net gain (loss)(894)2,615 (80)1,641 
Settlement loss(316,974)— — (316,974)
($317,868)$6,128 ($120)($311,860)
Entergy Louisiana
Amortization of prior service credit$— $1,136 $— $1,136 
Amortization of net gain (loss)(104)1,738 (2)1,632 
($104)$2,874 ($2)$2,768 
Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2025 and 2024:
2025Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $6,986 ($62)$6,924 
Amortization of net gain (loss)(822)6,140 (216)5,102 
($822)$13,126 ($278)$12,026 
Entergy Louisiana
Amortization of prior service credit$— $2,272 $— $2,272 
Amortization of net gain (loss)(182)3,622 (2)3,438 
($182)$5,894 ($2)$5,710 

2024Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $7,026 ($80)$6,946 
Amortization of net gain (loss)(2,033)5,230 (160)3,037 
Settlement loss(316,974)— — (316,974)
($319,007)$12,256 ($240)($306,991)
Entergy Louisiana
Amortization of prior service credit$— $2,272 $— $2,272 
Amortization of net gain (loss)(208)3,476 (2)3,266 
($208)$5,748 ($2)$5,538 
Pension Plan [Member] | Qualified Plan  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
Entergy’s qualified pension costs, including amounts capitalized, for the second quarters of 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$23,617 $23,370 
Interest cost on projected benefit obligation59,680 65,961 
Expected return on assets(75,280)(89,506)
Recognized net loss13,309 14,854 
Settlement charges— 325,253 
Net pension cost$21,326 $339,932 
Entergy’s qualified pension costs, including amounts capitalized, for the six months ended June 30, 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$47,234 $46,746 
Interest cost on projected benefit obligation119,360 136,587 
Expected return on assets(150,560)(185,486)
Recognized net loss26,618 29,974 
Settlement charges— 325,253 
Net pension cost$42,652 $353,074 
Other Postretirement Benefits Plan [Member]  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
Entergy’s other postretirement benefits income, including amounts capitalized, for the second quarters of 2025 and 2024, included the following components:
20252024
(In Thousands)
Service cost - benefits earned during the period$2,757 $3,126 
Interest cost on accumulated postretirement benefit obligation (APBO)9,690 9,852 
Expected return on assets(10,209)(10,569)
Amortization of prior service credit(5,720)(5,720)
Recognized net gain(3,870)(2,761)
Net other postretirement benefits income($7,352)($6,072)

Entergy’s other postretirement benefits income, including amounts capitalized, for the six months ended June 30, 2025 and 2024, included the following components:
 20252024
 (In Thousands)
Service cost - benefits earned during the period$5,514 $6,252 
Interest cost on APBO
19,380 19,704 
Expected return on assets(20,418)(21,138)
Amortization of prior service credit(11,440)(11,440)
Recognized net gain(7,740)(5,522)
Net other postretirement benefits income($14,704)($12,144)
Entergy Arkansas [Member] | Pension Plan [Member] | Qualified Plan  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,427 $5,454 $1,304 $411 $1,024 $1,372 
Interest cost on projected benefit obligation13,814 14,704 3,699 1,647 2,973 3,585 
Expected return on assets(17,676)(18,897)(4,949)(2,174)(3,889)(4,575)
Recognized net loss4,791 2,268 822 415 454 1,114 
Net pension cost$5,356 $3,529 $876 $299 $562 $1,496 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,100 $5,551 $1,284 $440 $962 $1,383 
Interest cost on projected benefit obligation13,217 13,961 3,521 1,569 2,831 3,386 
Expected return on assets(18,155)(19,447)(5,113)(2,203)(4,077)(4,633)
Recognized net loss5,746 2,602 1,140 470 393 1,162 
Settlement charges— — — — — 611 
Net pension cost$4,908 $2,667 $832 $276 $109 $1,909 
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,854 $10,908 $2,608 $822 $2,048 $2,744 
Interest cost on projected benefit obligation27,628 29,408 7,398 3,294 5,946 7,170 
Expected return on assets(35,352)(37,794)(9,898)(4,348)(7,778)(9,150)
Recognized net loss9,582 4,536 1,644 830 908 2,228 
Net pension cost$10,712 $7,058 $1,752 $598 $1,124 $2,992 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,199 $11,102 $2,568 $880 $1,923 $2,767 
Interest cost on projected benefit obligation26,434 27,922 7,042 3,138 5,662 6,777 
Expected return on assets(36,310)(38,894)(10,226)(4,407)(8,154)(9,281)
Recognized net loss11,492 5,204 2,280 940 786 2,327 
Settlement charges— — — — — 611 
Net pension cost$9,815 $5,334 $1,664 $551 $217 $3,201 
Schedule of Expected Benefit Payments [Table Text Block] Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2025:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Expected 2025 pension contributions$35,544 $41,253 $8,064 $5,016 $7,725 $15,668 
Pension contributions made through June 2025$16,968 $17,448 $3,951 $2,112 $3,240 $6,413 
Remaining estimated pension contributions to be made in 2025$18,576 $23,805 $4,113 $2,904 $4,485 $9,255 
Entergy Arkansas [Member] | Pension Plan [Member] | Nonqualified Plan  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for second quarters of 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$47 $36 $90 $35 $39 
2024$68 $51 $83 $31 $62 
The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$94 $72 $180 $70 $78 
2024$136 $102 $166 $61 $124 
Entergy Arkansas [Member] | Other Postretirement Benefits Plan [Member]  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$572 $671 $162 $52 $159 $174 
Interest cost on APBO1,775 2,012 489 249 582 394 
Expected return on assets(4,225)— (1,328)(1,445)(2,452)(702)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss(353)(1,811)(57)(27)153 (7)
Net other postretirement benefits income($1,707)($264)($973)($1,400)($2,651)($214)

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$642 $700 $184 $51 $168 $175 
Interest cost on APBO1,833 1,999 486 253 603 398 
Expected return on assets(4,384)— (1,372)(1,479)(2,539)(728)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss— (1,738)15 19 148 — 
Net other postretirement benefits income($1,385)($175)($926)($1,385)($2,713)($228)

The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,144 $1,342 $324 $104 $318 $348 
Interest cost on APBO3,550 4,024 978 498 1,164 788 
Expected return on assets(8,450)— (2,656)(2,890)(4,904)(1,404)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss(706)(3,622)(114)(54)306 (14)
Net other postretirement benefits income($3,414)($528)($1,946)($2,800)($5,302)($428)
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,284 $1,400 $368 $102 $336 $350 
Interest cost on APBO3,666 3,998 972 506 1,206 796 
Expected return on assets(8,768)— (2,744)(2,958)(5,078)(1,456)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss— (3,476)30 38 296 — 
Net other postretirement benefits income($2,770)($350)($1,852)($2,770)($5,426)($456)
Entergy Louisiana [Member]  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of reclassifications out of accumulated other comprehensive income [Table Text Block]
Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the second quarters of 2025 and 2024:
2025Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $3,493 ($31)$3,462 
Amortization of net gain (loss)(411)3,070 (108)2,551 
($411)$6,563 ($139)$6,013 
Entergy Louisiana
Amortization of prior service credit$— $1,136 $— $1,136 
Amortization of net gain (loss)(91)1,811 (1)1,719 
($91)$2,947 ($1)$2,855 

2024Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $3,513 ($40)$3,473 
Amortization of net gain (loss)(894)2,615 (80)1,641 
Settlement loss(316,974)— — (316,974)
($317,868)$6,128 ($120)($311,860)
Entergy Louisiana
Amortization of prior service credit$— $1,136 $— $1,136 
Amortization of net gain (loss)(104)1,738 (2)1,632 
($104)$2,874 ($2)$2,768 
Entergy and Entergy Louisiana reclassified the following costs out of accumulated other comprehensive income (loss) (before taxes and including amounts capitalized) for the six months ended June 30, 2025 and 2024:
2025Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $6,986 ($62)$6,924 
Amortization of net gain (loss)(822)6,140 (216)5,102 
($822)$13,126 ($278)$12,026 
Entergy Louisiana
Amortization of prior service credit$— $2,272 $— $2,272 
Amortization of net gain (loss)(182)3,622 (2)3,438 
($182)$5,894 ($2)$5,710 

2024Qualified
Pension
Costs		Other
Postretirement
Costs		Non-Qualified
Pension Costs		Total
(In Thousands)
Entergy
Amortization of prior service credit (cost)$— $7,026 ($80)$6,946 
Amortization of net gain (loss)(2,033)5,230 (160)3,037 
Settlement loss(316,974)— — (316,974)
($319,007)$12,256 ($240)($306,991)
Entergy Louisiana
Amortization of prior service credit$— $2,272 $— $2,272 
Amortization of net gain (loss)(208)3,476 (2)3,266 
($208)$5,748 ($2)$5,538 
Entergy Louisiana [Member] | Pension Plan [Member] | Qualified Plan  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,427 $5,454 $1,304 $411 $1,024 $1,372 
Interest cost on projected benefit obligation13,814 14,704 3,699 1,647 2,973 3,585 
Expected return on assets(17,676)(18,897)(4,949)(2,174)(3,889)(4,575)
Recognized net loss4,791 2,268 822 415 454 1,114 
Net pension cost$5,356 $3,529 $876 $299 $562 $1,496 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,100 $5,551 $1,284 $440 $962 $1,383 
Interest cost on projected benefit obligation13,217 13,961 3,521 1,569 2,831 3,386 
Expected return on assets(18,155)(19,447)(5,113)(2,203)(4,077)(4,633)
Recognized net loss5,746 2,602 1,140 470 393 1,162 
Settlement charges— — — — — 611 
Net pension cost$4,908 $2,667 $832 $276 $109 $1,909 
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,854 $10,908 $2,608 $822 $2,048 $2,744 
Interest cost on projected benefit obligation27,628 29,408 7,398 3,294 5,946 7,170 
Expected return on assets(35,352)(37,794)(9,898)(4,348)(7,778)(9,150)
Recognized net loss9,582 4,536 1,644 830 908 2,228 
Net pension cost$10,712 $7,058 $1,752 $598 $1,124 $2,992 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,199 $11,102 $2,568 $880 $1,923 $2,767 
Interest cost on projected benefit obligation26,434 27,922 7,042 3,138 5,662 6,777 
Expected return on assets(36,310)(38,894)(10,226)(4,407)(8,154)(9,281)
Recognized net loss11,492 5,204 2,280 940 786 2,327 
Settlement charges— — — — — 611 
Net pension cost$9,815 $5,334 $1,664 $551 $217 $3,201 
Schedule of Expected Benefit Payments [Table Text Block] Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2025:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Expected 2025 pension contributions$35,544 $41,253 $8,064 $5,016 $7,725 $15,668 
Pension contributions made through June 2025$16,968 $17,448 $3,951 $2,112 $3,240 $6,413 
Remaining estimated pension contributions to be made in 2025$18,576 $23,805 $4,113 $2,904 $4,485 $9,255 
Entergy Louisiana [Member] | Pension Plan [Member] | Nonqualified Plan  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for second quarters of 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$47 $36 $90 $35 $39 
2024$68 $51 $83 $31 $62 
The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$94 $72 $180 $70 $78 
2024$136 $102 $166 $61 $124 
Entergy Louisiana [Member] | Other Postretirement Benefits Plan [Member]  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$572 $671 $162 $52 $159 $174 
Interest cost on APBO1,775 2,012 489 249 582 394 
Expected return on assets(4,225)— (1,328)(1,445)(2,452)(702)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss(353)(1,811)(57)(27)153 (7)
Net other postretirement benefits income($1,707)($264)($973)($1,400)($2,651)($214)

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$642 $700 $184 $51 $168 $175 
Interest cost on APBO1,833 1,999 486 253 603 398 
Expected return on assets(4,384)— (1,372)(1,479)(2,539)(728)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss— (1,738)15 19 148 — 
Net other postretirement benefits income($1,385)($175)($926)($1,385)($2,713)($228)

The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,144 $1,342 $324 $104 $318 $348 
Interest cost on APBO3,550 4,024 978 498 1,164 788 
Expected return on assets(8,450)— (2,656)(2,890)(4,904)(1,404)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss(706)(3,622)(114)(54)306 (14)
Net other postretirement benefits income($3,414)($528)($1,946)($2,800)($5,302)($428)
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,284 $1,400 $368 $102 $336 $350 
Interest cost on APBO3,666 3,998 972 506 1,206 796 
Expected return on assets(8,768)— (2,744)(2,958)(5,078)(1,456)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss— (3,476)30 38 296 — 
Net other postretirement benefits income($2,770)($350)($1,852)($2,770)($5,426)($456)
Entergy Mississippi [Member] | Pension Plan [Member] | Qualified Plan  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,427 $5,454 $1,304 $411 $1,024 $1,372 
Interest cost on projected benefit obligation13,814 14,704 3,699 1,647 2,973 3,585 
Expected return on assets(17,676)(18,897)(4,949)(2,174)(3,889)(4,575)
Recognized net loss4,791 2,268 822 415 454 1,114 
Net pension cost$5,356 $3,529 $876 $299 $562 $1,496 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,100 $5,551 $1,284 $440 $962 $1,383 
Interest cost on projected benefit obligation13,217 13,961 3,521 1,569 2,831 3,386 
Expected return on assets(18,155)(19,447)(5,113)(2,203)(4,077)(4,633)
Recognized net loss5,746 2,602 1,140 470 393 1,162 
Settlement charges— — — — — 611 
Net pension cost$4,908 $2,667 $832 $276 $109 $1,909 
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,854 $10,908 $2,608 $822 $2,048 $2,744 
Interest cost on projected benefit obligation27,628 29,408 7,398 3,294 5,946 7,170 
Expected return on assets(35,352)(37,794)(9,898)(4,348)(7,778)(9,150)
Recognized net loss9,582 4,536 1,644 830 908 2,228 
Net pension cost$10,712 $7,058 $1,752 $598 $1,124 $2,992 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,199 $11,102 $2,568 $880 $1,923 $2,767 
Interest cost on projected benefit obligation26,434 27,922 7,042 3,138 5,662 6,777 
Expected return on assets(36,310)(38,894)(10,226)(4,407)(8,154)(9,281)
Recognized net loss11,492 5,204 2,280 940 786 2,327 
Settlement charges— — — — — 611 
Net pension cost$9,815 $5,334 $1,664 $551 $217 $3,201 
Schedule of Expected Benefit Payments [Table Text Block] Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2025:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Expected 2025 pension contributions$35,544 $41,253 $8,064 $5,016 $7,725 $15,668 
Pension contributions made through June 2025$16,968 $17,448 $3,951 $2,112 $3,240 $6,413 
Remaining estimated pension contributions to be made in 2025$18,576 $23,805 $4,113 $2,904 $4,485 $9,255 
Entergy Mississippi [Member] | Pension Plan [Member] | Nonqualified Plan  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for second quarters of 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$47 $36 $90 $35 $39 
2024$68 $51 $83 $31 $62 
The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$94 $72 $180 $70 $78 
2024$136 $102 $166 $61 $124 
Entergy Mississippi [Member] | Other Postretirement Benefits Plan [Member]  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$572 $671 $162 $52 $159 $174 
Interest cost on APBO1,775 2,012 489 249 582 394 
Expected return on assets(4,225)— (1,328)(1,445)(2,452)(702)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss(353)(1,811)(57)(27)153 (7)
Net other postretirement benefits income($1,707)($264)($973)($1,400)($2,651)($214)

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$642 $700 $184 $51 $168 $175 
Interest cost on APBO1,833 1,999 486 253 603 398 
Expected return on assets(4,384)— (1,372)(1,479)(2,539)(728)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss— (1,738)15 19 148 — 
Net other postretirement benefits income($1,385)($175)($926)($1,385)($2,713)($228)

The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,144 $1,342 $324 $104 $318 $348 
Interest cost on APBO3,550 4,024 978 498 1,164 788 
Expected return on assets(8,450)— (2,656)(2,890)(4,904)(1,404)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss(706)(3,622)(114)(54)306 (14)
Net other postretirement benefits income($3,414)($528)($1,946)($2,800)($5,302)($428)
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,284 $1,400 $368 $102 $336 $350 
Interest cost on APBO3,666 3,998 972 506 1,206 796 
Expected return on assets(8,768)— (2,744)(2,958)(5,078)(1,456)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss— (3,476)30 38 296 — 
Net other postretirement benefits income($2,770)($350)($1,852)($2,770)($5,426)($456)
Entergy New Orleans [Member] | Pension Plan [Member] | Qualified Plan  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,427 $5,454 $1,304 $411 $1,024 $1,372 
Interest cost on projected benefit obligation13,814 14,704 3,699 1,647 2,973 3,585 
Expected return on assets(17,676)(18,897)(4,949)(2,174)(3,889)(4,575)
Recognized net loss4,791 2,268 822 415 454 1,114 
Net pension cost$5,356 $3,529 $876 $299 $562 $1,496 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,100 $5,551 $1,284 $440 $962 $1,383 
Interest cost on projected benefit obligation13,217 13,961 3,521 1,569 2,831 3,386 
Expected return on assets(18,155)(19,447)(5,113)(2,203)(4,077)(4,633)
Recognized net loss5,746 2,602 1,140 470 393 1,162 
Settlement charges— — — — — 611 
Net pension cost$4,908 $2,667 $832 $276 $109 $1,909 
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,854 $10,908 $2,608 $822 $2,048 $2,744 
Interest cost on projected benefit obligation27,628 29,408 7,398 3,294 5,946 7,170 
Expected return on assets(35,352)(37,794)(9,898)(4,348)(7,778)(9,150)
Recognized net loss9,582 4,536 1,644 830 908 2,228 
Net pension cost$10,712 $7,058 $1,752 $598 $1,124 $2,992 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,199 $11,102 $2,568 $880 $1,923 $2,767 
Interest cost on projected benefit obligation26,434 27,922 7,042 3,138 5,662 6,777 
Expected return on assets(36,310)(38,894)(10,226)(4,407)(8,154)(9,281)
Recognized net loss11,492 5,204 2,280 940 786 2,327 
Settlement charges— — — — — 611 
Net pension cost$9,815 $5,334 $1,664 $551 $217 $3,201 
Schedule of Expected Benefit Payments [Table Text Block] Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2025:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Expected 2025 pension contributions$35,544 $41,253 $8,064 $5,016 $7,725 $15,668 
Pension contributions made through June 2025$16,968 $17,448 $3,951 $2,112 $3,240 $6,413 
Remaining estimated pension contributions to be made in 2025$18,576 $23,805 $4,113 $2,904 $4,485 $9,255 
Entergy New Orleans [Member] | Pension Plan [Member] | Nonqualified Plan  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for second quarters of 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$47 $36 $90 $35 $39 
2024$68 $51 $83 $31 $62 
The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$94 $72 $180 $70 $78 
2024$136 $102 $166 $61 $124 
Entergy New Orleans [Member] | Other Postretirement Benefits Plan [Member]  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$572 $671 $162 $52 $159 $174 
Interest cost on APBO1,775 2,012 489 249 582 394 
Expected return on assets(4,225)— (1,328)(1,445)(2,452)(702)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss(353)(1,811)(57)(27)153 (7)
Net other postretirement benefits income($1,707)($264)($973)($1,400)($2,651)($214)

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$642 $700 $184 $51 $168 $175 
Interest cost on APBO1,833 1,999 486 253 603 398 
Expected return on assets(4,384)— (1,372)(1,479)(2,539)(728)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss— (1,738)15 19 148 — 
Net other postretirement benefits income($1,385)($175)($926)($1,385)($2,713)($228)

The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,144 $1,342 $324 $104 $318 $348 
Interest cost on APBO3,550 4,024 978 498 1,164 788 
Expected return on assets(8,450)— (2,656)(2,890)(4,904)(1,404)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss(706)(3,622)(114)(54)306 (14)
Net other postretirement benefits income($3,414)($528)($1,946)($2,800)($5,302)($428)
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,284 $1,400 $368 $102 $336 $350 
Interest cost on APBO3,666 3,998 972 506 1,206 796 
Expected return on assets(8,768)— (2,744)(2,958)(5,078)(1,456)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss— (3,476)30 38 296 — 
Net other postretirement benefits income($2,770)($350)($1,852)($2,770)($5,426)($456)
Entergy Texas [Member] | Pension Plan [Member] | Qualified Plan  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,427 $5,454 $1,304 $411 $1,024 $1,372 
Interest cost on projected benefit obligation13,814 14,704 3,699 1,647 2,973 3,585 
Expected return on assets(17,676)(18,897)(4,949)(2,174)(3,889)(4,575)
Recognized net loss4,791 2,268 822 415 454 1,114 
Net pension cost$5,356 $3,529 $876 $299 $562 $1,496 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,100 $5,551 $1,284 $440 $962 $1,383 
Interest cost on projected benefit obligation13,217 13,961 3,521 1,569 2,831 3,386 
Expected return on assets(18,155)(19,447)(5,113)(2,203)(4,077)(4,633)
Recognized net loss5,746 2,602 1,140 470 393 1,162 
Settlement charges— — — — — 611 
Net pension cost$4,908 $2,667 $832 $276 $109 $1,909 
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,854 $10,908 $2,608 $822 $2,048 $2,744 
Interest cost on projected benefit obligation27,628 29,408 7,398 3,294 5,946 7,170 
Expected return on assets(35,352)(37,794)(9,898)(4,348)(7,778)(9,150)
Recognized net loss9,582 4,536 1,644 830 908 2,228 
Net pension cost$10,712 $7,058 $1,752 $598 $1,124 $2,992 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,199 $11,102 $2,568 $880 $1,923 $2,767 
Interest cost on projected benefit obligation26,434 27,922 7,042 3,138 5,662 6,777 
Expected return on assets(36,310)(38,894)(10,226)(4,407)(8,154)(9,281)
Recognized net loss11,492 5,204 2,280 940 786 2,327 
Settlement charges— — — — — 611 
Net pension cost$9,815 $5,334 $1,664 $551 $217 $3,201 
Schedule of Expected Benefit Payments [Table Text Block] Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2025:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Expected 2025 pension contributions$35,544 $41,253 $8,064 $5,016 $7,725 $15,668 
Pension contributions made through June 2025$16,968 $17,448 $3,951 $2,112 $3,240 $6,413 
Remaining estimated pension contributions to be made in 2025$18,576 $23,805 $4,113 $2,904 $4,485 $9,255 
Entergy Texas [Member] | Pension Plan [Member] | Nonqualified Plan  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for second quarters of 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$47 $36 $90 $35 $39 
2024$68 $51 $83 $31 $62 
The Registrant Subsidiaries recognized the following pension cost for their current and former employees for their non-qualified pension plans for the six months ended June 30, 2025 and 2024:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas
(In Thousands)
2025$94 $72 $180 $70 $78 
2024$136 $102 $166 $61 $124 
Entergy Texas [Member] | Other Postretirement Benefits Plan [Member]  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$572 $671 $162 $52 $159 $174 
Interest cost on APBO1,775 2,012 489 249 582 394 
Expected return on assets(4,225)— (1,328)(1,445)(2,452)(702)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss(353)(1,811)(57)(27)153 (7)
Net other postretirement benefits income($1,707)($264)($973)($1,400)($2,651)($214)

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$642 $700 $184 $51 $168 $175 
Interest cost on APBO1,833 1,999 486 253 603 398 
Expected return on assets(4,384)— (1,372)(1,479)(2,539)(728)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss— (1,738)15 19 148 — 
Net other postretirement benefits income($1,385)($175)($926)($1,385)($2,713)($228)

The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,144 $1,342 $324 $104 $318 $348 
Interest cost on APBO3,550 4,024 978 498 1,164 788 
Expected return on assets(8,450)— (2,656)(2,890)(4,904)(1,404)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss(706)(3,622)(114)(54)306 (14)
Net other postretirement benefits income($3,414)($528)($1,946)($2,800)($5,302)($428)
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,284 $1,400 $368 $102 $336 $350 
Interest cost on APBO3,666 3,998 972 506 1,206 796 
Expected return on assets(8,768)— (2,744)(2,958)(5,078)(1,456)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss— (3,476)30 38 296 — 
Net other postretirement benefits income($2,770)($350)($1,852)($2,770)($5,426)($456)
System Energy [Member] | Pension Plan [Member] | Qualified Plan  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,427 $5,454 $1,304 $411 $1,024 $1,372 
Interest cost on projected benefit obligation13,814 14,704 3,699 1,647 2,973 3,585 
Expected return on assets(17,676)(18,897)(4,949)(2,174)(3,889)(4,575)
Recognized net loss4,791 2,268 822 415 454 1,114 
Net pension cost$5,356 $3,529 $876 $299 $562 $1,496 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$4,100 $5,551 $1,284 $440 $962 $1,383 
Interest cost on projected benefit obligation13,217 13,961 3,521 1,569 2,831 3,386 
Expected return on assets(18,155)(19,447)(5,113)(2,203)(4,077)(4,633)
Recognized net loss5,746 2,602 1,140 470 393 1,162 
Settlement charges— — — — — 611 
Net pension cost$4,908 $2,667 $832 $276 $109 $1,909 
The Registrant Subsidiaries’ qualified pension costs, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024, included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,854 $10,908 $2,608 $822 $2,048 $2,744 
Interest cost on projected benefit obligation27,628 29,408 7,398 3,294 5,946 7,170 
Expected return on assets(35,352)(37,794)(9,898)(4,348)(7,778)(9,150)
Recognized net loss9,582 4,536 1,644 830 908 2,228 
Net pension cost$10,712 $7,058 $1,752 $598 $1,124 $2,992 

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
 Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$8,199 $11,102 $2,568 $880 $1,923 $2,767 
Interest cost on projected benefit obligation26,434 27,922 7,042 3,138 5,662 6,777 
Expected return on assets(36,310)(38,894)(10,226)(4,407)(8,154)(9,281)
Recognized net loss11,492 5,204 2,280 940 786 2,327 
Settlement charges— — — — — 611 
Net pension cost$9,815 $5,334 $1,664 $551 $217 $3,201 
Schedule of Expected Benefit Payments [Table Text Block] Based on current assumptions, the Registrant Subsidiaries expect to contribute the following to qualified pension plans for their current and former employees in 2025:
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Expected 2025 pension contributions$35,544 $41,253 $8,064 $5,016 $7,725 $15,668 
Pension contributions made through June 2025$16,968 $17,448 $3,951 $2,112 $3,240 $6,413 
Remaining estimated pension contributions to be made in 2025$18,576 $23,805 $4,113 $2,904 $4,485 $9,255 
System Energy [Member] | Other Postretirement Benefits Plan [Member]  
Defined Benefit Plan Disclosure [Line Items]  
Schedule of Net Benefit Costs [Table Text Block]
The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the second quarters of 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$572 $671 $162 $52 $159 $174 
Interest cost on APBO1,775 2,012 489 249 582 394 
Expected return on assets(4,225)— (1,328)(1,445)(2,452)(702)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss(353)(1,811)(57)(27)153 (7)
Net other postretirement benefits income($1,707)($264)($973)($1,400)($2,651)($214)

2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$642 $700 $184 $51 $168 $175 
Interest cost on APBO1,833 1,999 486 253 603 398 
Expected return on assets(4,384)— (1,372)(1,479)(2,539)(728)
Amortization of prior service cost (credit)524 (1,136)(239)(229)(1,093)(73)
Recognized net (gain) loss— (1,738)15 19 148 — 
Net other postretirement benefits income($1,385)($175)($926)($1,385)($2,713)($228)

The Registrant Subsidiaries’ other postretirement benefits income, including amounts capitalized, for their current and former employees for the six months ended June 30, 2025 and 2024 included the following components:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,144 $1,342 $324 $104 $318 $348 
Interest cost on APBO3,550 4,024 978 498 1,164 788 
Expected return on assets(8,450)— (2,656)(2,890)(4,904)(1,404)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss(706)(3,622)(114)(54)306 (14)
Net other postretirement benefits income($3,414)($528)($1,946)($2,800)($5,302)($428)
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New Orleans		Entergy
Texas		System
Energy
(In Thousands)
Service cost - benefits earned during the period$1,284 $1,400 $368 $102 $336 $350 
Interest cost on APBO3,666 3,998 972 506 1,206 796 
Expected return on assets(8,768)— (2,744)(2,958)(5,078)(1,456)
Amortization of prior service cost (credit)1,048 (2,272)(478)(458)(2,186)(146)
Recognized net (gain) loss— (3,476)30 38 296 — 
Net other postretirement benefits income($2,770)($350)($1,852)($2,770)($5,426)($456)
v3.25.2
Business Segment Information (Tables)
 6 Months Ended
Jun. 30, 2025
Schedule of Segment Reporting Information, by Segment [Table Text Block]
The following table presents segment financial information for Entergy’s single reportable segment, Utility, and a reconciliation to the corresponding consolidated amounts for Entergy Corporation for the three months ended June 30, 2025 and 2024:
UtilityParent & OtherEliminationsConsolidated
(In Thousands)
2025
Depreciation, amortization, and decommissioning$577,386 $1,766 $— $579,152 
Interest and investment income$160,248 $2,146 ($74,975)$87,419 
Interest expense$261,033 $61,475 ($434)$322,074 
Income taxes$152,836 ($14,437)$— $138,399 
2024
Depreciation, amortization, and decommissioning$557,962 $1,594 $— $559,556 
Interest and investment income$141,249 $9,985 ($80,647)$70,587 
Interest expense$225,511 $65,829 ($1,763)$289,577 
Income taxes$113,017 ($79,383)$— $33,634 

The following table presents segment financial information for Entergy’s single reportable segment, Utility, and a reconciliation to the corresponding consolidated amounts for Entergy Corporation for the six months ended June 30, 2025 and 2024:
UtilityParent & OtherEliminationsConsolidated
(In Thousands)
2025
Depreciation, amortization, and decommissioning$1,144,573 $3,451 $— $1,148,024 
Interest and investment income$267,423 $3,835 ($150,433)$120,825 
Interest expense$528,164 $124,344 ($643)$651,865 
Income taxes$267,109 ($28,669)$— $238,440 
Total assets as of June 30, 2025
$72,511,224 $777,674 ($4,905,758)$68,383,140 
Total expenditures for additions to long-lived assets$3,798,452 $606 $— $3,799,058 
2024
Asset write-offs, impairments, and related charges (credits)$131,775 $— $— $131,775 
Depreciation, amortization, and decommissioning$1,109,452 $3,146 $— $1,112,598 
Interest and investment income$366,499 $15,353 ($160,569)$221,283 
Interest expense$437,659 $121,242 ($2,124)$556,777 
Income taxes$147,565 ($92,938)$— $54,627 
Total assets as of December 31, 2024
$68,951,564 $721,459 ($4,882,991)$64,790,032 
Total expenditures for additions to long-lived assets$2,457,683 $693 $— $2,458,376 

Eliminations are primarily intersegment activity. All of Entergy’s goodwill is related to the Utility segment.
Reconciliation of Operating Profit (Loss) from Segments to Consolidated [Table Text Block]
The following table includes operating revenues and significant expense categories regularly provided to the chief operating decision maker for the Utility segment, a reconciliation of Utility operating revenues to Entergy’s consolidated operating revenues, and a reconciliation of Utility net income to consolidated net income and net income attributable to Entergy Corporation for the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
2025202420252024
(In Thousands)(In Thousands)
Utility operating revenues$3,315,723 $2,941,404 $6,145,320 $5,713,577 
Reconciliation of revenues:
Other revenues (a)13,144 12,227 30,448 34,703 
Elimination of intersegment revenues(18)(11)(45)(32)
Consolidated operating revenues3,328,849 2,953,620 6,175,723 5,748,248 
Less Utility expenses and other items:
Fuel, fuel-related expenses, and gas purchased for resale631,773 514,223 970,756 1,118,627 
Purchased power372,842 193,010 714,926 412,204 
Other operation and maintenance expenses713,296 685,990 1,375,770 1,366,705 
Other regulatory charges (credits) - net(55,957)125,607 (72,800)234,954 
Other Utility items (b)1,051,596 979,255 2,063,453 1,941,788 
Utility net income602,173 443,319 1,093,215 639,299 
Reconciliation of net income:
Non-cash pension settlement charge (c)— (316,738)— (316,738)
Income taxes on reconciling item noted above— 66,515 — 66,515 
Other loss(55,678)(62,479)(109,050)(102,362)
Elimination of intersegment loss(74,541)(78,885)(149,789)(158,446)
Consolidated net income471,954 51,732 834,376 128,268 
Preferred dividend requirements of subsidiaries and noncontrolling interests (d)4,024 2,810 5,686 4,065 
Net income attributable to Entergy Corporation$467,930 $48,922 $828,690 $124,203 

(a)See Note 12 to the financial statements herein and Note 19 to the financial statements in the Form 10-K for discussion of other revenues.
(b)Other Utility items includes nuclear refueling outage expenses, asset write-offs, decommissioning expenses, taxes other than income taxes, depreciation and amortization expenses, other income, interest expense, and income tax expense.
(c)See Note 11 to the financial statements in the Form 10-K for discussion of the one-time non-cash pension settlement charge resulting from a group annuity contract purchased in second quarter 2024 to settle certain pension liabilities, of which $8 million was recorded at Utility and $317 million was recorded at Parent & Other.
(d)Preferred dividend requirements of subsidiaries and noncontrolling interests is substantially derived from the Utility segment. See Note 6 to the financial statements in the Form 10-K for discussion of preferred stock and noncontrolling interests.
v3.25.2
Risk Management And Fair Values (Tables)
 6 Months Ended
Jun. 30, 2025
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location [Table Text Block]
The fair values of Entergy’s derivative instruments not designated as hedging instruments on the consolidated balance sheets as of June 30, 2025 and December 31, 2024 are shown in the table below.  Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$49($1)$48
Liabilities:
Natural gas swapsOther current liabilities$3$—$3
2024
Assets:
Natural gas swapsPrepayments and other$2$—$2
Financial transmission rightsPrepayments and other$21($1)$20
Liabilities:
Financial transmission rightsOther current liabilities($—)$1$1

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Entergy Corporation and Subsidiaries’ Consolidated Balance Sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $6 million as of June 30, 2025 and $2 million as of December 31, 2024
Derivatives Not Designated as Hedging Instruments [Table Text Block]
The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement
Location
Amount of gain
recorded in the income statement
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$11
Financial transmission rightsPurchased power expense(b)$66
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)$3
Financial transmission rightsPurchased power expense(b)$47

The effects of Entergy’s derivative instruments not designated as hedging instruments on the consolidated income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement
Location		Amount of gain (loss)
recorded in the income statement
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($1)
Financial transmission rightsPurchased power expense(b)$114
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale(a)($3)
Financial transmission rightsPurchased power expense(b)$100

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]
The following tables set forth, by level within the fair value hierarchy, Entergy’s assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2025 and December 31, 2024.  The assessment of
the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels.
2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$1,012 $— $— $1,012 
Decommissioning trust funds (a):
Equity securities48 — — 48 
Debt securities857 1,250 — 2,107 
Common trusts (b)3,678 
Securitization recovery trust account1 — — 1 
Storm reserve escrow accounts303 — — 303 
Financial transmission rights— — 48 48 
$2,221 $1,250 $48 $7,197 
Liabilities:
Natural gas swaps$— $— $3 $3 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:    
Temporary cash investments$811 $— $— $811 
Decommissioning trust funds (a):
Equity securities30 — — 30 
Debt securities848 1,199 — 2,047 
Common trusts (b)3,486 
Securitization recovery trust account4 — — 4 
Storm reserve escrow accounts340 — — 340 
Natural gas swaps2 — — 2 
Financial transmission rights— — 20 20 
 $2,035 $1,199 $20 $6,740 
Liabilities:    
Financial transmission rights$— $— $1 $1 

(a)The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the returns of major market indices.  Fixed income securities are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.
(b)Common trust funds are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025 and 2024:
20252024
(In Millions)
Balance as of April 1,$7 $9 
Issuances of financial transmission rights49 53 
Gains included as a regulatory liability/asset58 34 
Settlements(66)(47)
Balance as of June 30,$48 $49 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025 and 2024:
20252024
(In Millions)
Balance as of January 1,$20 $21 
Issuances of financial transmission rights49 53 
Gains included as a regulatory liability/asset93 75 
Settlements(114)(100)
Balance as of June 30,$48 $49 
Entergy Arkansas [Member]  
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location [Table Text Block]
The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2025 and December 31, 2024 are shown in the tables below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$11.1$—$11.1Entergy Arkansas
Financial transmission rightsPrepayments and other$28.6($0.3)$28.3Entergy Louisiana
Financial transmission rightsPrepayments and other$1.5($0.1)$1.4Entergy Mississippi
Financial transmission rightsPrepayments and other$3.0$—$3.0Entergy New Orleans
Financial transmission rightsPrepayments and other$4.5($0.6)$3.9Entergy Texas
Liabilities:
Natural gas swapsOther current liabilities$3.0$—$3.0Entergy Mississippi

InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2024
Assets:
Natural gas swapsPrepayments and other$1.6$—$1.6Entergy Mississippi
Financial transmission rightsPrepayments and other$8.6($0.1)$8.5Entergy Arkansas
Financial transmission rightsPrepayments and other$8.7($0.1)$8.6Entergy Louisiana
Financial transmission rightsPrepayments and other$1.3$—$1.3Entergy New Orleans
Financial transmission rightsPrepayments and other$2.0($0.1)$1.9Entergy Texas
Liabilities:
Financial transmission rightsOther current liabilities($0.4)$0.9$0.5Entergy Mississippi

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi,
and $0.6 million for Entergy Texas as of June 30, 2025 and in the amount of $0.5 million for Entergy Arkansas, $0.1 million for Entergy Louisiana, $0.8 million for Entergy Mississippi, $0.1 million for Entergy New Orleans, and $0.3 million for Entergy Texas as of December 31, 2024.
Derivatives Not Designated as Hedging Instruments [Table Text Block]
The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$11.4(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$9.5(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$42.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$8.8(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$2.3(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($3.0)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$12.0(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$25.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$2.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$3.3(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$4.6(b)Entergy Texas
The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($1.2)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$28.2(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$64.1(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$5.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$11.1(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$5.8(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$2.3(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$0.5(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$38.9(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$41.2(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$4.4(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$12.1(b)Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]
The following tables set forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2025 and December 31, 2024.  The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels.

Entergy Arkansas

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$182.4 $— $— $182.4 
Decommissioning trust funds (a):
Equity securities23.3 — — 23.3 
Debt securities266.3 327.8 — 594.1 
Common trusts (b)1,069.3 
Financial transmission rights— — 11.1 11.1 
$472.0 $327.8 $11.1 $1,880.2 
2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$3.4 $— $— $3.4 
Decommissioning trust funds (a):
Equity securities12.9 — — 12.9 
Debt securities259.9 319.1 — 579.0 
Common trusts (b)1,012.5 
Financial transmission rights— — 8.5 8.5 
$276.2 $319.1 $8.5 $1,616.3 
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation
The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$3.0 $3.4 ($0.1)$0.4 $0.4 
Issuances of financial transmission rights11.8 28.7 1.5 3.0 4.0 
Gains included as a regulatory liability/asset5.8 38.2 3.1 8.4 1.8 
Settlements(9.5)(42.0)(3.1)(8.8)(2.3)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$2.8 $4.1 $0.6 $0.5 $1.2 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset7.7 19.1 1.2 2.6 2.7 
Settlements(12.0)(25.0)(2.1)(3.3)(4.6)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$8.6 $8.6 ($0.5)$1.3 $1.9 
Issuances of financial transmission rights11.8 28.7 1.5 2.9 4.0 
Gains included as a regulatory liability/asset18.9 55.1 5.5 9.9 3.8 
Settlements(28.2)(64.1)(5.1)(11.1)(5.8)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$6.0 $9.8 $1.4 $1.1 $2.4 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset31.4 29.6 1.4 3.1 9.0 
Settlements(38.9)(41.2)(3.1)(4.4)(12.1)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 
Entergy Louisiana [Member]  
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location [Table Text Block]
The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2025 and December 31, 2024 are shown in the tables below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$11.1$—$11.1Entergy Arkansas
Financial transmission rightsPrepayments and other$28.6($0.3)$28.3Entergy Louisiana
Financial transmission rightsPrepayments and other$1.5($0.1)$1.4Entergy Mississippi
Financial transmission rightsPrepayments and other$3.0$—$3.0Entergy New Orleans
Financial transmission rightsPrepayments and other$4.5($0.6)$3.9Entergy Texas
Liabilities:
Natural gas swapsOther current liabilities$3.0$—$3.0Entergy Mississippi

InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2024
Assets:
Natural gas swapsPrepayments and other$1.6$—$1.6Entergy Mississippi
Financial transmission rightsPrepayments and other$8.6($0.1)$8.5Entergy Arkansas
Financial transmission rightsPrepayments and other$8.7($0.1)$8.6Entergy Louisiana
Financial transmission rightsPrepayments and other$1.3$—$1.3Entergy New Orleans
Financial transmission rightsPrepayments and other$2.0($0.1)$1.9Entergy Texas
Liabilities:
Financial transmission rightsOther current liabilities($0.4)$0.9$0.5Entergy Mississippi

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi,
and $0.6 million for Entergy Texas as of June 30, 2025 and in the amount of $0.5 million for Entergy Arkansas, $0.1 million for Entergy Louisiana, $0.8 million for Entergy Mississippi, $0.1 million for Entergy New Orleans, and $0.3 million for Entergy Texas as of December 31, 2024.
Derivatives Not Designated as Hedging Instruments [Table Text Block]
The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$11.4(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$9.5(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$42.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$8.8(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$2.3(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($3.0)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$12.0(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$25.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$2.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$3.3(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$4.6(b)Entergy Texas
The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($1.2)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$28.2(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$64.1(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$5.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$11.1(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$5.8(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$2.3(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$0.5(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$38.9(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$41.2(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$4.4(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$12.1(b)Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]
Entergy Louisiana

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$298.3 $— $— $298.3 
Decommissioning trust funds (a):
Equity securities20.8 — — 20.8 
Debt securities332.4 598.9 — 931.3 
Common trusts (b)1,588.4 
Storm reserve escrow account228.4 — — 228.4 
Financial transmission rights— — 28.3 28.3 
$879.9 $598.9 $28.3 $3,095.5 

2024Level 1Level 2Level 3Total
 (In Millions)
Assets:    
Temporary cash investments$326.8 $— $— $326.8 
Decommissioning trust funds (a):
Equity securities14.5 — — 14.5 
Debt securities326.0 582.1 — 908.1 
Common trusts (b)1,506.5 
Storm reserve escrow account256.7 — — 256.7 
Financial transmission rights— — 8.6 8.6 
 $924.0 $582.1 $8.6 $3,021.2 
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation
The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$3.0 $3.4 ($0.1)$0.4 $0.4 
Issuances of financial transmission rights11.8 28.7 1.5 3.0 4.0 
Gains included as a regulatory liability/asset5.8 38.2 3.1 8.4 1.8 
Settlements(9.5)(42.0)(3.1)(8.8)(2.3)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$2.8 $4.1 $0.6 $0.5 $1.2 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset7.7 19.1 1.2 2.6 2.7 
Settlements(12.0)(25.0)(2.1)(3.3)(4.6)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$8.6 $8.6 ($0.5)$1.3 $1.9 
Issuances of financial transmission rights11.8 28.7 1.5 2.9 4.0 
Gains included as a regulatory liability/asset18.9 55.1 5.5 9.9 3.8 
Settlements(28.2)(64.1)(5.1)(11.1)(5.8)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$6.0 $9.8 $1.4 $1.1 $2.4 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset31.4 29.6 1.4 3.1 9.0 
Settlements(38.9)(41.2)(3.1)(4.4)(12.1)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 
Entergy Mississippi [Member]  
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location [Table Text Block]
The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2025 and December 31, 2024 are shown in the tables below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$11.1$—$11.1Entergy Arkansas
Financial transmission rightsPrepayments and other$28.6($0.3)$28.3Entergy Louisiana
Financial transmission rightsPrepayments and other$1.5($0.1)$1.4Entergy Mississippi
Financial transmission rightsPrepayments and other$3.0$—$3.0Entergy New Orleans
Financial transmission rightsPrepayments and other$4.5($0.6)$3.9Entergy Texas
Liabilities:
Natural gas swapsOther current liabilities$3.0$—$3.0Entergy Mississippi

InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2024
Assets:
Natural gas swapsPrepayments and other$1.6$—$1.6Entergy Mississippi
Financial transmission rightsPrepayments and other$8.6($0.1)$8.5Entergy Arkansas
Financial transmission rightsPrepayments and other$8.7($0.1)$8.6Entergy Louisiana
Financial transmission rightsPrepayments and other$1.3$—$1.3Entergy New Orleans
Financial transmission rightsPrepayments and other$2.0($0.1)$1.9Entergy Texas
Liabilities:
Financial transmission rightsOther current liabilities($0.4)$0.9$0.5Entergy Mississippi

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi,
and $0.6 million for Entergy Texas as of June 30, 2025 and in the amount of $0.5 million for Entergy Arkansas, $0.1 million for Entergy Louisiana, $0.8 million for Entergy Mississippi, $0.1 million for Entergy New Orleans, and $0.3 million for Entergy Texas as of December 31, 2024.
Derivatives Not Designated as Hedging Instruments [Table Text Block]
The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$11.4(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$9.5(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$42.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$8.8(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$2.3(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($3.0)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$12.0(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$25.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$2.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$3.3(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$4.6(b)Entergy Texas
The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($1.2)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$28.2(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$64.1(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$5.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$11.1(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$5.8(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$2.3(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$0.5(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$38.9(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$41.2(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$4.4(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$12.1(b)Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]
Entergy Mississippi

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$401.3 $— $— $401.3 
Financial transmission rights— — 1.4 1.4 
$401.3 $— $1.4 $402.7 
Liabilities:
Natural gas swaps$— $— $3.0 $3.0 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$155.5 $— $— $155.5 
Natural gas swaps1.6 — — 1.6 
 $157.1 $— $— $157.1 
Liabilities:
Financial transmission rights$— $— $0.5 $0.5 
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation
The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$3.0 $3.4 ($0.1)$0.4 $0.4 
Issuances of financial transmission rights11.8 28.7 1.5 3.0 4.0 
Gains included as a regulatory liability/asset5.8 38.2 3.1 8.4 1.8 
Settlements(9.5)(42.0)(3.1)(8.8)(2.3)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$2.8 $4.1 $0.6 $0.5 $1.2 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset7.7 19.1 1.2 2.6 2.7 
Settlements(12.0)(25.0)(2.1)(3.3)(4.6)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$8.6 $8.6 ($0.5)$1.3 $1.9 
Issuances of financial transmission rights11.8 28.7 1.5 2.9 4.0 
Gains included as a regulatory liability/asset18.9 55.1 5.5 9.9 3.8 
Settlements(28.2)(64.1)(5.1)(11.1)(5.8)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$6.0 $9.8 $1.4 $1.1 $2.4 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset31.4 29.6 1.4 3.1 9.0 
Settlements(38.9)(41.2)(3.1)(4.4)(12.1)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 
Entergy New Orleans [Member]  
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location [Table Text Block]
The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2025 and December 31, 2024 are shown in the tables below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$11.1$—$11.1Entergy Arkansas
Financial transmission rightsPrepayments and other$28.6($0.3)$28.3Entergy Louisiana
Financial transmission rightsPrepayments and other$1.5($0.1)$1.4Entergy Mississippi
Financial transmission rightsPrepayments and other$3.0$—$3.0Entergy New Orleans
Financial transmission rightsPrepayments and other$4.5($0.6)$3.9Entergy Texas
Liabilities:
Natural gas swapsOther current liabilities$3.0$—$3.0Entergy Mississippi

InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2024
Assets:
Natural gas swapsPrepayments and other$1.6$—$1.6Entergy Mississippi
Financial transmission rightsPrepayments and other$8.6($0.1)$8.5Entergy Arkansas
Financial transmission rightsPrepayments and other$8.7($0.1)$8.6Entergy Louisiana
Financial transmission rightsPrepayments and other$1.3$—$1.3Entergy New Orleans
Financial transmission rightsPrepayments and other$2.0($0.1)$1.9Entergy Texas
Liabilities:
Financial transmission rightsOther current liabilities($0.4)$0.9$0.5Entergy Mississippi

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi,
and $0.6 million for Entergy Texas as of June 30, 2025 and in the amount of $0.5 million for Entergy Arkansas, $0.1 million for Entergy Louisiana, $0.8 million for Entergy Mississippi, $0.1 million for Entergy New Orleans, and $0.3 million for Entergy Texas as of December 31, 2024.
Derivatives Not Designated as Hedging Instruments [Table Text Block]
The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$11.4(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$9.5(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$42.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$8.8(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$2.3(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($3.0)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$12.0(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$25.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$2.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$3.3(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$4.6(b)Entergy Texas
The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($1.2)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$28.2(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$64.1(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$5.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$11.1(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$5.8(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$2.3(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$0.5(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$38.9(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$41.2(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$4.4(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$12.1(b)Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]
Entergy New Orleans

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Storm reserve escrow account$75.1 $— $— $75.1 
Financial transmission rights— — 3.0 3.0 
$75.1 $— $3.0 $78.1 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$31.4 $— $— $31.4 
Securitization recovery trust account1.6 — — 1.6 
Storm reserve escrow account83.7 — — 83.7 
Financial transmission rights— — 1.3 1.3 
$116.7 $— $1.3 $118.0 
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation
The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$3.0 $3.4 ($0.1)$0.4 $0.4 
Issuances of financial transmission rights11.8 28.7 1.5 3.0 4.0 
Gains included as a regulatory liability/asset5.8 38.2 3.1 8.4 1.8 
Settlements(9.5)(42.0)(3.1)(8.8)(2.3)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$2.8 $4.1 $0.6 $0.5 $1.2 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset7.7 19.1 1.2 2.6 2.7 
Settlements(12.0)(25.0)(2.1)(3.3)(4.6)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$8.6 $8.6 ($0.5)$1.3 $1.9 
Issuances of financial transmission rights11.8 28.7 1.5 2.9 4.0 
Gains included as a regulatory liability/asset18.9 55.1 5.5 9.9 3.8 
Settlements(28.2)(64.1)(5.1)(11.1)(5.8)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$6.0 $9.8 $1.4 $1.1 $2.4 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset31.4 29.6 1.4 3.1 9.0 
Settlements(38.9)(41.2)(3.1)(4.4)(12.1)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 
Entergy Texas [Member]  
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location [Table Text Block]
The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of June 30, 2025 and December 31, 2024 are shown in the tables below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2025
Assets:
Financial transmission rightsPrepayments and other$11.1$—$11.1Entergy Arkansas
Financial transmission rightsPrepayments and other$28.6($0.3)$28.3Entergy Louisiana
Financial transmission rightsPrepayments and other$1.5($0.1)$1.4Entergy Mississippi
Financial transmission rightsPrepayments and other$3.0$—$3.0Entergy New Orleans
Financial transmission rightsPrepayments and other$4.5($0.6)$3.9Entergy Texas
Liabilities:
Natural gas swapsOther current liabilities$3.0$—$3.0Entergy Mississippi

InstrumentBalance Sheet LocationGross Fair Value (a)Offsetting Position (b)Net Fair Value (c) (d)Registrant
(In Millions)
2024
Assets:
Natural gas swapsPrepayments and other$1.6$—$1.6Entergy Mississippi
Financial transmission rightsPrepayments and other$8.6($0.1)$8.5Entergy Arkansas
Financial transmission rightsPrepayments and other$8.7($0.1)$8.6Entergy Louisiana
Financial transmission rightsPrepayments and other$1.3$—$1.3Entergy New Orleans
Financial transmission rightsPrepayments and other$2.0($0.1)$1.9Entergy Texas
Liabilities:
Financial transmission rightsOther current liabilities($0.4)$0.9$0.5Entergy Mississippi

(a)Represents the gross amounts of recognized assets/liabilities
(b)Represents the netting of fair value balances with the same counterparty
(c)Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets
(d)Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $3.5 million for Entergy Arkansas, $1.2 million for Entergy Louisiana, $0.6 million for Entergy Mississippi,
and $0.6 million for Entergy Texas as of June 30, 2025 and in the amount of $0.5 million for Entergy Arkansas, $0.1 million for Entergy Louisiana, $0.8 million for Entergy Mississippi, $0.1 million for Entergy New Orleans, and $0.3 million for Entergy Texas as of December 31, 2024.
Derivatives Not Designated as Hedging Instruments [Table Text Block]
The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the three months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$11.4(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$9.5(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$42.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$8.8(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$2.3(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($3.0)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$12.0(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$25.0(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$2.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$3.3(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$4.6(b)Entergy Texas
The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the six months ended June 30, 2025 and 2024 are as follows:
InstrumentIncome Statement LocationAmount of gain
(loss) recorded
in the income statement		Registrant
(In Millions)
2025
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale($1.2)(a)Entergy Mississippi
Financial transmission rightsPurchased power expense$28.2(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$64.1(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$5.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$11.1(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$5.8(b)Entergy Texas
2024
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$2.3(a)Entergy Mississippi
Natural gas swapsFuel, fuel-related expenses, and gas purchased for resale$0.5(a)Entergy New Orleans
Financial transmission rightsPurchased power expense$38.9(b)Entergy Arkansas
Financial transmission rightsPurchased power expense$41.2(b)Entergy Louisiana
Financial transmission rightsPurchased power expense$3.1(b)Entergy Mississippi
Financial transmission rightsPurchased power expense$4.4(b)Entergy New Orleans
Financial transmission rightsPurchased power expense$12.1(b)Entergy Texas

(a)Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.
(b)Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]
Entergy Texas

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$17.7 $— $— $17.7 
Securitization recovery trust account1.0 — — 1.0 
Financial transmission rights— — 3.9 3.9 
$18.7 $— $3.9 $22.6 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$184.7 $— $— $184.7 
Securitization recovery trust account2.7 — — 2.7 
Financial transmission rights— — 1.9 1.9 
$187.4 $— $1.9 $189.3 
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation
The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$3.0 $3.4 ($0.1)$0.4 $0.4 
Issuances of financial transmission rights11.8 28.7 1.5 3.0 4.0 
Gains included as a regulatory liability/asset5.8 38.2 3.1 8.4 1.8 
Settlements(9.5)(42.0)(3.1)(8.8)(2.3)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the three months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of April 1,$2.8 $4.1 $0.6 $0.5 $1.2 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset7.7 19.1 1.2 2.6 2.7 
Settlements(12.0)(25.0)(2.1)(3.3)(4.6)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2025.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$8.6 $8.6 ($0.5)$1.3 $1.9 
Issuances of financial transmission rights11.8 28.7 1.5 2.9 4.0 
Gains included as a regulatory liability/asset18.9 55.1 5.5 9.9 3.8 
Settlements(28.2)(64.1)(5.1)(11.1)(5.8)
Balance as of June 30,$11.1 $28.3 $1.4 $3.0 $3.9 
The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the six months ended June 30, 2024.
Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
 (In Millions)
Balance as of January 1,$6.0 $9.8 $1.4 $1.1 $2.4 
Issuances of financial transmission rights17.6 21.6 3.9 2.8 7.3 
Gains included as a regulatory liability/asset31.4 29.6 1.4 3.1 9.0 
Settlements(38.9)(41.2)(3.1)(4.4)(12.1)
Balance as of June 30,$16.1 $19.8 $3.6 $2.6 $6.6 
System Energy [Member]  
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]
System Energy

2025Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$31.7 $— $— $31.7 
Decommissioning trust funds (a):
Equity securities4.1 — — 4.1 
Debt securities258.6 323.5 — 582.1 
Common trusts (b)1,020.1 
$294.4 $323.5 $— $1,638.0 

2024Level 1Level 2Level 3Total
(In Millions)
Assets:
Temporary cash investments$28.5 $— $— $28.5 
Decommissioning trust funds (a):
Equity securities2.4 — — 2.4 
Debt securities262.4 297.4 — 559.8 
Common trusts (b)966.9 
$293.3 $297.4 $— $1,557.6 
v3.25.2
Decommissioning Trust Funds (Tables)
 6 Months Ended
Jun. 30, 2025
Debt Securities, Available-for-Sale, Unrealized Loss Position, Fair Value [Table Text Block]
The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$565 $17 $1,102 $24 
More than 12 months438 43 510 56 
Total$1,003 $60 $1,612 $80 
Investments Classified by Contractual Maturity Date [Table Text Block]
The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
20252024
(In Millions)
Less than 1 year$29 $36 
1 year - 5 years541 574 
5 years - 10 years672 629 
10 years - 15 years195 166 
15 years - 20 years197 218 
20 years+473 424 
Total$2,107 $2,047 
Schedule of Realized Gain (Loss)
The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$227 $161 $489 $330 
Realized gains$1 $— $2 $1 
Realized losses$4 $14 $8 $20 
Debt Securities, Available-for-Sale
The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$2,107 $2,047 
Unrealized gains$20 $7 
Unrealized losses$60 $80 
Entergy Arkansas [Member]  
Debt Securities, Available-for-Sale, Unrealized Loss Position, Fair Value [Table Text Block]
The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$141.8 $4.6 $282.8 $8.2 
More than 12 months174.0 12.9 195.0 17.6 
Total$315.8 $17.5 $477.8 $25.8 
Investments Classified by Contractual Maturity Date [Table Text Block]
The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
 20252024
 (In Millions)
Less than 1 year$26.3 $31.7 
1 year - 5 years159.2 142.5 
5 years - 10 years251.7 231.0 
10 years - 15 years37.4 62.2 
15 years - 20 years43.1 62.8 
20 years+76.4 48.8 
Total$594.1 $579.0 
Schedule of Realized Gain (Loss)
The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$— $5.5 $— $17.9 
Realized gains$— $0.1 $— $0.1 
Realized losses$— $0.4 $— $0.9 
Debt Securities, Available-for-Sale The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$594.1 $579.0 
Unrealized gains$5.4 $1.2 
Unrealized losses$17.5 $25.8 
Entergy Louisiana [Member]  
Debt Securities, Available-for-Sale, Unrealized Loss Position, Fair Value [Table Text Block]
The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$318.7 $9.4 $543.8 $8.8 
More than 12 months150.6 14.7 178.4 18.1 
Total$469.3 $24.1 $722.2 $26.9 
Investments Classified by Contractual Maturity Date [Table Text Block]
The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
20252024
(In Millions)
Less than 1 year$2.4 $4.4 
1 year - 5 years212.3 188.2 
5 years - 10 years214.3 259.4 
10 years - 15 years115.0 80.9 
15 years - 20 years107.6 106.1 
20 years+279.7 269.1 
Total$931.3 $908.1 
Schedule of Realized Gain (Loss)
The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$71.5 $62.5 $181.5 $110.9 
Realized gains$0.1 $0.1 $0.2 $0.2 
Realized losses$2.4 $4.8 $4.0 $7.7 
Debt Securities, Available-for-Sale The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$931.3 $908.1 
Unrealized gains$8.1 $3.6 
Unrealized losses$24.1 $26.9 
System Energy [Member]  
Debt Securities, Available-for-Sale, Unrealized Loss Position, Fair Value [Table Text Block]
The fair value and gross unrealized losses of available-for-sale debt securities, summarized by length of time that the securities had been in a continuous loss position, were as follows as of June 30, 2025 and December 31, 2024:
20252024
Fair
Value		Gross
Unrealized
Losses		Fair
Value		Gross
Unrealized
Losses
(In Millions)
Less than 12 months$104.2 $3.3 $275.6 $6.8 
More than 12 months113.8 15.7 136.8 20.8 
Total$218.0 $19.0 $412.4 $27.6 
Investments Classified by Contractual Maturity Date [Table Text Block]
The fair value of available-for-sale debt securities, summarized by contractual maturities, as of June 30, 2025 and December 31, 2024 were as follows:
20252024
(In Millions)
Less than 1 year$0.2 $0.2 
1 year - 5 years169.2 243.7 
5 years - 10 years206.4 138.9 
10 years - 15 years42.5 22.7 
15 years - 20 years46.4 49.4 
20 years+117.4 104.9 
Total$582.1 $559.8 
Schedule of Realized Gain (Loss)
The following table summarizes proceeds from the dispositions of available-for-sale debt securities and the related gains and losses from the sales during the three and six months ended June 30, 2025 and 2024:
Three Months EndedSix Months Ended
 2025202420252024
 (In Millions)
Proceeds from disposition of securities$155.3 $93.5 $307.6 $201.5 
Realized gains$0.8 $— $1.3 $0.2 
Realized losses$1.4 $8.4 $4.0 $11.9 
Debt Securities, Available-for-Sale The available-for-sale debt securities held as of June 30, 2025 and December 31, 2024 are summarized as follows:
20252024
(In Millions)
Fair value$582.1 $559.8 
Unrealized gains$6.1 $1.9 
Unrealized losses$19.0 $27.6 
v3.25.2
Revenue (Tables)
 6 Months Ended
Jun. 30, 2025
Disaggregation of Revenue [Table Text Block] Entergy’s total revenues for the three months ended June 30, 2025 and 2024 were as follows:
20252024
(In Thousands)
Utility:
Residential$1,091,035 $1,009,836 
Commercial771,097 713,282 
Industrial945,901 792,721 
Governmental70,623 65,861 
Total billed retail2,878,656 2,581,700 
Sales for resale (a)146,457 54,579 
Other electric revenues (b)246,674 257,813 
Revenues from contracts with customers3,271,787 2,894,092 
Other Utility revenues (c)3,158 11,955 
Electric revenues3,274,945 2,906,047 
Natural gas revenues40,778 35,357 
Other revenues (d)13,126 12,216 
Total operating revenues$3,328,849 $2,953,620 
Entergy’s total revenues for the six months ended June 30, 2025 and 2024 were as follows:
20252024
(In Thousands)
Utility:
Residential$2,204,340 $2,080,177 
Commercial1,455,104 1,405,133 
Industrial1,720,020 1,541,679 
Governmental133,441 131,172 
Total billed retail5,512,905 5,158,161 
Sales for resale (a)198,330 133,583 
Other electric revenues (b)322,892 293,847 
Revenues from contracts with customers6,034,127 5,585,591 
Other Utility revenues (c)(1,316)26,962 
Electric revenues6,032,811 5,612,553 
Natural gas revenues112,509 101,024 
Other revenues (d)30,403 34,671 
Total operating revenues$6,175,723 $5,748,248 
Entergy Arkansas [Member]  
Disaggregation of Revenue [Table Text Block]
The Utility operating companies’ total revenues for the three months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$212,265 $408,293 $172,575 $73,279 $224,623 
Commercial141,468 306,916 147,052 58,133 117,528 
Industrial174,555 570,303 53,629 7,800 139,614 
Governmental4,911 23,622 14,544 20,656 6,890 
Total billed retail533,199 1,309,134 387,800 159,868 488,655 
Sales for resale (a)84,533 109,243 61,713 10,027 5,195 
Other electric revenues (b)78,808 75,871 41,739 13,779 37,761 
Revenues from contracts with customers696,540 1,494,248 491,252 183,674 531,611 
Other revenues (c)1,147 1,256 623 107 30 
Electric revenues697,687 1,495,504 491,875 183,781 531,641 
Natural gas revenues— 14,559 — 26,219 — 
Total operating revenues$697,687 $1,510,063 $491,875 $210,000 $531,641 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$204,822 $353,975 $163,049 $71,842 $216,148 
Commercial132,950 265,869 142,173 57,360 114,930 
Industrial138,786 458,420 49,180 7,602 138,733 
Governmental4,433 21,223 14,061 19,167 6,977 
Total billed retail480,991 1,099,487 368,463 155,971 476,788 
Sales for resale (a)43,842 80,823 21,260 8,575 3,015 
Other electric revenues (b)81,733 74,670 50,718 12,811 39,224 
Revenues from contracts with customers606,566 1,254,980 440,441 177,357 519,027 
Other revenues (c)2,232 6,464 2,453 1,307 50 
Electric revenues608,798 1,261,444 442,894 178,664 519,077 
Natural gas revenues— 14,680 — 20,677 — 
Total operating revenues$608,798 $1,276,124 $442,894 $199,341 $519,077 

The Utility operating companies’ total revenues for the six months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$486,871 $786,531 $358,883 $138,969 $433,086 
Commercial273,085 570,116 282,925 105,755 223,223 
Industrial323,620 1,036,010 100,974 13,454 245,962 
Governmental9,130 45,290 28,234 37,185 13,602 
Total billed retail1,092,706 2,437,947 771,016 295,363 915,873 
Sales for resale (a)121,262 220,791 89,810 13,917 7,590 
Other electric revenues (b)94,884 113,861 53,538 13,214 50,057 
Revenues from contracts with customers1,308,852 2,772,599 914,364 322,494 973,520 
Other revenues (c)2,346 (5,149)1,220 212 60 
Electric revenues1,311,198 2,767,450 915,584 322,706 973,580 
Natural gas revenues— 44,160 — 68,349 — 
Total operating revenues$1,311,198 $2,811,610 $915,584 $391,055 $973,580 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$480,574 $699,003 $341,666 $139,520 $419,414 
Commercial274,258 522,565 274,491 110,585 223,234 
Industrial288,193 880,017 95,607 14,580 263,282 
Governmental9,133 43,044 27,390 37,521 14,084 
Total billed retail1,052,158 2,144,629 739,154 302,206 920,014 
Sales for resale (a)82,807 163,551 69,193 21,075 4,922 
Other electric revenues (b)91,074 112,615 44,516 9,592 38,736 
Revenues from contracts with customers1,226,039 2,420,795 852,863 332,873 963,672 
Other revenues (c)4,804 13,442 4,887 2,732 (104)
Electric revenues1,230,843 2,434,237 857,750 335,605 963,568 
Natural gas revenues— 44,327 — 56,697 — 
Total operating revenues$1,230,843 $2,478,564 $857,750 $392,302 $963,568 

(a)Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues.
(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators.
(c)Other Utility revenues include the occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
(d)Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, and operation and management services fees.
Entergy Louisiana [Member]  
Disaggregation of Revenue [Table Text Block]
The Utility operating companies’ total revenues for the three months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$212,265 $408,293 $172,575 $73,279 $224,623 
Commercial141,468 306,916 147,052 58,133 117,528 
Industrial174,555 570,303 53,629 7,800 139,614 
Governmental4,911 23,622 14,544 20,656 6,890 
Total billed retail533,199 1,309,134 387,800 159,868 488,655 
Sales for resale (a)84,533 109,243 61,713 10,027 5,195 
Other electric revenues (b)78,808 75,871 41,739 13,779 37,761 
Revenues from contracts with customers696,540 1,494,248 491,252 183,674 531,611 
Other revenues (c)1,147 1,256 623 107 30 
Electric revenues697,687 1,495,504 491,875 183,781 531,641 
Natural gas revenues— 14,559 — 26,219 — 
Total operating revenues$697,687 $1,510,063 $491,875 $210,000 $531,641 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$204,822 $353,975 $163,049 $71,842 $216,148 
Commercial132,950 265,869 142,173 57,360 114,930 
Industrial138,786 458,420 49,180 7,602 138,733 
Governmental4,433 21,223 14,061 19,167 6,977 
Total billed retail480,991 1,099,487 368,463 155,971 476,788 
Sales for resale (a)43,842 80,823 21,260 8,575 3,015 
Other electric revenues (b)81,733 74,670 50,718 12,811 39,224 
Revenues from contracts with customers606,566 1,254,980 440,441 177,357 519,027 
Other revenues (c)2,232 6,464 2,453 1,307 50 
Electric revenues608,798 1,261,444 442,894 178,664 519,077 
Natural gas revenues— 14,680 — 20,677 — 
Total operating revenues$608,798 $1,276,124 $442,894 $199,341 $519,077 

The Utility operating companies’ total revenues for the six months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$486,871 $786,531 $358,883 $138,969 $433,086 
Commercial273,085 570,116 282,925 105,755 223,223 
Industrial323,620 1,036,010 100,974 13,454 245,962 
Governmental9,130 45,290 28,234 37,185 13,602 
Total billed retail1,092,706 2,437,947 771,016 295,363 915,873 
Sales for resale (a)121,262 220,791 89,810 13,917 7,590 
Other electric revenues (b)94,884 113,861 53,538 13,214 50,057 
Revenues from contracts with customers1,308,852 2,772,599 914,364 322,494 973,520 
Other revenues (c)2,346 (5,149)1,220 212 60 
Electric revenues1,311,198 2,767,450 915,584 322,706 973,580 
Natural gas revenues— 44,160 — 68,349 — 
Total operating revenues$1,311,198 $2,811,610 $915,584 $391,055 $973,580 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$480,574 $699,003 $341,666 $139,520 $419,414 
Commercial274,258 522,565 274,491 110,585 223,234 
Industrial288,193 880,017 95,607 14,580 263,282 
Governmental9,133 43,044 27,390 37,521 14,084 
Total billed retail1,052,158 2,144,629 739,154 302,206 920,014 
Sales for resale (a)82,807 163,551 69,193 21,075 4,922 
Other electric revenues (b)91,074 112,615 44,516 9,592 38,736 
Revenues from contracts with customers1,226,039 2,420,795 852,863 332,873 963,672 
Other revenues (c)4,804 13,442 4,887 2,732 (104)
Electric revenues1,230,843 2,434,237 857,750 335,605 963,568 
Natural gas revenues— 44,327 — 56,697 — 
Total operating revenues$1,230,843 $2,478,564 $857,750 $392,302 $963,568 

(a)Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues.
(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators.
(c)Other Utility revenues include the occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
(d)Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, and operation and management services fees.
Entergy Mississippi [Member]  
Disaggregation of Revenue [Table Text Block]
The Utility operating companies’ total revenues for the three months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$212,265 $408,293 $172,575 $73,279 $224,623 
Commercial141,468 306,916 147,052 58,133 117,528 
Industrial174,555 570,303 53,629 7,800 139,614 
Governmental4,911 23,622 14,544 20,656 6,890 
Total billed retail533,199 1,309,134 387,800 159,868 488,655 
Sales for resale (a)84,533 109,243 61,713 10,027 5,195 
Other electric revenues (b)78,808 75,871 41,739 13,779 37,761 
Revenues from contracts with customers696,540 1,494,248 491,252 183,674 531,611 
Other revenues (c)1,147 1,256 623 107 30 
Electric revenues697,687 1,495,504 491,875 183,781 531,641 
Natural gas revenues— 14,559 — 26,219 — 
Total operating revenues$697,687 $1,510,063 $491,875 $210,000 $531,641 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$204,822 $353,975 $163,049 $71,842 $216,148 
Commercial132,950 265,869 142,173 57,360 114,930 
Industrial138,786 458,420 49,180 7,602 138,733 
Governmental4,433 21,223 14,061 19,167 6,977 
Total billed retail480,991 1,099,487 368,463 155,971 476,788 
Sales for resale (a)43,842 80,823 21,260 8,575 3,015 
Other electric revenues (b)81,733 74,670 50,718 12,811 39,224 
Revenues from contracts with customers606,566 1,254,980 440,441 177,357 519,027 
Other revenues (c)2,232 6,464 2,453 1,307 50 
Electric revenues608,798 1,261,444 442,894 178,664 519,077 
Natural gas revenues— 14,680 — 20,677 — 
Total operating revenues$608,798 $1,276,124 $442,894 $199,341 $519,077 

The Utility operating companies’ total revenues for the six months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$486,871 $786,531 $358,883 $138,969 $433,086 
Commercial273,085 570,116 282,925 105,755 223,223 
Industrial323,620 1,036,010 100,974 13,454 245,962 
Governmental9,130 45,290 28,234 37,185 13,602 
Total billed retail1,092,706 2,437,947 771,016 295,363 915,873 
Sales for resale (a)121,262 220,791 89,810 13,917 7,590 
Other electric revenues (b)94,884 113,861 53,538 13,214 50,057 
Revenues from contracts with customers1,308,852 2,772,599 914,364 322,494 973,520 
Other revenues (c)2,346 (5,149)1,220 212 60 
Electric revenues1,311,198 2,767,450 915,584 322,706 973,580 
Natural gas revenues— 44,160 — 68,349 — 
Total operating revenues$1,311,198 $2,811,610 $915,584 $391,055 $973,580 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$480,574 $699,003 $341,666 $139,520 $419,414 
Commercial274,258 522,565 274,491 110,585 223,234 
Industrial288,193 880,017 95,607 14,580 263,282 
Governmental9,133 43,044 27,390 37,521 14,084 
Total billed retail1,052,158 2,144,629 739,154 302,206 920,014 
Sales for resale (a)82,807 163,551 69,193 21,075 4,922 
Other electric revenues (b)91,074 112,615 44,516 9,592 38,736 
Revenues from contracts with customers1,226,039 2,420,795 852,863 332,873 963,672 
Other revenues (c)4,804 13,442 4,887 2,732 (104)
Electric revenues1,230,843 2,434,237 857,750 335,605 963,568 
Natural gas revenues— 44,327 — 56,697 — 
Total operating revenues$1,230,843 $2,478,564 $857,750 $392,302 $963,568 

(a)Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues.
(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators.
(c)Other Utility revenues include the occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
(d)Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, and operation and management services fees.
Entergy New Orleans [Member]  
Disaggregation of Revenue [Table Text Block]
The Utility operating companies’ total revenues for the three months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$212,265 $408,293 $172,575 $73,279 $224,623 
Commercial141,468 306,916 147,052 58,133 117,528 
Industrial174,555 570,303 53,629 7,800 139,614 
Governmental4,911 23,622 14,544 20,656 6,890 
Total billed retail533,199 1,309,134 387,800 159,868 488,655 
Sales for resale (a)84,533 109,243 61,713 10,027 5,195 
Other electric revenues (b)78,808 75,871 41,739 13,779 37,761 
Revenues from contracts with customers696,540 1,494,248 491,252 183,674 531,611 
Other revenues (c)1,147 1,256 623 107 30 
Electric revenues697,687 1,495,504 491,875 183,781 531,641 
Natural gas revenues— 14,559 — 26,219 — 
Total operating revenues$697,687 $1,510,063 $491,875 $210,000 $531,641 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$204,822 $353,975 $163,049 $71,842 $216,148 
Commercial132,950 265,869 142,173 57,360 114,930 
Industrial138,786 458,420 49,180 7,602 138,733 
Governmental4,433 21,223 14,061 19,167 6,977 
Total billed retail480,991 1,099,487 368,463 155,971 476,788 
Sales for resale (a)43,842 80,823 21,260 8,575 3,015 
Other electric revenues (b)81,733 74,670 50,718 12,811 39,224 
Revenues from contracts with customers606,566 1,254,980 440,441 177,357 519,027 
Other revenues (c)2,232 6,464 2,453 1,307 50 
Electric revenues608,798 1,261,444 442,894 178,664 519,077 
Natural gas revenues— 14,680 — 20,677 — 
Total operating revenues$608,798 $1,276,124 $442,894 $199,341 $519,077 

The Utility operating companies’ total revenues for the six months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$486,871 $786,531 $358,883 $138,969 $433,086 
Commercial273,085 570,116 282,925 105,755 223,223 
Industrial323,620 1,036,010 100,974 13,454 245,962 
Governmental9,130 45,290 28,234 37,185 13,602 
Total billed retail1,092,706 2,437,947 771,016 295,363 915,873 
Sales for resale (a)121,262 220,791 89,810 13,917 7,590 
Other electric revenues (b)94,884 113,861 53,538 13,214 50,057 
Revenues from contracts with customers1,308,852 2,772,599 914,364 322,494 973,520 
Other revenues (c)2,346 (5,149)1,220 212 60 
Electric revenues1,311,198 2,767,450 915,584 322,706 973,580 
Natural gas revenues— 44,160 — 68,349 — 
Total operating revenues$1,311,198 $2,811,610 $915,584 $391,055 $973,580 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$480,574 $699,003 $341,666 $139,520 $419,414 
Commercial274,258 522,565 274,491 110,585 223,234 
Industrial288,193 880,017 95,607 14,580 263,282 
Governmental9,133 43,044 27,390 37,521 14,084 
Total billed retail1,052,158 2,144,629 739,154 302,206 920,014 
Sales for resale (a)82,807 163,551 69,193 21,075 4,922 
Other electric revenues (b)91,074 112,615 44,516 9,592 38,736 
Revenues from contracts with customers1,226,039 2,420,795 852,863 332,873 963,672 
Other revenues (c)4,804 13,442 4,887 2,732 (104)
Electric revenues1,230,843 2,434,237 857,750 335,605 963,568 
Natural gas revenues— 44,327 — 56,697 — 
Total operating revenues$1,230,843 $2,478,564 $857,750 $392,302 $963,568 

(a)Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues.
(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators.
(c)Other Utility revenues include the occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
(d)Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, and operation and management services fees.
Entergy Texas [Member]  
Disaggregation of Revenue [Table Text Block]
The Utility operating companies’ total revenues for the three months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$212,265 $408,293 $172,575 $73,279 $224,623 
Commercial141,468 306,916 147,052 58,133 117,528 
Industrial174,555 570,303 53,629 7,800 139,614 
Governmental4,911 23,622 14,544 20,656 6,890 
Total billed retail533,199 1,309,134 387,800 159,868 488,655 
Sales for resale (a)84,533 109,243 61,713 10,027 5,195 
Other electric revenues (b)78,808 75,871 41,739 13,779 37,761 
Revenues from contracts with customers696,540 1,494,248 491,252 183,674 531,611 
Other revenues (c)1,147 1,256 623 107 30 
Electric revenues697,687 1,495,504 491,875 183,781 531,641 
Natural gas revenues— 14,559 — 26,219 — 
Total operating revenues$697,687 $1,510,063 $491,875 $210,000 $531,641 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$204,822 $353,975 $163,049 $71,842 $216,148 
Commercial132,950 265,869 142,173 57,360 114,930 
Industrial138,786 458,420 49,180 7,602 138,733 
Governmental4,433 21,223 14,061 19,167 6,977 
Total billed retail480,991 1,099,487 368,463 155,971 476,788 
Sales for resale (a)43,842 80,823 21,260 8,575 3,015 
Other electric revenues (b)81,733 74,670 50,718 12,811 39,224 
Revenues from contracts with customers606,566 1,254,980 440,441 177,357 519,027 
Other revenues (c)2,232 6,464 2,453 1,307 50 
Electric revenues608,798 1,261,444 442,894 178,664 519,077 
Natural gas revenues— 14,680 — 20,677 — 
Total operating revenues$608,798 $1,276,124 $442,894 $199,341 $519,077 

The Utility operating companies’ total revenues for the six months ended June 30, 2025 and 2024 were as follows:
2025Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$486,871 $786,531 $358,883 $138,969 $433,086 
Commercial273,085 570,116 282,925 105,755 223,223 
Industrial323,620 1,036,010 100,974 13,454 245,962 
Governmental9,130 45,290 28,234 37,185 13,602 
Total billed retail1,092,706 2,437,947 771,016 295,363 915,873 
Sales for resale (a)121,262 220,791 89,810 13,917 7,590 
Other electric revenues (b)94,884 113,861 53,538 13,214 50,057 
Revenues from contracts with customers1,308,852 2,772,599 914,364 322,494 973,520 
Other revenues (c)2,346 (5,149)1,220 212 60 
Electric revenues1,311,198 2,767,450 915,584 322,706 973,580 
Natural gas revenues— 44,160 — 68,349 — 
Total operating revenues$1,311,198 $2,811,610 $915,584 $391,055 $973,580 
2024Entergy
Arkansas		Entergy
Louisiana		Entergy
Mississippi		Entergy
New
Orleans		Entergy
Texas
(In Thousands)
Residential$480,574 $699,003 $341,666 $139,520 $419,414 
Commercial274,258 522,565 274,491 110,585 223,234 
Industrial288,193 880,017 95,607 14,580 263,282 
Governmental9,133 43,044 27,390 37,521 14,084 
Total billed retail1,052,158 2,144,629 739,154 302,206 920,014 
Sales for resale (a)82,807 163,551 69,193 21,075 4,922 
Other electric revenues (b)91,074 112,615 44,516 9,592 38,736 
Revenues from contracts with customers1,226,039 2,420,795 852,863 332,873 963,672 
Other revenues (c)4,804 13,442 4,887 2,732 (104)
Electric revenues1,230,843 2,434,237 857,750 335,605 963,568 
Natural gas revenues— 44,327 — 56,697 — 
Total operating revenues$1,230,843 $2,478,564 $857,750 $392,302 $963,568 

(a)Sales for resale includes day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short duration of these transactions, Entergy does not consider them to be derivatives subject to fair value adjustments and includes them as part of customer revenues.
(b)Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market, unbilled revenue, and certain customer credits as directed by regulators.
(c)Other Utility revenues include the occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.
(d)Other revenues include the sale of electric power and capacity to wholesale customers, day-ahead sales of energy in a market administered by an ISO, and operation and management services fees.
v3.25.2
Acquisitions, Held for Sale, and Dispositions (Tables)
 6 Months Ended
Jun. 30, 2025
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]  
Disposal Groups, Including Discontinued Operations The assets and liabilities of the Entergy Louisiana and Entergy New Orleans natural gas distribution businesses classified as held for sale on Entergy’s, Entergy Louisiana’s, and Entergy New Orleans’s consolidated balance sheets as of June 30, 2025 and December 31, 2024 included the following amounts:
June 30, 2025
December 31, 2024
EntergyEntergy LouisianaEntergy New OrleansEntergyEntergy LouisianaEntergy New Orleans
(In Thousands)(In Thousands)
Deferred fuel$5,829 $3,324 $2,505 $5,608 $727 $4,881 
Fuel inventory - at average cost4,828 295 4,5334,493 702 3,791
Materials and supplies7,6041,1726,4325,4511,0454,406
Prepayments and other1,341 54 1,28722 — 22
Total current assets held for sale$19,602 $4,845 $14,757 $15,574 $2,474 $13,100 
Property, plant, and equipment - natural gas$697,812 $311,898 $385,914 $679,502 $303,193 $376,309 
Construction work in progress2,710 1,730 980 2,959 1,085 1,874 
Less - accumulated depreciation and amortization(283,404)(141,818)(141,586)(276,388)(139,556)(136,832)
Other regulatory assets33,523 6,936 23,667 35,381 8,947 23,682 
Goodwill (a)6,517 — — 6,474 — — 
Pension and other postretirement assets15,171 — 19,952 14,663 — 19,499 
Other199 — 199 206 — 206 
Total non-current assets held for sale$472,528 $178,746 $289,126 $462,797 $173,669 $284,738 
Accounts payable$2,945 $295 $2,650 $702 $702 $— 
Customer deposits5,327 2,572 2,755 6,214 1,984 4,230 
Taxes accrued— — — 13 13 — 
Other1,352 536 816 1,401 589 812 
Total current liabilities held for sale (b)
$9,624 $3,403 $6,221 $8,330 $3,288 $5,042 
Regulatory liability for income taxes - net$28,438 $3,193 $25,245 $31,575 $4,981 $26,594 
Other regulatory liabilities2,579 945 1,634 1,611 1,214 397 
Pension and other postretirement liabilities4,236 4,643 1,610 3,976 4,525 1,197 
Other4,146 1,414 2,732 3,844 1,194 2,650 
Total non-current liabilities held for sale (c)
$39,399 $10,195 $31,221 $41,006 $11,914 $30,838 
(a)    Goodwill was allocated to the natural gas distribution business based on its relative fair value compared to the retained portion of the reporting unit.
(b)    Included within other current liabilities on the respective consolidated balance sheets.
(c)    Included within other non-current liabilities on the respective consolidated balance sheets.
Schedule of Income (Loss) from Individually Significant Component Disposed of or Held-for-Sale [Table Text Block]
The pre-tax income for the Entergy Louisiana and Entergy New Orleans natural gas distribution businesses, excluding interest and corporate allocations, included in Entergy’s, Entergy Louisiana’s, and Entergy New Orleans’s consolidated income statements for the three and six months ended June 30, 2025 and 2024 is as follows:
Three Months EndedSix Months Ended
2025202420252024
(In Thousands)(In Thousands)
Entergy$9,484 $7,527 $31,500 $27,459 
Entergy Louisiana$2,272 $2,754 $12,047 $12,858 
Entergy New Orleans$7,212 $4,773 $19,453 $14,601 
Entergy Louisiana [Member]  
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]  
Disposal Groups, Including Discontinued Operations The assets and liabilities of the Entergy Louisiana and Entergy New Orleans natural gas distribution businesses classified as held for sale on Entergy’s, Entergy Louisiana’s, and Entergy New Orleans’s consolidated balance sheets as of June 30, 2025 and December 31, 2024 included the following amounts:
June 30, 2025
December 31, 2024
EntergyEntergy LouisianaEntergy New OrleansEntergyEntergy LouisianaEntergy New Orleans
(In Thousands)(In Thousands)
Deferred fuel$5,829 $3,324 $2,505 $5,608 $727 $4,881 
Fuel inventory - at average cost4,828 295 4,5334,493 702 3,791
Materials and supplies7,6041,1726,4325,4511,0454,406
Prepayments and other1,341 54 1,28722 — 22
Total current assets held for sale$19,602 $4,845 $14,757 $15,574 $2,474 $13,100 
Property, plant, and equipment - natural gas$697,812 $311,898 $385,914 $679,502 $303,193 $376,309 
Construction work in progress2,710 1,730 980 2,959 1,085 1,874 
Less - accumulated depreciation and amortization(283,404)(141,818)(141,586)(276,388)(139,556)(136,832)
Other regulatory assets33,523 6,936 23,667 35,381 8,947 23,682 
Goodwill (a)6,517 — — 6,474 — — 
Pension and other postretirement assets15,171 — 19,952 14,663 — 19,499 
Other199 — 199 206 — 206 
Total non-current assets held for sale$472,528 $178,746 $289,126 $462,797 $173,669 $284,738 
Accounts payable$2,945 $295 $2,650 $702 $702 $— 
Customer deposits5,327 2,572 2,755 6,214 1,984 4,230 
Taxes accrued— — — 13 13 — 
Other1,352 536 816 1,401 589 812 
Total current liabilities held for sale (b)
$9,624 $3,403 $6,221 $8,330 $3,288 $5,042 
Regulatory liability for income taxes - net$28,438 $3,193 $25,245 $31,575 $4,981 $26,594 
Other regulatory liabilities2,579 945 1,634 1,611 1,214 397 
Pension and other postretirement liabilities4,236 4,643 1,610 3,976 4,525 1,197 
Other4,146 1,414 2,732 3,844 1,194 2,650 
Total non-current liabilities held for sale (c)
$39,399 $10,195 $31,221 $41,006 $11,914 $30,838 
(a)    Goodwill was allocated to the natural gas distribution business based on its relative fair value compared to the retained portion of the reporting unit.
(b)    Included within other current liabilities on the respective consolidated balance sheets.
(c)    Included within other non-current liabilities on the respective consolidated balance sheets.
Schedule of Income (Loss) from Individually Significant Component Disposed of or Held-for-Sale [Table Text Block]
The pre-tax income for the Entergy Louisiana and Entergy New Orleans natural gas distribution businesses, excluding interest and corporate allocations, included in Entergy’s, Entergy Louisiana’s, and Entergy New Orleans’s consolidated income statements for the three and six months ended June 30, 2025 and 2024 is as follows:
Three Months EndedSix Months Ended
2025202420252024
(In Thousands)(In Thousands)
Entergy$9,484 $7,527 $31,500 $27,459 
Entergy Louisiana$2,272 $2,754 $12,047 $12,858 
Entergy New Orleans$7,212 $4,773 $19,453 $14,601 
Entergy New Orleans [Member]  
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]  
Disposal Groups, Including Discontinued Operations The assets and liabilities of the Entergy Louisiana and Entergy New Orleans natural gas distribution businesses classified as held for sale on Entergy’s, Entergy Louisiana’s, and Entergy New Orleans’s consolidated balance sheets as of June 30, 2025 and December 31, 2024 included the following amounts:
June 30, 2025
December 31, 2024
EntergyEntergy LouisianaEntergy New OrleansEntergyEntergy LouisianaEntergy New Orleans
(In Thousands)(In Thousands)
Deferred fuel$5,829 $3,324 $2,505 $5,608 $727 $4,881 
Fuel inventory - at average cost4,828 295 4,5334,493 702 3,791
Materials and supplies7,6041,1726,4325,4511,0454,406
Prepayments and other1,341 54 1,28722 — 22
Total current assets held for sale$19,602 $4,845 $14,757 $15,574 $2,474 $13,100 
Property, plant, and equipment - natural gas$697,812 $311,898 $385,914 $679,502 $303,193 $376,309 
Construction work in progress2,710 1,730 980 2,959 1,085 1,874 
Less - accumulated depreciation and amortization(283,404)(141,818)(141,586)(276,388)(139,556)(136,832)
Other regulatory assets33,523 6,936 23,667 35,381 8,947 23,682 
Goodwill (a)6,517 — — 6,474 — — 
Pension and other postretirement assets15,171 — 19,952 14,663 — 19,499 
Other199 — 199 206 — 206 
Total non-current assets held for sale$472,528 $178,746 $289,126 $462,797 $173,669 $284,738 
Accounts payable$2,945 $295 $2,650 $702 $702 $— 
Customer deposits5,327 2,572 2,755 6,214 1,984 4,230 
Taxes accrued— — — 13 13 — 
Other1,352 536 816 1,401 589 812 
Total current liabilities held for sale (b)
$9,624 $3,403 $6,221 $8,330 $3,288 $5,042 
Regulatory liability for income taxes - net$28,438 $3,193 $25,245 $31,575 $4,981 $26,594 
Other regulatory liabilities2,579 945 1,634 1,611 1,214 397 
Pension and other postretirement liabilities4,236 4,643 1,610 3,976 4,525 1,197 
Other4,146 1,414 2,732 3,844 1,194 2,650 
Total non-current liabilities held for sale (c)
$39,399 $10,195 $31,221 $41,006 $11,914 $30,838 
(a)    Goodwill was allocated to the natural gas distribution business based on its relative fair value compared to the retained portion of the reporting unit.
(b)    Included within other current liabilities on the respective consolidated balance sheets.
(c)    Included within other non-current liabilities on the respective consolidated balance sheets.
Schedule of Income (Loss) from Individually Significant Component Disposed of or Held-for-Sale [Table Text Block]
The pre-tax income for the Entergy Louisiana and Entergy New Orleans natural gas distribution businesses, excluding interest and corporate allocations, included in Entergy’s, Entergy Louisiana’s, and Entergy New Orleans’s consolidated income statements for the three and six months ended June 30, 2025 and 2024 is as follows:
Three Months EndedSix Months Ended
2025202420252024
(In Thousands)(In Thousands)
Entergy$9,484 $7,527 $31,500 $27,459 
Entergy Louisiana$2,272 $2,754 $12,047 $12,858 
Entergy New Orleans$7,212 $4,773 $19,453 $14,601 
v3.25.2
Commitments and Contingencies (Narrative) (Details)
$ in Millions
 1 Months Ended 6 Months Ended
Mar. 31, 2025
USD ($)
Oct. 31, 2024
USD ($)
Jun. 30, 2025
unit
MW
Minimum [Member]      
Commitments and Contingencies [Line Items]      
Generation Capacity | MW     400
Power island equipment      
Commitments and Contingencies [Line Items]      
Long-Term Purchase Commitment, Minimum Quantity Required | unit     15
Combustion turbine      
Commitments and Contingencies [Line Items]      
Long-Term Purchase Commitment, Minimum Quantity Required | unit     2
Palisades      
Commitments and Contingencies [Line Items]      
Litigation Settlement, Amount Awarded from Other Party   $ 7  
Proceeds from Legal Settlements $ 7    
Damages awarded for costs previously recorded as other operation and maintenance expenses   3  
Damages awarded for costs previously recorded as plant   $ 4  
v3.25.2
Rate And Regulatory Matters (Narrative - All Other) (Details)
 1 Months Ended 2 Months Ended 3 Months Ended 6 Months Ended 12 Months Ended 24 Months Ended
Jul. 31, 2025
USD ($)
Jun. 30, 2025
USD ($)
May 31, 2025
USD ($)
Apr. 30, 2025
USD ($)
Feb. 28, 2025
USD ($)
Dec. 31, 2024
USD ($)
Oct. 31, 2024
USD ($)
MW
kV
Aug. 31, 2024
Jul. 31, 2024
USD ($)
Jul. 31, 2020
USD ($)
Dec. 31, 2018
USD ($)
Oct. 31, 2025
USD ($)
Jun. 30, 2025
USD ($)
Sep. 30, 2024
USD ($)
Jun. 30, 2024
USD ($)
Mar. 31, 2024
USD ($)
Jun. 30, 2025
USD ($)
Dec. 31, 2024
USD ($)
Jun. 30, 2024
USD ($)
Dec. 31, 2026
USD ($)
Mar. 31, 2026
USD ($)
Dec. 31, 2025
USD ($)
Mar. 31, 2025
USD ($)
Dec. 31, 2024
USD ($)
Mar. 31, 2024
USD ($)
Jan. 01, 2025
Dec. 31, 2023
USD ($)
Apr. 30, 2023
USD ($)
Regulatory Liability, Noncurrent   $ 3,659,163,000       $ 3,609,463,000             $ 3,659,163,000       $ 3,659,163,000 $ 3,609,463,000           $ 3,609,463,000        
Regulatory Asset, Noncurrent   5,082,842,000       5,255,509,000             5,082,842,000       5,082,842,000 5,255,509,000           5,255,509,000        
Asset Impairment Charges                         0   $ 0   0   $ 131,775,000                  
Increase (Decrease) in Deferred Fuel Costs                                 263,205,000   (134,953,000)                  
Deferred Fuel Cost   99,774,000       0             99,774,000       99,774,000 0           0        
Entergy Arkansas [Member]                                                        
Regulatory Liability, Noncurrent   889,400,000       831,165,000             889,400,000       889,400,000 831,165,000           831,165,000        
Regulatory Asset, Noncurrent   1,704,768,000       1,700,110,000             1,704,768,000       1,704,768,000 1,700,110,000           1,700,110,000        
Payments for Legal Settlements                     $ 135,000,000                                  
Refund to customers, plus interest, associated with recalculated bandwidth remedy                   $ 13,700,000                                    
Asset Impairment Charges                         0   $ 0   0   131,775,000                  
Increase (Decrease) in Deferred Fuel Costs                                 33,234,000   (2,317,000)                  
Entergy Arkansas [Member] | Opportunity Sales [Member]                                                        
Regulatory Asset, Noncurrent                                                     $ 131,800,000  
Asset Impairment Charges                               $ 131,800,000                        
Asset Impairment Charges, net of tax                               99,100,000                        
Entergy Louisiana [Member]                                                        
Regulatory Liability, Noncurrent   1,640,771,000       1,692,547,000             1,640,771,000       1,640,771,000 1,692,547,000           1,692,547,000        
Regulatory Asset, Noncurrent   1,591,621,000       1,637,967,000             1,591,621,000       1,591,621,000 1,637,967,000           1,637,967,000        
Increase (Decrease) in Deferred Fuel Costs                                 92,390,000   (11,364,000)                  
Deferred Fuel Cost   84,372,000       0             84,372,000       84,372,000 0           0        
Amount transfer from restricted escrow account as storm damage reserve         $ 33,500,000                                              
Entergy Louisiana [Member] | Hurricane Francine                                                        
Total Restoration Costs For Repair and Replacement of Electrical System           183,600,000                                            
Carrying costs associated with storm restoration costs           3,600,000                                            
Exception to restoration costs to be recovered - carrying costs   1,800,000                                                    
Exception to restoration costs to be recovered - estimated invoices and incentive compensation   10,600,000                                                    
Entergy Louisiana [Member] | Deferred COVID-19 costs                                                        
Regulatory Asset, Noncurrent           47,800,000                       47,800,000           47,800,000        
Entergy Louisiana [Member] | Shorter-term financing interest earnings                                                        
Regulatory Liability, Noncurrent   48,900,000                     48,900,000       48,900,000                      
Entergy Mississippi [Member]                                                        
Regulatory Liability, Noncurrent   63,582,000       59,544,000             63,582,000       63,582,000 59,544,000           59,544,000        
Regulatory Asset, Noncurrent   473,715,000       525,847,000             473,715,000       473,715,000 525,847,000           525,847,000        
Increase (Decrease) in Deferred Fuel Costs                                 64,303,000   (41,104,000)                  
Entergy New Orleans [Member]                                                        
Regulatory Liability, Noncurrent   245,127,000       260,312,000             245,127,000       245,127,000 260,312,000           260,312,000        
Regulatory Asset, Noncurrent   122,938,000       133,261,000             122,938,000       122,938,000 133,261,000           133,261,000        
Increase (Decrease) in Deferred Fuel Costs                                 4,203,000   51,000                  
Deferred Fuel Cost   5,599,000       0             5,599,000       5,599,000 0           0        
Entergy Texas [Member]                                                        
Regulatory Liability, Noncurrent   17,790,000       18,705,000             17,790,000       17,790,000 18,705,000           18,705,000        
Regulatory Asset, Noncurrent   489,583,000       549,708,000             489,583,000       489,583,000 549,708,000           549,708,000        
Increase (Decrease) in Deferred Fuel Costs                                 69,075,000   $ (80,220,000)                  
Deferred Fuel Cost   9,804,000       $ 0             $ 9,804,000       9,804,000 $ 0           $ 0        
Energy Cost Recovery Rider [Member] | Entergy Arkansas [Member]                                                        
Energy Cost Recovery Rider Rate Per kWh       $ 0.01333                                     $ 0.00882          
Energy Cost Recovery Rider [Member] | Entergy Arkansas [Member] | Subsequent Event [Member]                                                        
Requested Energy Cost Recovery Rider Rate Per kWh                                         $ 0.01333              
2024 Formula Rate Plan Filing [Member] | Entergy Louisiana [Member]                                                        
Public Utilities, Requested Return on Equity, Percentage     9.70%                                                  
Basis points bandwidth above and below midpoint return on common equity     40                                                  
Earned return on common equity     9.98%                                                  
Public Utilities, Approved Rate Increase (Decrease), Amount     $ 2,000,000                                                  
State Effective Income Tax Rate, Percent           7.50%                       7.50%           7.50%   5.50%    
2024 Formula Rate Plan Filing [Member] | Entergy Louisiana [Member] | Subsequent Event [Member]                                                        
Customer credit for ROE above allowed ROE                       $ 31,900,000                                
Grand Gulf Credit Rider [Member] | Entergy Arkansas [Member]                                                        
Refund to retail customers                 $ 100,600,000         $ 92,300,000                            
2023 Entergy Louisiana Rate Case and Formula Rate Plan Extension Request | Entergy Louisiana [Member] | Hurricane Francine                                                        
Public Utilities, Interim Rate Increase (Decrease), Amount         17,800,000                                              
2023 Entergy Louisiana Rate Case and Formula Rate Plan Extension Request | Entergy Louisiana [Member] | System Energy Settlement with the LPSC                                                        
Public Utilities, Interim Rate Increase (Decrease), Amount           $ 25,100,000                                            
Distribution Cost Recovery Factor Rider [Member] | Entergy Texas [Member]                                                        
Public Utilities, Requested Rate Increase (Decrease), Amount       77,800,000                                                
Incremental annual revenues       29,300,000                                                
Transmission Cost Recovery Factor Rider | Entergy Texas [Member]                                                        
Public Utilities, Requested Rate Increase (Decrease), Amount             $ 9,700,000                                          
2023 Formula Rate Plan Filing | Entergy Louisiana [Member]                                                        
Public Utilities, Requested Return on Equity, Percentage               9.70%                                        
Basis points bandwidth above and below midpoint return on common equity               40                                        
2023 Formula Rate Plan Filing | Entergy Louisiana [Member] | Hurricane Francine                                                        
Public Utilities, Interim Rate Increase (Decrease), Amount         $ 17,800,000                                              
2025 Formula Rate Plan Filing | Entergy Arkansas [Member]                                                        
Netting Adjustment                                               $ 48,800,000        
Earned return on common equity                                               7.71%        
2025 Formula Rate Plan Filing | Entergy Arkansas [Member] | Subsequent Event [Member]                                                        
Public Utilities, Requested Rate Increase (Decrease), Amount $ 117,700,000                                                      
Projected Revenue Deficiency                                       $ 68,900,000                
Annual revenue constraint per rate class percentage 4.00%                                                      
Earned return on common equity                                       8.45%                
2025 Formula Rate Plan Filing | Entergy Arkansas [Member] | Subsequent Event [Member] | Maximum [Member]                                                        
Public Utilities, Requested Rate Increase (Decrease), Amount $ 92,300,000                                                      
2025 Formula Rate Plan Filing | Entergy Mississippi [Member]                                                        
Public Utilities, Requested Return on Equity, Percentage         7.64%                                              
Public Utilities, Requested Rate Increase (Decrease), Amount   $ 0     $ 0                                     $ 0        
Public Utilities, Interim Rate Increase (Decrease), Amount         $ 135,000                                              
Earned return on rate base   7.68%                                           7.55%        
2025 Formula Rate Plan Filing | Entergy New Orleans [Member]                                                        
Public Utilities, Requested Rate Increase (Decrease), Amount       $ 13,800,000                                                
Public Utilities, Approved Return on Equity, Percentage       9.35%                                                
Earned return on equity       10.98%                                                
Public Utilities, Requested Rate Increase (Decrease), Amount, Adjusted       $ 8,600,000                                                
2025 Formula Rate Plan Filing | Entergy New Orleans [Member] | Subsequent Event [Member]                                                        
Proposed formula rate plan rate mitigation through offsets to regulatory liabilities 4,400,000                                                      
Requested reduction to requested rate decrease 7,200,000                                                      
Proposed reduction in customer late fees $ 4,100,000                                                      
Additional generation and transmission resources | Entergy Louisiana [Member]                                                        
Measurement of electrical voltage for new transmission line | kV             500                                          
Measurement of electrical voltage for substation upgrades | kV             500                                          
Additional generation and transmission resources | Entergy Louisiana [Member] | Future additions contributed by customer                                                        
Generation Capacity | MW             1,500                                          
Additional generation and transmission resources | Entergy Louisiana [Member] | Three new combined cycle combustion turbine generation resources                                                        
Generation Capacity | MW             2,262                                          
Grand Gulf Sale-leaseback Renewal Complaint and Uncertain Tax Position Rate Base Issue [Member] | Entergy Mississippi [Member]                                                        
Allocated sale-leaseback annual renewal costs                                 $ 5,700,000                      
Fuel Reconciliation | Entergy Texas [Member]                                                        
Increase (Decrease) in Deferred Fuel Costs                                                 $ 1,600,000,000      
Deferred Fuel Cost                               $ 30,000,000                 $ 30,000,000      
Interim Facilities Rate Adjustments | Entergy Mississippi [Member]                                                        
Public Utilities, Interim Rate Increase (Decrease), Amount                                   $ 8,700,000                    
Interim Facilities Rate Adjustments | Entergy Mississippi [Member] | Subsequent Event [Member]                                                        
Public Utilities, Interim Rate Increase (Decrease), Amount                                         $ 1,000,000 $ 46,700,000            
Deferred COVID-19 costs | Entergy Louisiana [Member]                                                        
Low interest debt                                                       $ 1,600,000,000
v3.25.2
Equity (Narrative) (Details)
$ / shares in Units, $ in Thousands
 1 Months Ended 3 Months Ended 6 Months Ended
Jul. 25, 2025
$ / shares
May 15, 2024
shares
Mar. 15, 2024
shares
May 31, 2025
USD ($)
$ / shares
shares
Mar. 31, 2025
$ / shares
shares
Feb. 28, 2025
USD ($)
Dec. 31, 2024
Jun. 30, 2024
shares
May 31, 2024
shares
Mar. 31, 2024
shares
Dec. 31, 2023
shares
Jun. 30, 2025
USD ($)
$ / shares
shares
Mar. 31, 2025
USD ($)
shares
Jun. 30, 2024
USD ($)
$ / shares
shares
Mar. 31, 2024
USD ($)
Jun. 30, 2025
USD ($)
$ / shares
shares
Jun. 30, 2024
$ / shares
shares
Stock Issued During Period, Shares, Treasury Stock Reissued | shares                               1,268,179  
Common Stock, Dividends, Per Share, Declared | $ / shares                       $ 0.60   $ 0.57   $ 1.20 $ 1.13
Dividends, Common Stock, Cash | $                       $ 258,467 $ 258,249 $ 241,296 $ 240,959    
Stockholders' Equity Note, Stock Split, Conversion Ratio             2                    
Forward Contracts [Member]                                  
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount | shares                       2,423,880   2,897,964   1,304,889 2,942,440
Equity Distribution Program [Member]                                  
Forward Contract Indexed to Equity, Settlement, Cash, Amount | $                       $ 2,800,000       $ 2,800,000  
Equity Distribution Sales Agreement, Maximum Aggregate Gross Sales Price | $                       $ 4,500,000       $ 4,500,000  
Equity Distribution Sales Agreement, Increase in Maximum Aggregate Gross Sales Price | $           $ 1,500,000                      
Common Stock [Member] | Equity Distribution Program [Member]                                  
Forward Contract Indexed to Equity, Settlement, Cash, Amount | $       $ 805,669                          
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share | $ / shares       $ 51.78 $ 84.77                        
Stock Issued During Period, Shares, New Issues | shares                               0 0
Forward Contract Indexed to Issuer's Equity, Shares | shares   2,556,832 569,844   2,713,790     2,140,006 2,466,470 2,320,830 5,506,492            
Forward Contract Indexed to Equity, Settlement, Number of Shares | shares       15,560,474                          
Payments of Stock Issuance Costs | $       $ 1,000                          
Common Stock [Member] | Equity Offering                                  
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share | $ / shares         $ 81.87                        
Forward Contract Indexed to Issuer's Equity, Shares | shares         17,800,000                        
Forward Contract Indexed to Equity, Settlement, Number of Shares | shares         200,000               200,000        
System Energy [Member]                                  
Dividends, Common Stock, Cash | $       $ 30,000   $ 20,000                      
Subsequent Event [Member]                                  
Common Stock, Dividends, Per Share, Declared | $ / shares $ 0.60                                
v3.25.2
Equity (Schedule Of Earnings Per Share, Basic And Diluted) (Details) - USD ($)
$ / shares in Units, $ in Thousands
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Mar. 31, 2025
Jun. 30, 2024
Mar. 31, 2024
Jun. 30, 2025
Jun. 30, 2024
Weighted Average Number of Shares Outstanding, Basic 439,182,369   427,234,219   434,789,473 426,760,829
Earnings Per Share, Basic $ 1.07   $ 0.11   $ 1.91 $ 0.29
Average Dilutive Effect Of Equity Forwards Per Share $ (0.02)   $ 0   $ (0.03) $ 0
Incremental Common Shares Attributable to Dilutive Effect of Equity Forward Agreements 4,400,000   0   6,300,000 0
Weighted Average Number of Shares Outstanding, Diluted 445,700,889   428,753,441   443,446,875 428,311,535
Earnings Per Share, Diluted $ 1.05   $ 0.11   $ 1.87 $ 0.29
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest $ 471,954 $ 362,422 $ 51,732 $ 76,536 $ 834,376 $ 128,268
Preferred dividend requirements of subsidiaries and net income (loss) attributable to noncontrolling interests 4,024   2,810   5,686 4,065
Net Income (Loss) Available to Common Stockholders, Basic $ 467,930   $ 48,922   $ 828,690 $ 124,203
Employee Stock Option            
Average Dilutive Effect Of Stock Options Per Share $ 0   $ 0   $ 0 $ 0
Incremental Common Shares Attributable to Dilutive Effect of Share-Based Payment Arrangements 900,000   600,000   1,000,000.0 500,000
Restricted Stock [Member]            
Incremental Common Shares Attributable to Dilutive Effect of Share-Based Payment Arrangements 1,200,000   1,000,000.0   1,300,000 1,000,000.0
Average Dilutive Effect Of Restricted Stock Per Share $ 0   $ 0   $ (0.01) $ 0
Employee Stock Option            
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount 366,136   1,448,982   305,113 1,471,220
Forward Contracts [Member]            
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount 2,423,880   2,897,964   1,304,889 2,942,440
v3.25.2
Equity (Schedule of Accumulated Other Comprehensive Income (Loss)) (Details) - USD ($)
$ in Thousands
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Mar. 31, 2025
Jun. 30, 2024
Mar. 31, 2024
Jun. 30, 2025
Jun. 30, 2024
Dec. 31, 2024
Dec. 31, 2023
Accumulated Other Comprehensive Income (Loss) [Line Items]                
Accumulated Other Comprehensive Income (Loss), Net of Tax $ 34,438 $ 39,040 $ 80,361 $ (166,128) $ 34,438 $ 80,361 $ 42,769 $ (162,460)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax (4,602)   246,489   (8,331) 242,821    
Other Comprehensive Income (Loss), Net of Tax (4,602) (3,729) 246,489 (3,668) (8,331) 242,821    
Entergy Louisiana [Member]                
Accumulated Other Comprehensive Income (Loss) [Line Items]                
Accumulated Other Comprehensive Income (Loss), Net of Tax 50,555 52,687 50,751 52,774 50,555 50,751 $ 53,658 $ 54,798
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax (2,132)   (2,023)   (3,103) (4,047)    
Other Comprehensive Income (Loss), Net of Tax $ (2,132) $ (971) $ (2,023) $ (2,024) $ (3,103) $ (4,047)    
v3.25.2
Equity (Schedule of Reclassification out of Accumulated Other Comprehensive Income) (Details) - USD ($)
$ in Thousands
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Mar. 31, 2025
Jun. 30, 2024
Mar. 31, 2024
Jun. 30, 2025
Jun. 30, 2024
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]            
Other Nonoperating Income (Expense) $ (43,722)   $ (342,549)   $ (28,996) $ (393,294)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax 2,551   1,641   5,102 3,037
Income Tax Expense (Benefit) (138,399)   (33,634)   (238,440) (54,627)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax 4,602   (246,489)   8,331 (242,821)
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest 471,954 $ 362,422 51,732 $ 76,536 834,376 128,268
Reclassification out of Accumulated Other Comprehensive Income [Member]            
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]            
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax 4,602   (246,489)   8,331 (242,821)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Pension and other postretirement plans [Member]            
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]            
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) 3,462   3,473   6,924 6,946
Defined Benefit Plan, Amortization of Gain (Loss) 2,551   1,641   5,102 3,037
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement 0   (316,974)   0 (316,974)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax 6,013   (311,860)   12,026 (306,991)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, Tax 1,411   (65,371)   3,695 (64,170)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax 4,602   (246,489)   8,331 (242,821)
Entergy Louisiana [Member]            
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]            
Other Nonoperating Income (Expense) (33,797)   (20,646)   (16,726) (67,821)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax 1,719   1,632   3,438 3,266
Income Tax Expense (Benefit) (72,541)   (20,750)   (126,603) (59,674)
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax 2,132   2,023   3,103 4,047
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest 300,180 $ 254,197 131,114 $ 182,723 554,377 313,837
Entergy Louisiana [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Pension and other postretirement plans [Member]            
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]            
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) 1,136   1,136   2,272 2,272
Defined Benefit Plan, Amortization of Gain (Loss) 1,719   1,632   3,438 3,266
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax 2,855   2,768   5,710 5,538
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, Tax 723   745   2,607 1,491
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, after Tax 2,132   2,023   3,103 4,047
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax $ 2,132   $ 2,023   $ 3,103 $ 4,047
v3.25.2
Equity (Schedule of Forward Sales Agreements) (Details) - Equity Distribution Program [Member] - USD ($)
$ / shares in Units, $ in Thousands
 1 Months Ended
May 15, 2024
Mar. 15, 2024
May 31, 2025
Mar. 31, 2025
Jun. 30, 2024
May 31, 2024
Mar. 31, 2024
Dec. 31, 2023
Jun. 30, 2025
Forward Contract Indexed to Equity, Settlement, Cash, Amount                 $ 2,800,000
Common Stock [Member]                  
Forward Contract Indexed to Issuer's Equity, Shares 2,556,832 569,844   2,713,790 2,140,006 2,466,470 2,320,830 5,506,492  
Forward Sale Agreement, Gross Sales Price $ 142,387 $ 29,318   $ 232,216 $ 114,540 $ 134,396 $ 119,153 $ 280,459  
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share     $ 51.78 $ 84.77          
Forward Sale Agreement, Forward Sellers Fees $ 1,424 $ 293   $ 2,322 $ 1,145 $ 1,344 $ 1,192 $ 2,805  
Forward Contract Indexed to Equity, Settlement, Cash, Amount     $ 805,669            
Forward Contract Indexed to Equity, Settlement, Number of Shares     15,560,474            
v3.25.2
Equity (Schedule of Forward Sales Agreements Settled) (Details) - Equity Distribution Program [Member] - USD ($)
$ / shares in Units, $ in Thousands
 1 Months Ended
May 15, 2024
Mar. 15, 2024
May 31, 2025
Mar. 31, 2025
Jun. 30, 2024
May 31, 2024
Mar. 31, 2024
Dec. 31, 2023
Jun. 30, 2025
Forward Contract Indexed to Equity, Settlement, Cash, Amount                 $ 2,800,000
Common Stock [Member]                  
Forward Contract Indexed to Issuer's Equity, Shares 2,556,832 569,844   2,713,790 2,140,006 2,466,470 2,320,830 5,506,492  
Forward Sale Agreement, Gross Sales Price $ 142,387 $ 29,318   $ 232,216 $ 114,540 $ 134,396 $ 119,153 $ 280,459  
Forward Sale Agreement, Forward Sellers Fees $ 1,424 $ 293   $ 2,322 $ 1,145 $ 1,344 $ 1,192 $ 2,805  
Forward Contract Indexed to Equity, Settlement, Number of Shares     15,560,474            
Forward Contract Indexed to Issuer's Equity, Forward Rate Per Share     $ 51.78 $ 84.77          
Forward Contract Indexed to Equity, Settlement, Cash, Amount     $ 805,669            
v3.25.2
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Narrative) (Details) - USD ($)
 1 Months Ended 6 Months Ended
Jul. 31, 2025
May 31, 2025
Mar. 31, 2025
Feb. 28, 2025
Jan. 31, 2025
Jun. 30, 2025
Jan. 02, 2025
Commercial Paper [Member]              
Debt Instrument [Line Items]              
Debt, Weighted Average Interest Rate           4.65%  
Commercial Paper program limit           $ 2,000,000,000  
Commercial Paper           459,000,000  
Entergy Arkansas [Member]              
Debt Instrument [Line Items]              
Authorized Short Term Borrowings           250,000,000  
Entergy Arkansas [Member] | 5.45% Series mortgage bonds due June 2034              
Debt Instrument [Line Items]              
Proceeds from Issuance of Debt   $ 300,000,000          
Debt Instrument, Interest Rate, Stated Percentage   5.45%          
Entergy Louisiana [Member]              
Debt Instrument [Line Items]              
Authorized Short Term Borrowings           450,000,000  
Entergy Louisiana [Member] | 5.80% Series mortgage bonds due March 2055              
Debt Instrument [Line Items]              
Proceeds from Issuance of Debt         $ 750,000,000    
Debt Instrument, Interest Rate, Stated Percentage             5.80%
Entergy Louisiana [Member] | 3.78% Series mortgage bonds due April 2025 (Legacy)              
Debt Instrument [Line Items]              
Debt Instrument, Interest Rate, Stated Percentage     3.78%        
Repayments of Debt     $ 190,000,000        
Entergy Louisiana [Member] | 3.78% Series mortgage bonds due April 2025              
Debt Instrument [Line Items]              
Debt Instrument, Interest Rate, Stated Percentage     3.78%        
Repayments of Debt     $ 110,000,000        
Entergy Mississippi [Member]              
Debt Instrument [Line Items]              
Authorized Short Term Borrowings           200,000,000  
Entergy Mississippi [Member] | 5.80% Series mortgage bonds due April 2055              
Debt Instrument [Line Items]              
Proceeds from Issuance of Debt     $ 600,000,000        
Debt Instrument, Interest Rate, Stated Percentage     5.80%        
Entergy Texas [Member]              
Debt Instrument [Line Items]              
Authorized Short Term Borrowings           200,000,000  
Entergy Texas [Member] | 5.25% Series mortgage bonds due April 2035              
Debt Instrument [Line Items]              
Proceeds from Issuance of Debt       $ 500,000,000      
Debt Instrument, Interest Rate, Stated Percentage       5.25%      
System Energy [Member]              
Debt Instrument [Line Items]              
Authorized Short Term Borrowings           200,000,000  
System Energy [Member] | 5.30% Series mortgage bonds due December 2034              
Debt Instrument [Line Items]              
Proceeds from Issuance of Debt   $ 240,000,000          
Debt Instrument, Interest Rate, Stated Percentage   5.30%          
System Energy [Member] | 2.14% Series mortgage bonds due December 2025              
Debt Instrument [Line Items]              
Debt Instrument, Interest Rate, Stated Percentage   2.14%          
Repayments of Debt   $ 200,000,000          
Entergy New Orleans [Member]              
Debt Instrument [Line Items]              
Authorized Short Term Borrowings           $ 150,000,000  
Entergy New Orleans [Member] | 3.0% Series mortgage bonds due March 2025              
Debt Instrument [Line Items]              
Debt Instrument, Interest Rate, Stated Percentage     3.00%        
Repayments of Debt     $ 78,000,000        
Entergy New Orleans [Member] | Unsecured term loan due March 2026              
Debt Instrument [Line Items]              
Debt, Weighted Average Interest Rate     5.79%        
Proceeds from Issuance of Debt       $ 80,000,000      
System Energy VIE [Member]              
Debt Instrument [Line Items]              
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage           0.10%  
Entergy Arkansas VIE [Member]              
Debt Instrument [Line Items]              
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage           0.10%  
Entergy Louisiana Waterford VIE [Member]              
Debt Instrument [Line Items]              
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage           0.10%  
Entergy Louisiana River Bend VIE [Member]              
Debt Instrument [Line Items]              
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage           0.10%  
Maximum [Member] | Entergy Arkansas [Member]              
Debt Instrument [Line Items]              
Line of Credit Facility, Commitment Fee Percentage           0.375%  
Ratio of Indebtedness to Net Capital           0.65  
Consolidated debt ratio of lessees total capitalization           70.00%  
Maximum [Member] | Entergy Louisiana [Member]              
Debt Instrument [Line Items]              
Line of Credit Facility, Commitment Fee Percentage           0.375%  
Ratio of Indebtedness to Net Capital           0.65  
Consolidated debt ratio of lessees total capitalization           70.00%  
Maximum [Member] | Entergy Mississippi [Member]              
Debt Instrument [Line Items]              
Line of Credit Facility, Commitment Fee Percentage           0.375%  
Ratio of Indebtedness to Net Capital           0.65  
Maximum [Member] | Entergy Texas [Member]              
Debt Instrument [Line Items]              
Line of Credit Facility, Commitment Fee Percentage           0.375%  
Ratio of Indebtedness to Net Capital           0.65  
Maximum [Member] | System Energy [Member]              
Debt Instrument [Line Items]              
Ratio of Indebtedness to Net Capital           0.65  
Consolidated debt ratio of lessees total capitalization           70.00%  
Maximum [Member] | Entergy New Orleans [Member]              
Debt Instrument [Line Items]              
Line of Credit Facility, Commitment Fee Percentage           0.375%  
Ratio of Indebtedness to Net Capital           0.65  
Minimum [Member] | Entergy Arkansas [Member]              
Debt Instrument [Line Items]              
Line of Credit Facility, Commitment Fee Percentage           0.075%  
Minimum [Member] | Entergy Louisiana [Member]              
Debt Instrument [Line Items]              
Line of Credit Facility, Commitment Fee Percentage           0.075%  
Minimum [Member] | Entergy Mississippi [Member]              
Debt Instrument [Line Items]              
Line of Credit Facility, Commitment Fee Percentage           0.075%  
Minimum [Member] | Entergy Texas [Member]              
Debt Instrument [Line Items]              
Line of Credit Facility, Commitment Fee Percentage           0.075%  
Minimum [Member] | Entergy New Orleans [Member]              
Debt Instrument [Line Items]              
Line of Credit Facility, Commitment Fee Percentage           0.075%  
Credit Facility of $3 Billion              
Debt Instrument [Line Items]              
Line of Credit Facility, Maximum Borrowing Capacity           $ 3,000,000,000  
Letters of Credit Outstanding, Amount           $ 4,000,000  
Line of Credit Facility, Commitment Fee Percentage           0.225%  
Long-Term Line of Credit           $ 0  
Line of Credit Facility, Remaining Borrowing Capacity           2,996,000,000  
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit           $ 20,000,000  
Line of Credit Facility, Interest Rate at Period End           5.93%  
Credit Facility of $3 Billion | Maximum [Member]              
Debt Instrument [Line Items]              
Ratio of Indebtedness to Net Capital           0.65  
Uncommitted Credit Facility of $160 Million | Subsequent Event [Member] | Entergy Texas [Member]              
Debt Instrument [Line Items]              
Line of Credit Facility, Maximum Borrowing Capacity $ 160,000,000            
Line of Credit Facility, Commitment Fee Percentage 1.05%            
v3.25.2
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Schedule of Line of Credit Facilities) (Details)
 6 Months Ended
Jun. 30, 2025
USD ($)
Credit Facility of $3 Billion  
Line of Credit Facility, Maximum Borrowing Capacity $ 3,000,000,000
Long-Term Line of Credit 0
Letters of Credit Outstanding, Amount $ 4,000,000
Line of Credit Facility, Interest Rate at Period End 5.93%
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit $ 20,000,000
Line of Credit Facility, Commitment Fee Percentage 0.225%
Line of Credit Facility, Remaining Borrowing Capacity $ 2,996,000,000
Entergy Arkansas [Member] | Credit Facility of $25 Million [Member]  
Line of Credit Facility, Maximum Borrowing Capacity 25,000,000
Long-Term Line of Credit 0
Letters of Credit Outstanding, Amount $ 0
Line of Credit Facility, Interest Rate at Period End 6.28%
Entergy Arkansas [Member] | Credit Facility of $300 Million  
Line of Credit Facility, Maximum Borrowing Capacity $ 300,000,000
Long-Term Line of Credit 0
Letters of Credit Outstanding, Amount $ 0
Line of Credit Facility, Interest Rate at Period End 5.55%
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit $ 5,000,000
Entergy Louisiana [Member] | Credit Facility of $400 Million  
Line of Credit Facility, Maximum Borrowing Capacity 400,000,000
Long-Term Line of Credit 0
Letters of Credit Outstanding, Amount $ 0
Line of Credit Facility, Interest Rate at Period End 5.68%
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit $ 15,000,000
Entergy Mississippi [Member] | Credit Facility of $300 Million  
Line of Credit Facility, Maximum Borrowing Capacity 300,000,000
Long-Term Line of Credit 0
Letters of Credit Outstanding, Amount $ 0
Line of Credit Facility, Interest Rate at Period End 5.55%
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit $ 5,000,000
Entergy New Orleans [Member] | Credit Facility of $25 Million [Member]  
Line of Credit Facility, Maximum Borrowing Capacity 25,000,000
Long-Term Line of Credit 0
Letters of Credit Outstanding, Amount $ 0
Line of Credit Facility, Interest Rate at Period End 6.05%
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit $ 10,000,000
Entergy Texas [Member] | Credit Facility of $300 Million  
Line of Credit Facility, Maximum Borrowing Capacity 300,000,000
Long-Term Line of Credit 0
Letters of Credit Outstanding, Amount $ 1,100,000
Line of Credit Facility, Interest Rate at Period End 5.68%
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit $ 25,000,000
Maximum [Member] | Entergy Arkansas [Member]  
Line of Credit Facility, Commitment Fee Percentage 0.375%
Maximum [Member] | Entergy Louisiana [Member]  
Line of Credit Facility, Commitment Fee Percentage 0.375%
Maximum [Member] | Entergy Mississippi [Member]  
Line of Credit Facility, Commitment Fee Percentage 0.375%
Maximum [Member] | Entergy New Orleans [Member]  
Line of Credit Facility, Commitment Fee Percentage 0.375%
Maximum [Member] | Entergy Texas [Member]  
Line of Credit Facility, Commitment Fee Percentage 0.375%
Minimum [Member] | Entergy Arkansas [Member]  
Line of Credit Facility, Commitment Fee Percentage 0.075%
Minimum [Member] | Entergy Louisiana [Member]  
Line of Credit Facility, Commitment Fee Percentage 0.075%
Minimum [Member] | Entergy Mississippi [Member]  
Line of Credit Facility, Commitment Fee Percentage 0.075%
Minimum [Member] | Entergy New Orleans [Member]  
Line of Credit Facility, Commitment Fee Percentage 0.075%
Minimum [Member] | Entergy Texas [Member]  
Line of Credit Facility, Commitment Fee Percentage 0.075%
v3.25.2
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Schedule of uncommitted standby letter of credit facilities) (Details) - USD ($)
$ in Millions
 6 Months Ended
Jun. 30, 2025
Dec. 31, 2024
Financial transmission rights    
Letters of Credit Outstanding, Amount $ 6.0 $ 2.0
Entergy Arkansas [Member] | Financial transmission rights    
Letters of Credit Outstanding, Amount 3.5 0.5
Entergy Mississippi [Member] | Financial transmission rights    
Letters of Credit Outstanding, Amount 0.6 0.8
Entergy Louisiana [Member] | Financial transmission rights    
Letters of Credit Outstanding, Amount 1.2 0.1
Entergy New Orleans [Member] | Financial transmission rights    
Letters of Credit Outstanding, Amount   0.1
Entergy Texas [Member] | Financial transmission rights    
Letters of Credit Outstanding, Amount 0.6 $ 0.3
Credit Facility of $25 Million [Member] | Entergy Arkansas [Member]    
Line of Credit Facility, Maximum Borrowing Capacity 25.0  
Letters of Credit Outstanding, Amount 0.0  
Credit Facility of $25 Million [Member] | Entergy New Orleans [Member]    
Line of Credit Facility, Maximum Borrowing Capacity 25.0  
Letters of Credit Outstanding, Amount 0.0  
Uncommitted Credit Facility of $25 Million [Member] | Entergy Arkansas [Member]    
Line of Credit Facility, Maximum Borrowing Capacity $ 25.0  
Line of Credit Facility, Commitment Fee Percentage 0.78%  
Letters of Credit Outstanding, Amount $ 23.6  
Uncommitted Credit Facility of $25 Million [Member] | Entergy Arkansas [Member] | Financial Transmission Rights (FTRs) [Member]    
Letters of Credit Outstanding, Amount 3.5  
Uncommitted Credit Facility of $125 Million [Member] | Entergy Louisiana [Member]    
Line of Credit Facility, Maximum Borrowing Capacity $ 125.0  
Line of Credit Facility, Commitment Fee Percentage 0.78%  
Letters of Credit Outstanding, Amount $ 74.3  
Uncommitted Credit Facility of $125 Million [Member] | Entergy Louisiana [Member] | Financial Transmission Rights (FTRs) [Member]    
Letters of Credit Outstanding, Amount 1.2  
Uncommitted Credit Facility of $65 Million [Member] | Entergy Mississippi [Member] | Facility 1    
Line of Credit Facility, Maximum Borrowing Capacity $ 65.0  
Line of Credit Facility, Commitment Fee Percentage 0.78%  
Letters of Credit Outstanding, Amount $ 47.3  
Uncommitted Credit Facility of $65 Million [Member] | Entergy Mississippi [Member] | Facility 2    
Line of Credit Facility, Maximum Borrowing Capacity $ 65.0  
Line of Credit Facility, Commitment Fee Percentage 0.50%  
Letters of Credit Outstanding, Amount $ 0.0  
Uncommitted Credit Facility of $65 Million [Member] | Entergy Mississippi [Member] | Financial Transmission Rights (FTRs) [Member]    
Letters of Credit Outstanding, Amount 0.6  
Uncommitted Credit Facility of $65 Million [Member] | Entergy Mississippi [Member] | MISO [Member]    
Letters of Credit Outstanding, Amount 46.0  
Uncommitted Credit Facility of $65 Million [Member] | Entergy Mississippi [Member] | Non-MISO [Member]    
Letters of Credit Outstanding, Amount 1.3  
Uncommitted Credit Facility of $75 Million | Entergy Arkansas [Member]    
Line of Credit Facility, Maximum Borrowing Capacity $ 75.0  
Line of Credit Facility, Commitment Fee Percentage 0.50%  
Letters of Credit Outstanding, Amount $ 0.0  
Uncommitted Credit Facility of $45 Million | Entergy Louisiana [Member]    
Line of Credit Facility, Maximum Borrowing Capacity $ 45.0  
Line of Credit Facility, Commitment Fee Percentage 0.50%  
Letters of Credit Outstanding, Amount $ 0.0  
Uncommitted Credit Facility of $1 Million | Entergy New Orleans [Member]    
Line of Credit Facility, Maximum Borrowing Capacity $ 1.0  
Line of Credit Facility, Commitment Fee Percentage 1.625%  
Letters of Credit Outstanding, Amount $ 0.5  
Uncommitted Credit Facility of $150 Million | Entergy Texas [Member]    
Line of Credit Facility, Maximum Borrowing Capacity $ 150.0  
Line of Credit Facility, Commitment Fee Percentage 1.25%  
Letters of Credit Outstanding, Amount $ 54.0  
Uncommitted Credit Facility of $150 Million | Entergy Texas [Member] | Financial Transmission Rights (FTRs) [Member]    
Letters of Credit Outstanding, Amount $ 0.6  
Minimum [Member] | Entergy Arkansas [Member]    
Line of Credit Facility, Commitment Fee Percentage 0.075%  
Minimum [Member] | Entergy Mississippi [Member]    
Line of Credit Facility, Commitment Fee Percentage 0.075%  
Minimum [Member] | Entergy Louisiana [Member]    
Line of Credit Facility, Commitment Fee Percentage 0.075%  
Minimum [Member] | Entergy New Orleans [Member]    
Line of Credit Facility, Commitment Fee Percentage 0.075%  
Minimum [Member] | Entergy Texas [Member]    
Line of Credit Facility, Commitment Fee Percentage 0.075%  
Maximum [Member] | Entergy Arkansas [Member]    
Line of Credit Facility, Commitment Fee Percentage 0.375%  
Maximum [Member] | Entergy Mississippi [Member]    
Line of Credit Facility, Commitment Fee Percentage 0.375%  
Maximum [Member] | Entergy Louisiana [Member]    
Line of Credit Facility, Commitment Fee Percentage 0.375%  
Maximum [Member] | Entergy New Orleans [Member]    
Line of Credit Facility, Commitment Fee Percentage 0.375%  
Maximum [Member] | Entergy Texas [Member]    
Line of Credit Facility, Commitment Fee Percentage 0.375%  
v3.25.2
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Schedule of Short-Term Debt) (Details)
$ in Millions
Jun. 30, 2025
USD ($)
Entergy Arkansas [Member]  
Short Term Borrowings And The Outstanding Short Term Borrowings Abstract  
Authorized Short Term Borrowings $ 250
Short term borrowings, outstanding 0
Entergy Arkansas [Member] | Credit Facility of $300 Million  
Short Term Borrowings And The Outstanding Short Term Borrowings Abstract  
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit 5
Entergy Louisiana [Member]  
Short Term Borrowings And The Outstanding Short Term Borrowings Abstract  
Authorized Short Term Borrowings 450
Short term borrowings, outstanding 0
Entergy Mississippi [Member]  
Short Term Borrowings And The Outstanding Short Term Borrowings Abstract  
Authorized Short Term Borrowings 200
Short term borrowings, outstanding 0
Entergy Mississippi [Member] | Credit Facility of $300 Million  
Short Term Borrowings And The Outstanding Short Term Borrowings Abstract  
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit 5
Entergy New Orleans [Member]  
Short Term Borrowings And The Outstanding Short Term Borrowings Abstract  
Authorized Short Term Borrowings 150
Short term borrowings, outstanding 21
Entergy Texas [Member]  
Short Term Borrowings And The Outstanding Short Term Borrowings Abstract  
Authorized Short Term Borrowings 200
Short term borrowings, outstanding 0
Entergy Texas [Member] | Credit Facility of $300 Million  
Short Term Borrowings And The Outstanding Short Term Borrowings Abstract  
Amount of total borrowing capacity against which fronting commitments exist for the issuance of letters of credit 25
System Energy [Member]  
Short Term Borrowings And The Outstanding Short Term Borrowings Abstract  
Authorized Short Term Borrowings 200
Short term borrowings, outstanding $ 0
v3.25.2
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Schedule of nuclear fuel company VIE credit facilities) (Details)
$ in Millions
 6 Months Ended
Jun. 30, 2025
USD ($)
Entergy Arkansas VIE [Member]  
Schedule of nuclear fuel company VIE credit facilities [Abstract]  
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage 0.10%
Entergy Arkansas VIE [Member] | Credit Facility of $80 Million [Member]  
Schedule of nuclear fuel company VIE credit facilities [Abstract]  
Line of Credit Facility, Current Borrowing Capacity $ 80.0
Line of Credit Facility, Interest Rate During Period 5.44%
Long-Term Line of Credit $ 33.2
System Energy VIE [Member]  
Schedule of nuclear fuel company VIE credit facilities [Abstract]  
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage 0.10%
System Energy VIE [Member] | Credit Facility of $120 Million [Member]  
Schedule of nuclear fuel company VIE credit facilities [Abstract]  
Line of Credit Facility, Current Borrowing Capacity $ 120.0
Line of Credit Facility, Interest Rate During Period 5.43%
Long-Term Line of Credit $ 44.3
Entergy Louisiana River Bend VIE [Member]  
Schedule of nuclear fuel company VIE credit facilities [Abstract]  
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage 0.10%
Entergy Louisiana River Bend VIE [Member] | Credit Facility of $105 Million [Member]  
Schedule of nuclear fuel company VIE credit facilities [Abstract]  
Line of Credit Facility, Current Borrowing Capacity $ 105.0
Line of Credit Facility, Interest Rate During Period 5.42%
Long-Term Line of Credit $ 69.5
Entergy Louisiana Waterford VIE [Member]  
Schedule of nuclear fuel company VIE credit facilities [Abstract]  
Line of Credit Facility, Unused Capacity, Commitment Fee Percentage 0.10%
Entergy Louisiana Waterford VIE [Member] | Credit Facility of $105 Million [Member]  
Schedule of nuclear fuel company VIE credit facilities [Abstract]  
Line of Credit Facility, Current Borrowing Capacity $ 105.0
Line of Credit Facility, Interest Rate During Period 5.43%
Long-Term Line of Credit $ 61.0
v3.25.2
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Schedule of nuclear fuel company VIE notes payable) (Details)
$ in Millions
Jun. 30, 2025
USD ($)
VIE Notes Payable, 5.54% Series O due May 2029 [Member] | Entergy Arkansas VIE [Member]  
Notes Payable, Noncurrent [Abstract]  
Debt Instrument, Interest Rate, Stated Percentage 5.54%
Notes Payable, Noncurrent $ 70
VIE Notes Payable, 1.84% Series N due July 2026 [Member] | Entergy Arkansas VIE [Member]  
Notes Payable, Noncurrent [Abstract]  
Debt Instrument, Interest Rate, Stated Percentage 1.84%
Notes Payable, Noncurrent $ 90
VIE Notes Payable, 2.51% Series V Due June 2027 [Member] | Entergy Louisiana River Bend VIE [Member]  
Notes Payable, Noncurrent [Abstract]  
Debt Instrument, Interest Rate, Stated Percentage 2.51%
Notes Payable, Noncurrent $ 70
VIE Notes Payable, 5.94% Series J due September 2026 [Member] | Entergy Louisiana Waterford VIE [Member]  
Notes Payable, Noncurrent [Abstract]  
Debt Instrument, Interest Rate, Stated Percentage 5.94%
Notes Payable, Noncurrent $ 70
VIE Notes Payable, 2.05% Series K due September 2027 [Member] | System Energy VIE [Member]  
Notes Payable, Noncurrent [Abstract]  
Debt Instrument, Interest Rate, Stated Percentage 2.05%
Notes Payable, Noncurrent $ 90
v3.25.2
Revolving Credit Facilities, Lines Of Credit, Short-Term Borrowings, And Long-Term Debt (Schedule of Long-Term Debt Instruments) (Details) - USD ($)
$ in Thousands
Jun. 30, 2025
Dec. 31, 2024
Long-Term Debt, Fair Value $ 27,487,432 $ 25,181,802
Long-Term Debt 29,929,838 27,991,595
Entergy Arkansas [Member]    
Long-Term Debt, Fair Value 4,883,114 4,546,643
Long-Term Debt 5,438,033 5,122,494
Entergy Louisiana [Member]    
Long-Term Debt, Fair Value 9,410,962 8,751,266
Long-Term Debt 10,399,823 9,866,453
Entergy Mississippi [Member]    
Long-Term Debt, Fair Value 2,720,374 2,116,246
Long-Term Debt 3,020,687 2,427,073
Entergy New Orleans [Member]    
Long-Term Debt, Fair Value 697,241 697,466
Long-Term Debt 737,560 735,467
Entergy Texas [Member]    
Long-Term Debt, Fair Value 3,729,255 3,176,230
Long-Term Debt 4,038,417 3,552,443
System Energy [Member]    
Long-Term Debt, Fair Value 1,101,434 1,063,946
Long-Term Debt $ 1,094,396 $ 1,089,736
v3.25.2
Stock Based Compensation (Narrative) (Details) - USD ($)
 1 Months Ended 3 Months Ended 6 Months Ended
Feb. 06, 2025
May 31, 2025
Feb. 28, 2025
Jun. 30, 2025
Mar. 31, 2025
Jun. 30, 2024
Mar. 31, 2024
Jun. 30, 2025
Jun. 30, 2024
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]                  
Common Stock, Dividends, Per Share, Declared       $ 0.60   $ 0.57   $ 1.20 $ 1.13
Dividends, Common Stock, Cash       $ 258,467,000 $ 258,249,000 $ 241,296,000 $ 240,959,000    
System Energy [Member]                  
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]                  
Dividends, Common Stock, Cash   $ 30,000,000 $ 20,000,000            
Employee Stock Option                  
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]                  
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount       366,136   1,448,982   305,113 1,471,220
Forward Contracts [Member]                  
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]                  
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount       2,423,880   2,897,964   1,304,889 2,942,440
Equity Distribution Program [Member]                  
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]                  
Equity Distribution Sales Agreement, Increase in Maximum Aggregate Gross Sales Price     $ 1,500,000,000            
Employee Stock Option | 2019 Omnibus Incentive Plan [Member]                  
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]                  
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Grants in Period, Net of Forfeitures     366,136            
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Grants in Period, Weighted Average Grant Date Fair Value     $ 17.43            
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Outstanding, Number       3,132,728       3,132,728  
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Outstanding, Weighted Average Exercise Price       $ 56.71       $ 56.71  
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Vested and Expected to Vest, Outstanding, Aggregate Intrinsic Value       $ 78,600,000       $ 78,600,000  
Restricted Stock [Member] | 2019 Omnibus Incentive Plan [Member]                  
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]                  
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Grants in Period, Net of Forfeitures 510,009                
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value $ 82.79                
Long Term Performance Unit [Member] | 2019 Omnibus Incentive Plan [Member]                  
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]                  
Share-Based Compensation Arrangement by Share-Based Payment Award, Options, Grants in Period, Net of Forfeitures 187,036                
Percent of performance measure based on relative total shareholder return 80.00%             80.00%  
Percent of performance measure based on environmental achievement measure 20.00%             20.00%  
Long Term Performance Unit [Member] | Performance measure based on relative total shareholder return [Member]                  
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]                  
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value $ 115.13                
Long Term Performance Unit [Member] | Performance measure based on the environmental achievement measure [Member]                  
Share-Based Compensation Arrangement by Share-Based Payment Award [Line Items]                  
Share-Based Compensation Arrangement by Share-Based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value $ 82.79                
v3.25.2
Stock-Based Compensation (Schedule of Share-Based Payment Arrangement, Expensed and Capitalized, Amount) (Details) - USD ($)
$ in Millions
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Forward Contracts [Member]        
Share-Based Payment Arrangement, Additional Disclosure [Abstract]        
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount 2,423,880 2,897,964 1,304,889 2,942,440
Employee Stock Option        
Share-Based Payment Arrangement, Additional Disclosure [Abstract]        
Share-Based Payment Arrangement, Expense $ 1.0 $ 1.1 $ 2.1 $ 2.2
Share-Based Payment Arrangement, Expense, Tax Benefit 0.2 0.3 0.5 0.6
Share-Based Payment Arrangement, Amount Capitalized 0.5 0.5 1.0 1.0
Other Equity Awards [Member]        
Share-Based Payment Arrangement, Additional Disclosure [Abstract]        
Share-Based Payment Arrangement, Expense 9.4 9.8 19.4 19.7
Share-Based Payment Arrangement, Expense, Tax Benefit 2.3 2.5 4.8 5.0
Share-Based Payment Arrangement, Amount Capitalized $ 4.7 $ 4.6 $ 9.5 $ 9.1
v3.25.2
Retirement And Other Postretirement Benefits (Narrative) (Details) - Pension Plan [Member] - USD ($)
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Dec. 31, 2025
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Plan Assets, Contributions by Employer     $ 99,700,000    
Defined Benefit Plan, Expected Future Employer Contributions, Next Fiscal Year $ 240,000,000   240,000,000    
Nonqualified Plan          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) 2,500,000 $ 2,700,000 5,000,000 $ 5,400,000  
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement 0 0 0 0  
Entergy Arkansas [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Plan Assets, Contributions by Employer     16,968,000    
Entergy Arkansas [Member] | Nonqualified Plan          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Net Periodic Benefit Cost (Credit)     94,000 136,000  
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement 0 0 0 0  
Entergy Arkansas [Member] | Nonqualified Plan          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) 47,000 68,000      
Entergy Louisiana [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Plan Assets, Contributions by Employer     17,448,000    
Entergy Louisiana [Member] | Nonqualified Plan          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Net Periodic Benefit Cost (Credit)     72,000 102,000  
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement 0 0 0 0  
Entergy Louisiana [Member] | Nonqualified Plan          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) 36,000 51,000      
Entergy Mississippi [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Plan Assets, Contributions by Employer     3,951,000    
Entergy Mississippi [Member] | Nonqualified Plan          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Net Periodic Benefit Cost (Credit)     180,000 166,000  
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement 0 0 0 0  
Entergy Mississippi [Member] | Nonqualified Plan          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) 90,000 83,000      
Entergy New Orleans [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Plan Assets, Contributions by Employer     2,112,000    
Entergy New Orleans [Member] | Nonqualified Plan          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Net Periodic Benefit Cost (Credit)     70,000 61,000  
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement 0 0 0 0  
Entergy New Orleans [Member] | Nonqualified Plan          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) 35,000 31,000      
Entergy Texas [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Plan Assets, Contributions by Employer     3,240,000    
Entergy Texas [Member] | Nonqualified Plan          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Net Periodic Benefit Cost (Credit)     78,000 124,000  
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement 0 0 0 $ 0  
Entergy Texas [Member] | Nonqualified Plan          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) $ 39,000 $ 62,000      
System Energy [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Plan Assets, Contributions by Employer     $ 6,413,000    
Subsequent Event [Member] | Entergy Arkansas [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year         $ 18,576,000
Subsequent Event [Member] | Entergy Louisiana [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year         23,805,000
Subsequent Event [Member] | Entergy Mississippi [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year         4,113,000
Subsequent Event [Member] | Entergy New Orleans [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year         2,904,000
Subsequent Event [Member] | Entergy Texas [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year         4,485,000
Subsequent Event [Member] | System Energy [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year         $ 9,255,000
v3.25.2
Retirement And Other Postretirement Benefits (Schedule of Net Benefit Costs) (Details) - USD ($)
$ in Thousands
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Pension Plan [Member] | Qualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Service Cost $ 23,617 $ 23,370 $ 47,234 $ 46,746
Defined Benefit Plan, Interest Cost 59,680 65,961 119,360 136,587
Defined Benefit Plan, Expected Return (Loss) on Plan Assets (75,280) (89,506) (150,560) (185,486)
Defined Benefit Plan, Amortization of Gain (Loss) 13,309 14,854 26,618 29,974
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement 0 (325,253) 0 (325,253)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total 21,326 339,932 42,652 353,074
Pension Plan [Member] | Entergy Arkansas [Member] | Qualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Service Cost 4,427 4,100 8,854 8,199
Defined Benefit Plan, Interest Cost 13,814 13,217 27,628 26,434
Defined Benefit Plan, Expected Return (Loss) on Plan Assets (17,676) (18,155) (35,352) (36,310)
Defined Benefit Plan, Amortization of Gain (Loss) 4,791 5,746 9,582 11,492
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement   0   0
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total 5,356 4,908 10,712 9,815
Pension Plan [Member] | Entergy Arkansas [Member] | Nonqualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total 47 68    
Pension Plan [Member] | Entergy Louisiana [Member] | Qualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Service Cost 5,454 5,551 10,908 11,102
Defined Benefit Plan, Interest Cost 14,704 13,961 29,408 27,922
Defined Benefit Plan, Expected Return (Loss) on Plan Assets (18,897) (19,447) (37,794) (38,894)
Defined Benefit Plan, Amortization of Gain (Loss) 2,268 2,602 4,536 5,204
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement   0   0
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total 3,529 2,667 7,058 5,334
Pension Plan [Member] | Entergy Louisiana [Member] | Nonqualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total 36 51    
Pension Plan [Member] | Entergy Mississippi [Member] | Qualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Service Cost 1,304 1,284 2,608 2,568
Defined Benefit Plan, Interest Cost 3,699 3,521 7,398 7,042
Defined Benefit Plan, Expected Return (Loss) on Plan Assets (4,949) (5,113) (9,898) (10,226)
Defined Benefit Plan, Amortization of Gain (Loss) 822 1,140 1,644 2,280
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement   0   0
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total 876 832 1,752 1,664
Pension Plan [Member] | Entergy Mississippi [Member] | Nonqualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total 90 83    
Pension Plan [Member] | Entergy New Orleans [Member] | Qualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Service Cost 411 440 822 880
Defined Benefit Plan, Interest Cost 1,647 1,569 3,294 3,138
Defined Benefit Plan, Expected Return (Loss) on Plan Assets (2,174) (2,203) (4,348) (4,407)
Defined Benefit Plan, Amortization of Gain (Loss) 415 470 830 940
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement   0   0
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total 299 276 598 551
Pension Plan [Member] | Entergy New Orleans [Member] | Nonqualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total 35 31    
Pension Plan [Member] | Entergy Texas [Member] | Qualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Service Cost 1,024 962 2,048 1,923
Defined Benefit Plan, Interest Cost 2,973 2,831 5,946 5,662
Defined Benefit Plan, Expected Return (Loss) on Plan Assets (3,889) (4,077) (7,778) (8,154)
Defined Benefit Plan, Amortization of Gain (Loss) 454 393 908 786
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement   0   0
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total 562 109 1,124 217
Pension Plan [Member] | Entergy Texas [Member] | Nonqualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total 39 62    
Pension Plan [Member] | System Energy [Member] | Qualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Service Cost 1,372 1,383 2,744 2,767
Defined Benefit Plan, Interest Cost 3,585 3,386 7,170 6,777
Defined Benefit Plan, Expected Return (Loss) on Plan Assets (4,575) (4,633) (9,150) (9,281)
Defined Benefit Plan, Amortization of Gain (Loss) 1,114 1,162 2,228 2,327
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Settlement   (611)   (611)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total 1,496 1,909 2,992 3,201
Other Postretirement Benefits Plan [Member]        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Service Cost 2,757 3,126 5,514 6,252
Defined Benefit Plan, Interest Cost 9,690 9,852 19,380 19,704
Defined Benefit Plan, Expected Return (Loss) on Plan Assets (10,209) (10,569) (20,418) (21,138)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) (5,720) (5,720) (11,440) (11,440)
Defined Benefit Plan, Amortization of Gain (Loss) (3,870) (2,761) (7,740) (5,522)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total (7,352) (6,072) (14,704) (12,144)
Other Postretirement Benefits Plan [Member] | Entergy Arkansas [Member]        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Service Cost 572 642 1,144 1,284
Defined Benefit Plan, Interest Cost 1,775 1,833 3,550 3,666
Defined Benefit Plan, Expected Return (Loss) on Plan Assets (4,225) (4,384) (8,450) (8,768)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) 524 524 1,048 1,048
Defined Benefit Plan, Amortization of Gain (Loss) (353) 0 (706) 0
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total (1,707) (1,385) (3,414) (2,770)
Other Postretirement Benefits Plan [Member] | Entergy Louisiana [Member]        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Service Cost 671 700 1,342 1,400
Defined Benefit Plan, Interest Cost 2,012 1,999 4,024 3,998
Defined Benefit Plan, Expected Return (Loss) on Plan Assets 0 0 0 0
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) (1,136) (1,136) (2,272) (2,272)
Defined Benefit Plan, Amortization of Gain (Loss) (1,811) (1,738) (3,622) (3,476)
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total (264) (175) (528) (350)
Other Postretirement Benefits Plan [Member] | Entergy Mississippi [Member]        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Service Cost 162 184 324 368
Defined Benefit Plan, Interest Cost 489 486 978 972
Defined Benefit Plan, Expected Return (Loss) on Plan Assets (1,328) (1,372) (2,656) (2,744)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) (239) (239) (478) (478)
Defined Benefit Plan, Amortization of Gain (Loss) (57) 15 (114) 30
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total (973) (926) (1,946) (1,852)
Other Postretirement Benefits Plan [Member] | Entergy New Orleans [Member]        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Service Cost 52 51 104 102
Defined Benefit Plan, Interest Cost 249 253 498 506
Defined Benefit Plan, Expected Return (Loss) on Plan Assets (1,445) (1,479) (2,890) (2,958)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) (229) (229) (458) (458)
Defined Benefit Plan, Amortization of Gain (Loss) (27) 19 (54) 38
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total (1,400) (1,385) (2,800) (2,770)
Other Postretirement Benefits Plan [Member] | Entergy Texas [Member]        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Service Cost 159 168 318 336
Defined Benefit Plan, Interest Cost 582 603 1,164 1,206
Defined Benefit Plan, Expected Return (Loss) on Plan Assets (2,452) (2,539) (4,904) (5,078)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) (1,093) (1,093) (2,186) (2,186)
Defined Benefit Plan, Amortization of Gain (Loss) 153 148 306 296
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total (2,651) (2,713) (5,302) (5,426)
Other Postretirement Benefits Plan [Member] | System Energy [Member]        
Defined Benefit Plan Disclosure [Line Items]        
Defined Benefit Plan, Service Cost 174 175 348 350
Defined Benefit Plan, Interest Cost 394 398 788 796
Defined Benefit Plan, Expected Return (Loss) on Plan Assets (702) (728) (1,404) (1,456)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit) (73) (73) (146) (146)
Defined Benefit Plan, Amortization of Gain (Loss) (7) 0 (14) 0
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Total $ (214) $ (228) $ (428) $ (456)
v3.25.2
Retirement And Other Postretirement Benefits (Schedule of reclassifications out of accumulated other comprehensive income) (Details) - USD ($)
$ in Thousands
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Defined Benefit Plan Disclosure [Line Items]        
Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, before Tax $ 6,013 $ (311,860) $ 12,026 $ (306,991)
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax (3,462) (3,473) (6,924) (6,946)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax 2,551 1,641 5,102 3,037
Other Comprehensive Income (Loss), Defined Benefit Plan, Settlement Gain (Loss), Reclassification Adjustment from AOCI, before Tax   (316,974)   (316,974)
Entergy Louisiana [Member]        
Defined Benefit Plan Disclosure [Line Items]        
Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, before Tax 2,855 2,768 5,710 5,538
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax (1,136) (1,136) (2,272) (2,272)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax 1,719 1,632 3,438 3,266
Pension Plan [Member] | Nonqualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, before Tax     (278) (240)
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax     62 80
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax     (216) (160)
Other Comprehensive Income (Loss), Defined Benefit Plan, Settlement Gain (Loss), Reclassification Adjustment from AOCI, before Tax       0
Pension Plan [Member] | Qualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, before Tax     (822) (319,007)
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax     0 0
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax     (822) (2,033)
Other Comprehensive Income (Loss), Defined Benefit Plan, Settlement Gain (Loss), Reclassification Adjustment from AOCI, before Tax       (316,974)
Pension Plan [Member] | Qualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, before Tax (411) (317,868)    
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax 0 0    
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax (411) (894)    
Other Comprehensive Income (Loss), Defined Benefit Plan, Settlement Gain (Loss), Reclassification Adjustment from AOCI, before Tax   (316,974)    
Pension Plan [Member] | Nonqualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, before Tax (139) (120)    
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax 31 40    
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax (108) (80)    
Other Comprehensive Income (Loss), Defined Benefit Plan, Settlement Gain (Loss), Reclassification Adjustment from AOCI, before Tax   0    
Pension Plan [Member] | Entergy Louisiana [Member] | Nonqualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, before Tax     (2) (2)
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax     0 0
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax     (2) (2)
Pension Plan [Member] | Entergy Louisiana [Member] | Qualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, before Tax     (182) (208)
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax     0 0
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax     (182) (208)
Pension Plan [Member] | Entergy Louisiana [Member] | Qualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, before Tax (91) (104)    
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax 0 0    
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax (91) (104)    
Pension Plan [Member] | Entergy Louisiana [Member] | Nonqualified Plan        
Defined Benefit Plan Disclosure [Line Items]        
Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, before Tax (1) (2)    
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax 0 0    
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax (1) (2)    
Other Postretirement Benefits Plan [Member]        
Defined Benefit Plan Disclosure [Line Items]        
Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, before Tax 6,563 6,128 13,126 12,256
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax (3,493) (3,513) (6,986) (7,026)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax 3,070 2,615 6,140 5,230
Other Comprehensive Income (Loss), Defined Benefit Plan, Settlement Gain (Loss), Reclassification Adjustment from AOCI, before Tax   0   0
Other Postretirement Benefits Plan [Member] | Entergy Louisiana [Member]        
Defined Benefit Plan Disclosure [Line Items]        
Other Comprehensive (Income) Loss, Defined Benefit Plan, Reclassification Adjustment from AOCI, before Tax 2,947 2,874 5,894 5,748
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, before Tax (1,136) (1,136) (2,272) (2,272)
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, before Tax $ 1,811 $ 1,738 $ 3,622 $ 3,476
v3.25.2
Retirement And Other Postretirement Benefits (Schedule of Expected Benefit Payments) (Details) - Pension Plan [Member] - USD ($)
$ in Thousands
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Dec. 31, 2025
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Plan Assets, Contributions by Employer     $ 99,700    
Qualified Plan          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Service Cost $ 23,617 $ 23,370 47,234 $ 46,746  
Entergy Louisiana [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Expected Future Employer Contributions, Current Fiscal Year 41,253   41,253    
Defined Benefit Plan, Plan Assets, Contributions by Employer     17,448    
Entergy Louisiana [Member] | Qualified Plan          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Service Cost 5,454 5,551 10,908 11,102  
Entergy Louisiana [Member] | Subsequent Event [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year         $ 23,805
Entergy Mississippi [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Expected Future Employer Contributions, Current Fiscal Year 8,064   8,064    
Defined Benefit Plan, Plan Assets, Contributions by Employer     3,951    
Entergy Mississippi [Member] | Qualified Plan          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Service Cost 1,304 1,284 2,608 2,568  
Entergy Mississippi [Member] | Subsequent Event [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year         4,113
Entergy New Orleans [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Expected Future Employer Contributions, Current Fiscal Year 5,016   5,016    
Defined Benefit Plan, Plan Assets, Contributions by Employer     2,112    
Entergy New Orleans [Member] | Qualified Plan          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Service Cost 411 440 822 880  
Entergy New Orleans [Member] | Subsequent Event [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year         2,904
Entergy Texas [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Expected Future Employer Contributions, Current Fiscal Year 7,725   7,725    
Defined Benefit Plan, Plan Assets, Contributions by Employer     3,240    
Entergy Texas [Member] | Qualified Plan          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Service Cost 1,024 962 2,048 1,923  
Entergy Texas [Member] | Subsequent Event [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year         4,485
System Energy [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Expected Future Employer Contributions, Current Fiscal Year 15,668   15,668    
Defined Benefit Plan, Plan Assets, Contributions by Employer     6,413    
System Energy [Member] | Qualified Plan          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Service Cost 1,372 1,383 2,744 2,767  
System Energy [Member] | Subsequent Event [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year         9,255
Entergy Arkansas [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Expected Future Employer Contributions, Current Fiscal Year 35,544   35,544    
Defined Benefit Plan, Plan Assets, Contributions by Employer     16,968    
Entergy Arkansas [Member] | Qualified Plan          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Service Cost $ 4,427 $ 4,100 $ 8,854 $ 8,199  
Entergy Arkansas [Member] | Subsequent Event [Member]          
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]          
Defined Benefit Plan, Expected Future Employer Contributions, Remainder of Fiscal Year         $ 18,576
v3.25.2
Business Segment Information (Reconciliation of Operating Profit (Loss) from Segments to Consolidated) (Details) - USD ($)
$ in Thousands
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Mar. 31, 2025
Jun. 30, 2024
Mar. 31, 2024
Jun. 30, 2025
Jun. 30, 2024
Revenues $ 3,328,849   $ 2,953,620   $ 6,175,723 $ 5,748,248
Utilities Operating Expense, Fuel Used 636,274   522,550   980,796 1,139,166
Utilities Operating Expense, Purchased Power 376,105   200,705   721,851 428,847
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses 724,463   701,775   1,397,130 1,388,806
Other Regulatory Charges Credits Net (55,957)   125,607   (72,800) 234,954
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest 471,954 $ 362,422 51,732 $ 76,536 834,376 128,268
Preferred dividend requirements of subsidiaries and net income (loss) attributable to noncontrolling interests 4,024   2,810   5,686 4,065
Net Income (Loss) Available to Common Stockholders, Basic 467,930   48,922   828,690 124,203
Other Nonoperating Income (Expense) (43,722)   (342,549)   (28,996) (393,294)
Utility [Member] | Pension Plan [Member] | Group annuity contract purchase            
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment     8,000      
Corporate Segment and Other Operating Segment [Member] | Pension Plan [Member] | Group annuity contract purchase            
Defined Benefit Plan, Net Periodic Benefit Cost (Credit), Gain (Loss) Due to Curtailment     317,000      
Operating Segments [Member] | Utility [Member]            
Revenues 3,315,723   2,941,404   6,145,320 5,713,577
Utilities Operating Expense, Fuel Used 631,773   514,223   970,756 1,118,627
Utilities Operating Expense, Purchased Power 372,842   193,010   714,926 412,204
Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses 713,296   685,990   1,375,770 1,366,705
Other Regulatory Charges Credits Net (55,957)   125,607   (72,800) 234,954
Segment Reporting, Other Segment Item, Amount 1,051,596   979,255   2,063,453 1,941,788
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest 602,173   443,319   1,093,215 639,299
Operating Segments [Member] | Corporate Segment and Other Operating Segment [Member]            
Revenues 13,144   12,227   30,448 34,703
Consolidation, Eliminations            
Revenues (18)   (11)   (45) (32)
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest (74,541)   (78,885)   (149,789) (158,446)
Segment Reporting, Reconciling Item, Excluding Corporate Nonsegment | Corporate Segment and Other Operating Segment [Member]            
Net Income (Loss), Including Portion Attributable to Noncontrolling Interest (55,678)   (62,479)   (109,050) (102,362)
Other Nonoperating Income (Expense)     (316,738)     (316,738)
Income Tax (Expense) Benefit on Reconciling Items $ 0   $ 66,515   $ 0 $ 66,515
v3.25.2
Business Segment Information (Schedule of Segment Reporting Information, by Segment) (Details) - USD ($)
$ in Thousands
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Dec. 31, 2024
Segment Reporting Information [Line Items]          
Asset Impairment Charges $ 0 $ 0 $ 0 $ 131,775  
Depreciation, Depletion and Amortization 579,152 559,556 1,148,024 1,112,598  
Investment Income, Net 87,419 70,587 120,825 221,283  
Interest Expense, Nonoperating 322,074 289,577 651,865 556,777  
Income Tax Expense (Benefit) 138,399 33,634 238,440 54,627  
Assets 68,383,140   68,383,140   $ 64,790,032
Segment, Expenditure, Addition to Long-Lived Assets     3,799,058 2,458,376  
Consolidation, Eliminations          
Segment Reporting Information [Line Items]          
Asset Impairment Charges       0  
Depreciation, Depletion and Amortization 0 0 0 0  
Investment Income, Net (74,975) (80,647) (150,433) (160,569)  
Interest Expense, Nonoperating (434) (1,763) (643) (2,124)  
Income Tax Expense (Benefit) 0 0 0 0  
Assets (4,905,758)   (4,905,758)   (4,882,991)
Segment, Expenditure, Addition to Long-Lived Assets     0 0  
Utility [Member] | Operating Segments [Member]          
Segment Reporting Information [Line Items]          
Asset Impairment Charges       131,775  
Depreciation, Depletion and Amortization 577,386 557,962 1,144,573 1,109,452  
Investment Income, Net 160,248 141,249 267,423 366,499  
Interest Expense, Nonoperating 261,033 225,511 528,164 437,659  
Income Tax Expense (Benefit) 152,836 113,017 267,109 147,565  
Assets 72,511,224   72,511,224   68,951,564
Segment, Expenditure, Addition to Long-Lived Assets     3,798,452 2,457,683  
Corporate Segment and Other Operating Segment [Member] | Operating Segments [Member]          
Segment Reporting Information [Line Items]          
Asset Impairment Charges       0  
Depreciation, Depletion and Amortization 1,766 1,594 3,451 3,146  
Investment Income, Net 2,146 9,985 3,835 15,353  
Interest Expense, Nonoperating 61,475 65,829 124,344 121,242  
Income Tax Expense (Benefit) (14,437) $ (79,383) (28,669) (92,938)  
Assets $ 777,674   777,674   $ 721,459
Segment, Expenditure, Addition to Long-Lived Assets     $ 606 $ 693  
v3.25.2
Risk Management and Fair Values (Narrative) (Details)
$ in Thousands
Jun. 30, 2025
USD ($)
MMBTU
GWh
Dec. 31, 2024
USD ($)
Cash $ 164,024 $ 48,424
Entergy Arkansas [Member]    
Cash 44,574 1,306
Entergy Louisiana [Member]    
Cash 1,186 327
Entergy Mississippi [Member]    
Cash 30 184
Entergy New Orleans [Member]    
Cash 26 374
Entergy Texas [Member]    
Cash 25 291
System Energy [Member]    
Cash $ 46 448
Natural Gas Swaps    
Derivative, Remaining Maturity 9 months  
Total volume outstanding | MMBTU 9,493,000  
Natural Gas Swaps | Entergy Louisiana [Member]    
Total volume outstanding | MMBTU 0  
Natural Gas Swaps | Entergy Mississippi [Member]    
Derivative, Remaining Maturity 9 months  
Total volume outstanding | MMBTU 9,493,000  
Natural Gas Swaps | Entergy New Orleans [Member]    
Total volume outstanding | MMBTU 0  
Financial transmission rights    
Letters of Credit Outstanding, Amount $ 6,000 2,000
Total volume outstanding | GWh 102,393  
Financial transmission rights | Corporate Segment and Other Operating Segment [Member]    
Letters of Credit Outstanding, Amount $ 0  
Cash 0  
Financial transmission rights | Entergy Arkansas [Member]    
Letters of Credit Outstanding, Amount $ 3,500 500
Total volume outstanding | GWh 20,804  
Financial transmission rights | Entergy Louisiana [Member]    
Letters of Credit Outstanding, Amount $ 1,200 100
Total volume outstanding | GWh 55,064  
Financial transmission rights | Entergy Mississippi [Member]    
Letters of Credit Outstanding, Amount $ 600 800
Total volume outstanding | GWh 11,361  
Financial transmission rights | Entergy New Orleans [Member]    
Letters of Credit Outstanding, Amount   100
Total volume outstanding | GWh 3,660  
Financial transmission rights | Entergy Texas [Member]    
Letters of Credit Outstanding, Amount $ 600 $ 300
Total volume outstanding | GWh 11,505  
v3.25.2
Risk Management and Fair Values (Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location) (Details) - USD ($)
$ in Millions
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Mar. 31, 2025
Dec. 31, 2024
Mar. 31, 2024
Dec. 31, 2023
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value $ 48.0 $ 49.0 $ 48.0 $ 49.0 $ 7.0 $ 20.0 $ 9.0 $ 21.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset 58.0 34.0 93.0 75.0        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements (66.0) (47.0) (114.0) (100.0)        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances 49.0 53.0 49.0 53.0        
Financial transmission rights                
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Letters of Credit Outstanding, Amount 6.0   6.0     $ 2.0    
Financial transmission rights | Not Designated as Hedging Instrument [Member]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset (49.0)   (49.0)          
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Derivative Liability, Current, Statement of Financial Position [Extensible Enumeration]           Other Liabilities, Current    
Derivative Asset, Subject to Master Netting Arrangement, Liability Offset $ 1.0   $ 1.0     $ 1.0    
Derivative Liability, Subject to Master Netting Arrangement, after Offset           $ 1.0    
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration] Prepaid Expense and Other Assets, Current   Prepaid Expense and Other Assets, Current     Prepaid Expense and Other Assets, Current    
Derivative Asset, Subject to Master Netting Arrangement, after Offset $ 48.0   $ 48.0     $ 20.0    
Natural Gas Swaps | Not Designated as Hedging Instrument [Member]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset           (2.0)    
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Derivative Liability, Current, Statement of Financial Position [Extensible Enumeration] Other Liabilities, Current   Other Liabilities, Current          
Derivative Asset, Subject to Master Netting Arrangement, Liability Offset           $ 0.0    
Derivative Liability, Subject to Master Netting Arrangement, after Offset $ 3.0   $ 3.0          
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration]           Prepaid Expense and Other Assets, Current    
Derivative Asset, Subject to Master Netting Arrangement, after Offset           $ 2.0    
Other Current Liabilities [Member] | Financial transmission rights | Not Designated as Hedging Instrument [Member]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset           0.0    
Prepaid Expenses and Other Current Assets | Financial transmission rights | Not Designated as Hedging Instrument [Member]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset           (21.0)    
Entergy Louisiana [Member]                
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value 28.3 19.8 28.3 19.8 3.4 8.6 4.1 9.8
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset 38.2 19.1 55.1 29.6        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements (42.0) (25.0) (64.1) (41.2)        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances 28.7 21.6 28.7 21.6        
Entergy Louisiana [Member] | Uncommitted Credit Facility of $125 Million [Member]                
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Letters of Credit Outstanding, Amount 74.3   74.3          
Entergy Louisiana [Member] | Financial Transmission Rights (FTRs) [Member] | Uncommitted Credit Facility of $125 Million [Member]                
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Letters of Credit Outstanding, Amount 1.2   1.2          
Entergy Louisiana [Member] | Financial transmission rights                
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Letters of Credit Outstanding, Amount 1.2   1.2     0.1    
Entergy Louisiana [Member] | Financial transmission rights | Not Designated as Hedging Instrument [Member]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset (28.6)   (28.6)     (8.7)    
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Derivative Asset, Subject to Master Netting Arrangement, Liability Offset $ 0.3   $ 0.3     $ 0.1    
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration] Prepaid Expense and Other Assets, Current   Prepaid Expense and Other Assets, Current     Prepaid Expense and Other Assets, Current    
Derivative Asset, Subject to Master Netting Arrangement, after Offset $ 28.3   $ 28.3     $ 8.6    
Entergy Mississippi [Member]                
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value 1.4 3.6 1.4 3.6 (0.1) (0.5) 0.6 1.4
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset 3.1 1.2 5.5 1.4        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements (3.1) (2.1) (5.1) (3.1)        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances 1.5 3.9 1.5 3.9        
Entergy Mississippi [Member] | Financial transmission rights                
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Letters of Credit Outstanding, Amount 0.6   0.6     0.8    
Entergy Mississippi [Member] | Financial transmission rights | Not Designated as Hedging Instrument [Member]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset (1.5)   (1.5)     $ (0.4)    
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Derivative Liability, Current, Statement of Financial Position [Extensible Enumeration]           Other Liabilities, Current    
Derivative Asset, Subject to Master Netting Arrangement, Liability Offset $ (0.1)   $ (0.1)     $ 0.9    
Derivative Liability, Subject to Master Netting Arrangement, after Offset           0.5    
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration] Prepaid Expense and Other Assets, Current   Prepaid Expense and Other Assets, Current          
Derivative Asset, Subject to Master Netting Arrangement, after Offset $ 1.4   $ 1.4          
Entergy Mississippi [Member] | Natural Gas Swaps | Not Designated as Hedging Instrument [Member]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset           (1.6)    
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Derivative Liability, Current, Statement of Financial Position [Extensible Enumeration] Other Liabilities, Current   Other Liabilities, Current          
Derivative Asset, Subject to Master Netting Arrangement, Liability Offset           $ 0.0    
Derivative Liability, Subject to Master Netting Arrangement, after Offset $ 3.0   $ 3.0          
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration]           Prepaid Expense and Other Assets, Current    
Derivative Asset, Subject to Master Netting Arrangement, after Offset           $ 1.6    
Entergy New Orleans [Member]                
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value 3.0 2.6 3.0 2.6 0.4 1.3 0.5 1.1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset 8.4 2.6 9.9 3.1        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements (8.8) (3.3) (11.1) (4.4)        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances 3.0 2.8 2.9 2.8        
Entergy New Orleans [Member] | Financial transmission rights                
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Letters of Credit Outstanding, Amount           0.1    
Entergy New Orleans [Member] | Financial transmission rights | Not Designated as Hedging Instrument [Member]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset (3.0)   (3.0)     (1.3)    
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Derivative Asset, Subject to Master Netting Arrangement, Liability Offset $ 0.0   $ 0.0     $ 0.0    
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration] Prepaid Expense and Other Assets, Current   Prepaid Expense and Other Assets, Current     Prepaid Expense and Other Assets, Current    
Derivative Asset, Subject to Master Netting Arrangement, after Offset $ 3.0   $ 3.0     $ 1.3    
Entergy Arkansas [Member]                
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value 11.1 16.1 11.1 16.1 3.0 8.6 2.8 6.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset 5.8 7.7 18.9 31.4        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements (9.5) (12.0) (28.2) (38.9)        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances 11.8 17.6 11.8 17.6        
Entergy Arkansas [Member] | Uncommitted Credit Facility of $25 Million [Member]                
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Letters of Credit Outstanding, Amount 23.6   23.6          
Entergy Arkansas [Member] | Financial Transmission Rights (FTRs) [Member] | Uncommitted Credit Facility of $25 Million [Member]                
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Letters of Credit Outstanding, Amount 3.5   3.5          
Entergy Arkansas [Member] | Financial transmission rights                
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Letters of Credit Outstanding, Amount 3.5   3.5     0.5    
Entergy Arkansas [Member] | Financial transmission rights | Not Designated as Hedging Instrument [Member]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset (11.1)   (11.1)     (8.6)    
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Derivative Asset, Subject to Master Netting Arrangement, Liability Offset $ 0.0   $ 0.0     $ 0.1    
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration] Prepaid Expense and Other Assets, Current   Prepaid Expense and Other Assets, Current     Prepaid Expense and Other Assets, Current    
Derivative Asset, Subject to Master Netting Arrangement, after Offset $ 11.1   $ 11.1     $ 8.5    
Entergy Texas [Member]                
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value 3.9 6.6 3.9 6.6 $ 0.4 1.9 $ 1.2 $ 2.4
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset 1.8 2.7 3.8 9.0        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements (2.3) (4.6) (5.8) (12.1)        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances 4.0 $ 7.3 4.0 $ 7.3        
Entergy Texas [Member] | Financial transmission rights                
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Letters of Credit Outstanding, Amount 0.6   0.6     0.3    
Entergy Texas [Member] | Financial transmission rights | Not Designated as Hedging Instrument [Member]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Derivative Asset, Subject to Master Netting Arrangement, before Offset (4.5)   (4.5)     (2.0)    
Derivative Liability, Subject to Master Netting Arrangement, before Offset of Collateral [Abstract]                
Derivative Asset, Subject to Master Netting Arrangement, Liability Offset $ 0.6   $ 0.6     $ 0.1    
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration] Prepaid Expense and Other Assets, Current   Prepaid Expense and Other Assets, Current     Prepaid Expense and Other Assets, Current    
Derivative Asset, Subject to Master Netting Arrangement, after Offset $ 3.9   $ 3.9     $ 1.9    
v3.25.2
Risk Management and Fair Values (Schedule of Derivatives Not Designated As Hedging Instruments) (Details) - USD ($)
$ in Millions
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Dec. 31, 2024
Financial transmission rights          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Letters of Credit Outstanding, Amount $ 6.0   $ 6.0   $ 2.0
Financial transmission rights | Not Designated as Hedging Instrument [Member]          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] Utilities Operating Expense, Purchased Power Utilities Operating Expense, Purchased Power Utilities Operating Expense, Purchased Power Utilities Operating Expense, Purchased Power  
Derivative, Gain (Loss) on Derivative, Net $ 66.0 $ 47.0 $ 114.0 $ 100.0  
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration] Prepaid Expense and Other Assets, Current   Prepaid Expense and Other Assets, Current   Prepaid Expense and Other Assets, Current
Derivative Asset, Subject to Master Netting Arrangement, before Offset $ 49.0   $ 49.0    
Derivative Asset, Subject to Master Netting Arrangement, Liability Offset (1.0)   (1.0)   $ (1.0)
Derivative Asset, Subject to Master Netting Arrangement, after Offset $ 48.0   $ 48.0   $ 20.0
Derivative Liability, Current, Statement of Financial Position [Extensible Enumeration]         Other Liabilities, Current
Derivative Liability, Subject to Master Netting Arrangement, after Offset         $ 1.0
Financial transmission rights | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Derivative Asset, Subject to Master Netting Arrangement, before Offset         0.0
Financial transmission rights | Not Designated as Hedging Instrument [Member] | Prepaid Expenses and Other Current Assets          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Derivative Asset, Subject to Master Netting Arrangement, before Offset         $ 21.0
Natural Gas Swaps | Not Designated as Hedging Instrument [Member]          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] Utilities Operating Expense, Fuel Used Utilities Operating Expense, Fuel Used Utilities Operating Expense, Fuel Used Utilities Operating Expense, Fuel Used  
Derivative, Gain (Loss) on Derivative, Net $ 11.0 $ 3.0 $ (1.0) $ (3.0)  
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration]         Prepaid Expense and Other Assets, Current
Derivative Asset, Subject to Master Netting Arrangement, before Offset         $ 2.0
Derivative Asset, Subject to Master Netting Arrangement, Liability Offset         0.0
Derivative Asset, Subject to Master Netting Arrangement, after Offset         2.0
Derivative Liability, Subject to Master Netting Arrangement, Asset Offset $ 0.0   $ 0.0    
Derivative Liability, Current, Statement of Financial Position [Extensible Enumeration] Other Liabilities, Current   Other Liabilities, Current    
Derivative Liability, Subject to Master Netting Arrangement, after Offset $ 3.0   $ 3.0    
Derivative Liability, Subject to Master Netting Arrangement, before Offset 3.0   3.0    
Entergy Arkansas [Member] | Uncommitted Credit Facility of $25 Million [Member]          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Letters of Credit Outstanding, Amount 23.6   23.6    
Entergy Arkansas [Member] | Financial Transmission Rights (FTRs) [Member] | Uncommitted Credit Facility of $25 Million [Member]          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Letters of Credit Outstanding, Amount 3.5   3.5    
Entergy Arkansas [Member] | Financial transmission rights          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Letters of Credit Outstanding, Amount $ 3.5   $ 3.5   $ 0.5
Entergy Arkansas [Member] | Financial transmission rights | Not Designated as Hedging Instrument [Member]          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] Utilities Operating Expense, Purchased Power Utilities Operating Expense, Purchased Power Utilities Operating Expense, Purchased Power Utilities Operating Expense, Purchased Power  
Derivative, Gain (Loss) on Derivative, Net $ 9.5 $ 12.0 $ 28.2 $ 38.9  
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration] Prepaid Expense and Other Assets, Current   Prepaid Expense and Other Assets, Current   Prepaid Expense and Other Assets, Current
Derivative Asset, Subject to Master Netting Arrangement, before Offset $ 11.1   $ 11.1   $ 8.6
Derivative Asset, Subject to Master Netting Arrangement, Liability Offset 0.0   0.0   (0.1)
Derivative Asset, Subject to Master Netting Arrangement, after Offset 11.1   11.1   8.5
Entergy Louisiana [Member] | Uncommitted Credit Facility of $125 Million [Member]          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Letters of Credit Outstanding, Amount 74.3   74.3    
Entergy Louisiana [Member] | Financial Transmission Rights (FTRs) [Member] | Uncommitted Credit Facility of $125 Million [Member]          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Letters of Credit Outstanding, Amount 1.2   1.2    
Entergy Louisiana [Member] | Financial transmission rights          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Letters of Credit Outstanding, Amount $ 1.2   $ 1.2   $ 0.1
Entergy Louisiana [Member] | Financial transmission rights | Not Designated as Hedging Instrument [Member]          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] Utilities Operating Expense, Purchased Power Utilities Operating Expense, Purchased Power Utilities Operating Expense, Purchased Power Utilities Operating Expense, Purchased Power  
Derivative, Gain (Loss) on Derivative, Net $ 42.0 $ 25.0 $ 64.1 $ 41.2  
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration] Prepaid Expense and Other Assets, Current   Prepaid Expense and Other Assets, Current   Prepaid Expense and Other Assets, Current
Derivative Asset, Subject to Master Netting Arrangement, before Offset $ 28.6   $ 28.6   $ 8.7
Derivative Asset, Subject to Master Netting Arrangement, Liability Offset (0.3)   (0.3)   (0.1)
Derivative Asset, Subject to Master Netting Arrangement, after Offset 28.3   28.3   8.6
Entergy Mississippi [Member] | Financial transmission rights          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Letters of Credit Outstanding, Amount $ 0.6   $ 0.6   0.8
Entergy Mississippi [Member] | Financial transmission rights | Not Designated as Hedging Instrument [Member]          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] Utilities Operating Expense, Purchased Power Utilities Operating Expense, Purchased Power Utilities Operating Expense, Purchased Power Utilities Operating Expense, Purchased Power  
Derivative, Gain (Loss) on Derivative, Net $ 3.1 $ 2.1 $ 5.1 $ 3.1  
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration] Prepaid Expense and Other Assets, Current   Prepaid Expense and Other Assets, Current    
Derivative Asset, Subject to Master Netting Arrangement, before Offset $ 1.5   $ 1.5   0.4
Derivative Asset, Subject to Master Netting Arrangement, Liability Offset 0.1   0.1   $ (0.9)
Derivative Asset, Subject to Master Netting Arrangement, after Offset $ 1.4   $ 1.4    
Derivative Liability, Current, Statement of Financial Position [Extensible Enumeration]         Other Liabilities, Current
Derivative Liability, Subject to Master Netting Arrangement, after Offset         $ 0.5
Entergy Mississippi [Member] | Natural Gas Swaps | Not Designated as Hedging Instrument [Member]          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] Utilities Operating Expense, Fuel Used Utilities Operating Expense, Fuel Used Utilities Operating Expense, Fuel Used Utilities Operating Expense, Fuel Used  
Derivative, Gain (Loss) on Derivative, Net $ 11.4 $ (3.0) $ (1.2) $ 2.3  
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration]         Prepaid Expense and Other Assets, Current
Derivative Asset, Subject to Master Netting Arrangement, before Offset         $ 1.6
Derivative Asset, Subject to Master Netting Arrangement, Liability Offset         0.0
Derivative Asset, Subject to Master Netting Arrangement, after Offset         1.6
Derivative Liability, Subject to Master Netting Arrangement, Asset Offset $ 0.0   $ 0.0    
Derivative Liability, Current, Statement of Financial Position [Extensible Enumeration] Other Liabilities, Current   Other Liabilities, Current    
Derivative Liability, Subject to Master Netting Arrangement, after Offset $ 3.0   $ 3.0    
Derivative Liability, Subject to Master Netting Arrangement, before Offset $ (3.0)   $ (3.0)    
Entergy New Orleans [Member] | Financial transmission rights          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Letters of Credit Outstanding, Amount         $ 0.1
Entergy New Orleans [Member] | Financial transmission rights | Not Designated as Hedging Instrument [Member]          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] Utilities Operating Expense, Purchased Power Utilities Operating Expense, Purchased Power Utilities Operating Expense, Purchased Power Utilities Operating Expense, Purchased Power  
Derivative, Gain (Loss) on Derivative, Net $ 8.8 $ 3.3 $ 11.1 $ 4.4  
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration] Prepaid Expense and Other Assets, Current   Prepaid Expense and Other Assets, Current   Prepaid Expense and Other Assets, Current
Derivative Asset, Subject to Master Netting Arrangement, before Offset $ 3.0   $ 3.0   $ 1.3
Derivative Asset, Subject to Master Netting Arrangement, Liability Offset 0.0   0.0   0.0
Derivative Asset, Subject to Master Netting Arrangement, after Offset 3.0   3.0   1.3
Entergy New Orleans [Member] | Natural Gas Swaps | Not Designated as Hedging Instrument [Member]          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]       Utilities Operating Expense, Fuel Used  
Derivative, Gain (Loss) on Derivative, Net       $ 0.5  
Entergy Texas [Member] | Financial transmission rights          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Letters of Credit Outstanding, Amount $ 0.6   $ 0.6   $ 0.3
Entergy Texas [Member] | Financial transmission rights | Not Designated as Hedging Instrument [Member]          
Effect Of Derivative Instruments Not Designated As Hedging Instruments On The Consolidated Statements Of Income [Line Items]          
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] Utilities Operating Expense, Purchased Power Utilities Operating Expense, Purchased Power Utilities Operating Expense, Purchased Power Utilities Operating Expense, Purchased Power  
Derivative, Gain (Loss) on Derivative, Net $ 2.3 $ 4.6 $ 5.8 $ 12.1  
Derivative Asset, Current, Statement of Financial Position [Extensible Enumeration] Prepaid Expense and Other Assets, Current   Prepaid Expense and Other Assets, Current   Prepaid Expense and Other Assets, Current
Derivative Asset, Subject to Master Netting Arrangement, before Offset $ 4.5   $ 4.5   $ 2.0
Derivative Asset, Subject to Master Netting Arrangement, Liability Offset (0.6)   (0.6)   (0.1)
Derivative Asset, Subject to Master Netting Arrangement, after Offset $ 3.9   $ 3.9   $ 1.9
v3.25.2
Risk Management and Fair Values (Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis) (Details) - USD ($)
$ in Thousands
Jun. 30, 2025
Dec. 31, 2024
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Cash Equivalents, at Carrying Value $ 1,011,607 $ 811,279
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 7,197,000 6,740,000
Cash and Cash Equivalents, Fair Value Disclosure 1,012,000 811,000
Asset Recovery Damaged Property Costs, Noncurrent 303,479 340,460
Prepaid Expenses and Other Current Assets    
Liabilities, Fair Value Disclosure [Abstract]    
Other Restricted Assets, Current 1,000 4,000
Debt Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 2,107,000 2,047,000
Equity Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 48,000 30,000
Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 48,000 20,000
Liabilities, Fair Value Disclosure [Abstract]    
Liabilities, Fair Value Disclosure on Recurring Basis   1,000
Natural Gas Swaps    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset   2,000
Liabilities, Fair Value Disclosure [Abstract]    
Liabilities, Fair Value Disclosure on Recurring Basis 3,000  
Fair Value, Inputs, Level 1 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 2,221,000 2,035,000
Cash and Cash Equivalents, Fair Value Disclosure 1,012,000 811,000
Other Restricted Assets, Current 1,000 4,000
Asset Recovery Damaged Property Costs, Noncurrent 303,000 340,000
Fair Value, Inputs, Level 1 [Member] | Debt Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 857,000 848,000
Fair Value, Inputs, Level 1 [Member] | Equity Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 48,000 30,000
Fair Value, Inputs, Level 1 [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 0 0
Liabilities, Fair Value Disclosure [Abstract]    
Liabilities, Fair Value Disclosure on Recurring Basis   0
Fair Value, Inputs, Level 1 [Member] | Natural Gas Swaps    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset   2,000
Liabilities, Fair Value Disclosure [Abstract]    
Liabilities, Fair Value Disclosure on Recurring Basis 0  
Fair Value, Inputs, Level 2 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 1,250,000 1,199,000
Cash and Cash Equivalents, Fair Value Disclosure 0 0
Other Restricted Assets, Current 0 0
Asset Recovery Damaged Property Costs, Noncurrent 0 0
Fair Value, Inputs, Level 2 [Member] | Debt Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 1,250,000 1,199,000
Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 0 0
Fair Value, Inputs, Level 2 [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 0 0
Liabilities, Fair Value Disclosure [Abstract]    
Liabilities, Fair Value Disclosure on Recurring Basis   0
Fair Value, Inputs, Level 2 [Member] | Natural Gas Swaps    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset   0
Liabilities, Fair Value Disclosure [Abstract]    
Liabilities, Fair Value Disclosure on Recurring Basis 0  
Fair Value, Inputs, Level 3 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 48,000 20,000
Cash and Cash Equivalents, Fair Value Disclosure 0 0
Other Restricted Assets, Current 0 0
Asset Recovery Damaged Property Costs, Noncurrent 0 0
Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 0 0
Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 0 0
Fair Value, Inputs, Level 3 [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 48,000 20,000
Liabilities, Fair Value Disclosure [Abstract]    
Liabilities, Fair Value Disclosure on Recurring Basis   1,000
Fair Value, Inputs, Level 3 [Member] | Natural Gas Swaps    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset   0
Liabilities, Fair Value Disclosure [Abstract]    
Liabilities, Fair Value Disclosure on Recurring Basis 3,000  
Fair Value Measured at Net Asset Value Per Share    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 3,678,000 3,486,000
Entergy New Orleans [Member]    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Cash Equivalents, at Carrying Value 0 31,403
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 78,100 118,000
Cash and Cash Equivalents, Fair Value Disclosure   31,400
Other Restricted Assets, Current 0 1,611
Asset Recovery Damaged Property Costs, Noncurrent 75,073 83,742
Entergy New Orleans [Member] | Prepaid Expenses and Other Current Assets    
Liabilities, Fair Value Disclosure [Abstract]    
Other Restricted Assets, Current   1,600
Entergy New Orleans [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 3,000 1,300
Entergy New Orleans [Member] | Fair Value, Inputs, Level 1 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 75,100 116,700
Cash and Cash Equivalents, Fair Value Disclosure   31,400
Other Restricted Assets, Current   1,600
Asset Recovery Damaged Property Costs, Noncurrent 75,100 83,700
Entergy New Orleans [Member] | Fair Value, Inputs, Level 1 [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 0 0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 0 0
Cash and Cash Equivalents, Fair Value Disclosure   0
Other Restricted Assets, Current   0
Asset Recovery Damaged Property Costs, Noncurrent 0 0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 2 [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 0 0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 3,000 1,300
Cash and Cash Equivalents, Fair Value Disclosure   0
Other Restricted Assets, Current   0
Asset Recovery Damaged Property Costs, Noncurrent 0 0
Entergy New Orleans [Member] | Fair Value, Inputs, Level 3 [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 3,000 1,300
Entergy Mississippi [Member]    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Cash Equivalents, at Carrying Value 401,336 155,509
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 402,700 157,100
Cash and Cash Equivalents, Fair Value Disclosure 401,300 155,500
Entergy Mississippi [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 1,400  
Liabilities, Fair Value Disclosure [Abstract]    
Liabilities, Fair Value Disclosure on Recurring Basis   500
Entergy Mississippi [Member] | Natural Gas Swaps    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset   1,600
Liabilities, Fair Value Disclosure [Abstract]    
Liabilities, Fair Value Disclosure on Recurring Basis 3,000  
Entergy Mississippi [Member] | Fair Value, Inputs, Level 1 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 401,300 157,100
Cash and Cash Equivalents, Fair Value Disclosure 401,300 155,500
Entergy Mississippi [Member] | Fair Value, Inputs, Level 1 [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 0  
Liabilities, Fair Value Disclosure [Abstract]    
Liabilities, Fair Value Disclosure on Recurring Basis   0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 1 [Member] | Natural Gas Swaps    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset   1,600
Liabilities, Fair Value Disclosure [Abstract]    
Liabilities, Fair Value Disclosure on Recurring Basis 0  
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 0 0
Cash and Cash Equivalents, Fair Value Disclosure 0 0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 0  
Liabilities, Fair Value Disclosure [Abstract]    
Liabilities, Fair Value Disclosure on Recurring Basis   0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 2 [Member] | Natural Gas Swaps    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset   0
Liabilities, Fair Value Disclosure [Abstract]    
Liabilities, Fair Value Disclosure on Recurring Basis 0  
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 1,400 0
Cash and Cash Equivalents, Fair Value Disclosure 0 0
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 1,400  
Liabilities, Fair Value Disclosure [Abstract]    
Liabilities, Fair Value Disclosure on Recurring Basis   500
Entergy Mississippi [Member] | Fair Value, Inputs, Level 3 [Member] | Natural Gas Swaps    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset   0
Liabilities, Fair Value Disclosure [Abstract]    
Liabilities, Fair Value Disclosure on Recurring Basis 3,000  
Entergy Louisiana [Member]    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Cash Equivalents, at Carrying Value 298,264 326,775
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 3,095,500 3,021,200
Cash and Cash Equivalents, Fair Value Disclosure 298,300 326,800
Asset Recovery Damaged Property Costs, Noncurrent 228,406 256,718
Entergy Louisiana [Member] | Debt Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 931,300 908,100
Entergy Louisiana [Member] | Equity Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 20,800 14,500
Entergy Louisiana [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 28,300 8,600
Entergy Louisiana [Member] | Fair Value, Inputs, Level 1 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 879,900 924,000
Cash and Cash Equivalents, Fair Value Disclosure 298,300 326,800
Asset Recovery Damaged Property Costs, Noncurrent 228,400 256,700
Entergy Louisiana [Member] | Fair Value, Inputs, Level 1 [Member] | Debt Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 332,400 326,000
Entergy Louisiana [Member] | Fair Value, Inputs, Level 1 [Member] | Equity Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 20,800 14,500
Entergy Louisiana [Member] | Fair Value, Inputs, Level 1 [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 0 0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 598,900 582,100
Cash and Cash Equivalents, Fair Value Disclosure 0 0
Asset Recovery Damaged Property Costs, Noncurrent 0 0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Debt Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 598,900 582,100
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 0 0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 2 [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 0 0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 28,300 8,600
Cash and Cash Equivalents, Fair Value Disclosure 0 0
Asset Recovery Damaged Property Costs, Noncurrent 0 0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 0 0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 0 0
Entergy Louisiana [Member] | Fair Value, Inputs, Level 3 [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 28,300 8,600
Entergy Louisiana [Member] | Fair Value Measured at Net Asset Value Per Share    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 1,588,400 1,506,500
Entergy Arkansas [Member]    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Cash Equivalents, at Carrying Value 182,414 3,441
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 1,880,200 1,616,300
Cash and Cash Equivalents, Fair Value Disclosure 182,400 3,400
Entergy Arkansas [Member] | Debt Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 594,100 579,000
Entergy Arkansas [Member] | Equity Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 23,300 12,900
Entergy Arkansas [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 11,100 8,500
Entergy Arkansas [Member] | Fair Value, Inputs, Level 1 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 472,000 276,200
Cash and Cash Equivalents, Fair Value Disclosure 182,400 3,400
Entergy Arkansas [Member] | Fair Value, Inputs, Level 1 [Member] | Debt Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 266,300 259,900
Entergy Arkansas [Member] | Fair Value, Inputs, Level 1 [Member] | Equity Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 23,300 12,900
Entergy Arkansas [Member] | Fair Value, Inputs, Level 1 [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 0 0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 327,800 319,100
Cash and Cash Equivalents, Fair Value Disclosure 0 0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Debt Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 327,800 319,100
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 0 0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 2 [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 0 0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 11,100 8,500
Cash and Cash Equivalents, Fair Value Disclosure 0 0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 0 0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 0 0
Entergy Arkansas [Member] | Fair Value, Inputs, Level 3 [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 11,100 8,500
Entergy Arkansas [Member] | Fair Value Measured at Net Asset Value Per Share    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 1,069,300 1,012,500
Entergy Texas [Member]    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Cash Equivalents, at Carrying Value 17,718 184,706
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 22,600 189,300
Cash and Cash Equivalents, Fair Value Disclosure 17,700 184,700
Other Restricted Assets, Current 1,005 2,703
Entergy Texas [Member] | Prepaid Expenses and Other Current Assets    
Liabilities, Fair Value Disclosure [Abstract]    
Other Restricted Assets, Current 1,000 2,700
Entergy Texas [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 3,900 1,900
Entergy Texas [Member] | Fair Value, Inputs, Level 1 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 18,700 187,400
Cash and Cash Equivalents, Fair Value Disclosure 17,700 184,700
Other Restricted Assets, Current 1,000 2,700
Entergy Texas [Member] | Fair Value, Inputs, Level 1 [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 0 0
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 0 0
Cash and Cash Equivalents, Fair Value Disclosure 0 0
Other Restricted Assets, Current 0 0
Entergy Texas [Member] | Fair Value, Inputs, Level 2 [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 0 0
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 3,900 1,900
Cash and Cash Equivalents, Fair Value Disclosure 0 0
Other Restricted Assets, Current 0 0
Entergy Texas [Member] | Fair Value, Inputs, Level 3 [Member] | Financial transmission rights    
Assets, Fair Value Disclosure [Abstract]    
Derivative Asset 3,900 1,900
System Energy [Member]    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Cash Equivalents, at Carrying Value 31,743 28,460
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 1,638,000 1,557,600
Cash and Cash Equivalents, Fair Value Disclosure 31,700 28,500
System Energy [Member] | Debt Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 582,100 559,800
System Energy [Member] | Equity Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 4,100 2,400
System Energy [Member] | Fair Value, Inputs, Level 1 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 294,400 293,300
Cash and Cash Equivalents, Fair Value Disclosure 31,700 28,500
System Energy [Member] | Fair Value, Inputs, Level 1 [Member] | Debt Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 258,600 262,400
System Energy [Member] | Fair Value, Inputs, Level 1 [Member] | Equity Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 4,100 2,400
System Energy [Member] | Fair Value, Inputs, Level 2 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 323,500 297,400
Cash and Cash Equivalents, Fair Value Disclosure 0 0
System Energy [Member] | Fair Value, Inputs, Level 2 [Member] | Debt Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 323,500 297,400
System Energy [Member] | Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 0 0
System Energy [Member] | Fair Value, Inputs, Level 3 [Member]    
Liabilities, Fair Value Disclosure [Abstract]    
Assets, Fair Value Disclosure 0 0
Cash and Cash Equivalents, Fair Value Disclosure 0 0
System Energy [Member] | Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 0 0
System Energy [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member]    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value 0 0
System Energy [Member] | Fair Value Measured at Net Asset Value Per Share    
Assets, Fair Value Disclosure [Abstract]    
Decommissioning Fund Investments, Fair Value $ 1,020,100 $ 966,900
v3.25.2
Risk Management and Fair Values (Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation) (Details) - USD ($)
$ in Millions
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Mar. 31, 2025
Dec. 31, 2024
Mar. 31, 2024
Dec. 31, 2023
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]                
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value $ 48.0 $ 49.0 $ 48.0 $ 49.0 $ 7.0 $ 20.0 $ 9.0 $ 21.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset 58.0 34.0 93.0 75.0        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements (66.0) (47.0) (114.0) (100.0)        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances 49.0 53.0 49.0 53.0        
Entergy Arkansas [Member]                
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]                
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value 11.1 16.1 11.1 16.1 3.0 8.6 2.8 6.0
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset 5.8 7.7 18.9 31.4        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements (9.5) (12.0) (28.2) (38.9)        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances 11.8 17.6 11.8 17.6        
Entergy Louisiana [Member]                
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]                
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value 28.3 19.8 28.3 19.8 3.4 8.6 4.1 9.8
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset 38.2 19.1 55.1 29.6        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements (42.0) (25.0) (64.1) (41.2)        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances 28.7 21.6 28.7 21.6        
Entergy Mississippi [Member]                
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]                
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value 1.4 3.6 1.4 3.6 (0.1) (0.5) 0.6 1.4
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset 3.1 1.2 5.5 1.4        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements (3.1) (2.1) (5.1) (3.1)        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances 1.5 3.9 1.5 3.9        
Entergy New Orleans [Member]                
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]                
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value 3.0 2.6 3.0 2.6 0.4 1.3 0.5 1.1
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset 8.4 2.6 9.9 3.1        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements (8.8) (3.3) (11.1) (4.4)        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances 3.0 2.8 2.9 2.8        
Entergy Texas [Member]                
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]                
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value 3.9 6.6 3.9 6.6 $ 0.4 $ 1.9 $ 1.2 $ 2.4
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included as Regulatory Liability/Asset 1.8 2.7 3.8 9.0        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements (2.3) (4.6) (5.8) (12.1)        
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances $ 4.0 $ 7.3 $ 4.0 $ 7.3        
v3.25.2
Decommissioning Trust Funds (Narrative) (Details) - USD ($)
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Dec. 31, 2024
Decommissioning Trust Funds (Textual) [Abstract]          
Debt Securities, Available-for-Sale, Amortized Cost $ 2,148,000,000   $ 2,148,000,000   $ 2,121,000,000
Average Coupon Rate of Debt Securities Percentage 4.14%   4.14%    
Average Duration of Debt Securities in Years     6 years 4 months 20 days    
Average Maturity of Debt Securities, Years     10 years 9 months 21 days    
Proceeds from Sale of Debt Securities, Available-for-Sale $ 227,000,000 $ 161,000,000 $ 489,000,000 $ 330,000,000  
Debt Securities, Available-for-Sale, Realized Gain 1,000,000 0 2,000,000 1,000,000  
Debt Securities, Available-for-Sale, Realized Loss 4,000,000 14,000,000 8,000,000 20,000,000  
Equity Securities, FV-NI, Unrealized Gain (Loss) 536,000,000   513,000,000    
Deferred Tax Asset, Debt Securities, Available-for-Sale, Unrealized Loss 0   0   0
Entergy Arkansas [Member]          
Decommissioning Trust Funds (Textual) [Abstract]          
Debt Securities, Available-for-Sale, Amortized Cost $ 606,100,000   $ 606,100,000   603,500,000
Average Coupon Rate of Debt Securities Percentage 3.75%   3.75%    
Average Duration of Debt Securities in Years     6 years 2 months 12 days    
Average Maturity of Debt Securities, Years     8 years 5 months 15 days    
Proceeds from Sale of Debt Securities, Available-for-Sale $ 0 5,500,000 $ 0 17,900,000  
Debt Securities, Available-for-Sale, Realized Gain 0 100,000 0 100,000  
Debt Securities, Available-for-Sale, Realized Loss 0 400,000 0 900,000  
Equity Securities, FV-NI, Unrealized Gain (Loss) 138,000,000   126,700,000    
Entergy Louisiana [Member]          
Decommissioning Trust Funds (Textual) [Abstract]          
Debt Securities, Available-for-Sale, Amortized Cost $ 947,300,000   $ 947,300,000   931,500,000
Average Coupon Rate of Debt Securities Percentage 4.40%   4.40%    
Average Duration of Debt Securities in Years     6 years 6 months 25 days    
Average Maturity of Debt Securities, Years     12 years 4 months 17 days    
Proceeds from Sale of Debt Securities, Available-for-Sale $ 71,500,000 62,500,000 $ 181,500,000 110,900,000  
Percentage Interest in River Bend     30.00%    
Debt Securities, Available-for-Sale, Realized Gain 100,000 100,000 $ 200,000 200,000  
Debt Securities, Available-for-Sale, Realized Loss 2,400,000 4,800,000 4,000,000.0 7,700,000  
Equity Securities, FV-NI, Unrealized Gain (Loss) 267,900,000   254,600,000    
System Energy [Member]          
Decommissioning Trust Funds (Textual) [Abstract]          
Debt Securities, Available-for-Sale, Amortized Cost $ 595,000,000   $ 595,000,000   $ 585,500,000
Average Coupon Rate of Debt Securities Percentage 4.13%   4.13%    
Average Duration of Debt Securities in Years     6 years 3 months 7 days    
Average Maturity of Debt Securities, Years     10 years 8 months 23 days    
Proceeds from Sale of Debt Securities, Available-for-Sale $ 155,300,000 93,500,000 $ 307,600,000 201,500,000  
Debt Securities, Available-for-Sale, Realized Gain 800,000 0 1,300,000 200,000  
Debt Securities, Available-for-Sale, Realized Loss 1,400,000 $ 8,400,000 4,000,000.0 $ 11,900,000  
Equity Securities, FV-NI, Unrealized Gain (Loss) $ 130,500,000   $ 131,300,000    
v3.25.2
Decommissioning Trust Funds (Schedule of Available-for-Sale Securities Reconciliation) (Details) - USD ($)
$ in Millions
 6 Months Ended 12 Months Ended
Jun. 30, 2025
Dec. 31, 2024
Debt Securities, Available-for-Sale [Line Items]    
Debt Securities, Available-for-Sale $ 2,107.0 $ 2,047.0
Debt Securities, Available-for-Sale, Unrealized Gain 20.0 7.0
Debt Securities, Available-for-Sale, Unrealized Loss 60.0 80.0
Entergy Arkansas [Member]    
Debt Securities, Available-for-Sale [Line Items]    
Debt Securities, Available-for-Sale 594.1 579.0
Debt Securities, Available-for-Sale, Unrealized Gain 5.4 1.2
Debt Securities, Available-for-Sale, Unrealized Loss 17.5 25.8
Entergy Louisiana [Member]    
Debt Securities, Available-for-Sale [Line Items]    
Debt Securities, Available-for-Sale 931.3 908.1
Debt Securities, Available-for-Sale, Unrealized Gain 8.1 3.6
Debt Securities, Available-for-Sale, Unrealized Loss 24.1 26.9
System Energy [Member]    
Debt Securities, Available-for-Sale [Line Items]    
Debt Securities, Available-for-Sale 582.1 559.8
Debt Securities, Available-for-Sale, Unrealized Gain 6.1 1.9
Debt Securities, Available-for-Sale, Unrealized Loss $ 19.0 $ 27.6
v3.25.2
Decommissioning Trust Funds (Schedule of Debt Securities, Available-for-Sale, Unrealized Loss Position, Fair Value) (Details) - USD ($)
$ in Millions
Jun. 30, 2025
Dec. 31, 2024
Debt Securities, Available-for-Sale [Line Items]    
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value $ 565.0 $ 1,102.0
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value 438.0 510.0
Debt Securities, Held-to-Maturity, Unrealized Loss Position, Fair Value 1,003.0 1,612.0
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, Less than 12 Months 17.0 24.0
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, 12 Months or Longer 43.0 56.0
Debt Securities, Available-for-Sale, Unrealized Loss Position 60.0 80.0
Entergy Arkansas [Member]    
Debt Securities, Available-for-Sale [Line Items]    
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value 141.8 282.8
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value 174.0 195.0
Debt Securities, Held-to-Maturity, Unrealized Loss Position, Fair Value 315.8 477.8
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, Less than 12 Months 4.6 8.2
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, 12 Months or Longer 12.9 17.6
Debt Securities, Available-for-Sale, Unrealized Loss Position 17.5 25.8
Entergy Louisiana [Member]    
Debt Securities, Available-for-Sale [Line Items]    
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value 318.7 543.8
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value 150.6 178.4
Debt Securities, Held-to-Maturity, Unrealized Loss Position, Fair Value 469.3 722.2
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, Less than 12 Months 9.4 8.8
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, 12 Months or Longer 14.7 18.1
Debt Securities, Available-for-Sale, Unrealized Loss Position 24.1 26.9
System Energy [Member]    
Debt Securities, Available-for-Sale [Line Items]    
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, Less than 12 Months, Fair Value 104.2 275.6
Debt Securities, Held-to-Maturity, Continuous Unrealized Loss Position, 12 Months or Longer, Fair Value 113.8 136.8
Debt Securities, Held-to-Maturity, Unrealized Loss Position, Fair Value 218.0 412.4
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, Less than 12 Months 3.3 6.8
Debt Securities, Available-for-Sale, Continuous Unrealized Loss Position, 12 Months or Longer 15.7 20.8
Debt Securities, Available-for-Sale, Unrealized Loss Position $ 19.0 $ 27.6
v3.25.2
Decommissioning Trust Funds (Schedule of Investments Classified by Contractual Maturity Date) (Details) - USD ($)
$ in Thousands
Jun. 30, 2025
Dec. 31, 2024
Debt Securities, Available-for-Sale, Fair Value, Fiscal Year Maturity [Abstract]    
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year One Through Five $ 541,000 $ 574,000
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 5 Through 10 672,000 629,000
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 10 Through 15 195,000 166,000
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 15 Through 20 197,000 218,000
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 20 473,000 424,000
Debt Securities, Available-for-Sale 2,107,000 2,047,000
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, Year One 29,000 36,000
Decommissioning Fund Investments 5,833,432 5,562,575
Entergy Arkansas [Member]    
Debt Securities, Available-for-Sale, Fair Value, Fiscal Year Maturity [Abstract]    
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year One Through Five 159,200 142,500
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 5 Through 10 251,700 231,000
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 10 Through 15 37,400 62,200
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 15 Through 20 43,100 62,800
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 20 76,400 48,800
Debt Securities, Available-for-Sale 594,100 579,000
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, Year One 26,300 31,700
Decommissioning Fund Investments 1,686,652 1,604,428
Entergy Louisiana [Member]    
Debt Securities, Available-for-Sale, Fair Value, Fiscal Year Maturity [Abstract]    
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year One Through Five 212,300 188,200
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 5 Through 10 214,300 259,400
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 10 Through 15 115,000 80,900
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 15 Through 20 107,600 106,100
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 20 279,700 269,100
Debt Securities, Available-for-Sale 931,300 908,100
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, Year One 2,400 4,400
Decommissioning Fund Investments 2,540,476 2,429,088
System Energy [Member]    
Debt Securities, Available-for-Sale, Fair Value, Fiscal Year Maturity [Abstract]    
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year One Through Five 169,200 243,700
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 5 Through 10 206,400 138,900
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 10 Through 15 42,500 22,700
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 15 Through 20 46,400 49,400
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, after Year 20 117,400 104,900
Debt Securities, Available-for-Sale 582,100 559,800
Debt Securities, Available-for-Sale, Fair Value, Maturity, Allocated and Single Maturity Date, Year One 200 200
Decommissioning Fund Investments $ 1,606,304 $ 1,529,059
v3.25.2
Decommissioning Trust Funds (Schedule of Realized Gain (Loss)) (Details) - USD ($)
$ in Thousands
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Proceeds from Sale of Debt Securities, Available-for-sale $ 227,000 $ 161,000 $ 489,000 $ 330,000
Debt Securities, Available-for-Sale, Realized Gain 1,000 0 2,000 1,000
Debt Securities, Available-for-Sale, Realized Loss 4,000 14,000 8,000 20,000
System Energy [Member]        
Proceeds from Sale of Debt Securities, Available-for-sale 155,300 93,500 307,600 201,500
Debt Securities, Available-for-Sale, Realized Gain 800 0 1,300 200
Debt Securities, Available-for-Sale, Realized Loss 1,400 8,400 4,000 11,900
Entergy Louisiana [Member]        
Proceeds from Sale of Debt Securities, Available-for-sale 71,500 62,500 181,500 110,900
Debt Securities, Available-for-Sale, Realized Gain 100 100 200 200
Debt Securities, Available-for-Sale, Realized Loss 2,400 4,800 4,000 7,700
Entergy Arkansas [Member]        
Proceeds from Sale of Debt Securities, Available-for-sale 0 5,500 0 17,900
Debt Securities, Available-for-Sale, Realized Gain 0 100 0 100
Debt Securities, Available-for-Sale, Realized Loss $ 0 $ 400 $ 0 $ 900
v3.25.2
Income Taxes (Narrative) (Details) - USD ($)
$ in Thousands
 1 Months Ended 3 Months Ended 6 Months Ended
Jul. 31, 2025
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Dec. 31, 2024
Regulatory Liability, Noncurrent   $ 3,659,163   $ 3,659,163   $ 3,609,463
Increase (Decrease) in Regulatory Liabilities       20,040 $ 380,394  
Income Tax Expense (Benefit)   138,399 $ 33,634 238,440 54,627  
Production tax credits   571,200   571,200    
Subsequent Event [Member] | Disposal Group, Held-for-Sale, Not Discontinued Operations | Entergy New Orleans and Entergy Louisiana natural gas distribution businesses            
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal $ 11,000          
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal, tax purposes 335,000          
Entergy New Orleans [Member]            
Regulatory Liability, Noncurrent   245,127   245,127   260,312
Increase (Decrease) in Regulatory Liabilities       (13,791) 167,529  
Income Tax Expense (Benefit)   5,744 7,492 9,483 (11,841)  
Entergy New Orleans [Member] | Subsequent Event [Member] | Disposal Group, Held-for-Sale, Not Discontinued Operations | Entergy New Orleans natural gas distribution business            
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal 5,000          
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal, tax purposes 185,000          
Entergy Arkansas [Member]            
Regulatory Liability, Noncurrent   889,400   889,400   831,165
Increase (Decrease) in Regulatory Liabilities       65,970 71,529  
Income Tax Expense (Benefit)   25,677 32,120 48,679 21,446  
Production tax credits   221,400   221,400    
Entergy Louisiana [Member]            
Regulatory Liability, Noncurrent   1,640,771   1,640,771   1,692,547
Increase (Decrease) in Regulatory Liabilities       (70,161) 286,036  
Income Tax Expense (Benefit)   72,541 20,750 126,603 59,674  
Production tax credits   208,900   208,900    
Entergy Louisiana [Member] | Subsequent Event [Member] | Disposal Group, Held-for-Sale, Not Discontinued Operations | Entergy Louisiana natural gas distribution business            
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal 12,000          
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal, tax purposes $ 150,000          
System Energy [Member]            
Regulatory Liability, Noncurrent   802,492   802,492   $ 747,190
Increase (Decrease) in Regulatory Liabilities       52,405 (115,256)  
Income Tax Expense (Benefit)   5,119 $ 7,521 11,395 $ 15,533  
Production tax credits   $ 140,900   $ 140,900    
v3.25.2
Variable Interest Entities (Narrative) (Details) - USD ($)
$ in Thousands
 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Dec. 31, 2024
Variable Interest Entity [Line Items]      
Assets $ 68,383,140   $ 64,790,032
Entergy New Orleans [Member]      
Variable Interest Entity [Line Items]      
Assets 2,258,897   2,223,153
Entergy Louisiana [Member]      
Variable Interest Entity [Line Items]      
Assets 31,952,642   30,348,550
Equity, Attributable to Noncontrolling Interest $ 42,996   42,706
Entergy Louisiana [Member] | Restoration Law Trust I [Member]      
Variable Interest Entity [Line Items]      
LURC's beneficial interest in the storm trust, percentage 1.00%    
Entergy Louisiana [Member] | Restoration Law Trust I [Member] | Entergy Finance Company [Member]      
Variable Interest Entity [Line Items]      
Equity, Attributable to Noncontrolling Interest $ 28,900   28,800
Entergy Louisiana [Member] | Restoration Law Trust I [Member] | Entergy Finance Company [Member]      
Variable Interest Entity [Line Items]      
Redeemable Noncontrolling Interest, Equity, Preferred, Fair Value $ 2,800,000   2,900,000
Entergy Louisiana [Member] | Restoration Law Trust II [Member]      
Variable Interest Entity [Line Items]      
LURC's beneficial interest in the storm trust, percentage 1.00%    
Entergy Louisiana [Member] | Restoration Law Trust II [Member] | Entergy Finance Company [Member]      
Variable Interest Entity [Line Items]      
Equity, Attributable to Noncontrolling Interest $ 14,100   13,900
Entergy Louisiana [Member] | Restoration Law Trust II [Member] | Entergy Finance Company [Member]      
Variable Interest Entity [Line Items]      
Redeemable Noncontrolling Interest, Equity, Preferred, Fair Value 1,300,000   1,400,000
System Energy [Member]      
Variable Interest Entity [Line Items]      
Assets 4,660,737   4,642,474
System Energy [Member] | Grand Gulf [Member]      
Variable Interest Entity [Line Items]      
Payments on lease including interest 8,600 $ 8,600  
Entergy Arkansas [Member]      
Variable Interest Entity [Line Items]      
Assets 15,740,635   15,073,983
Equity, Attributable to Noncontrolling Interest 12,632   15,168
Entergy Arkansas [Member] | AR Searcy Partnership, LLC [Member]      
Variable Interest Entity [Line Items]      
Assets 127,500   129,700
Ownership Interest in Partnership, Carrying Value 114,000   113,200
Entergy Mississippi [Member]      
Variable Interest Entity [Line Items]      
Assets 7,850,534   6,988,970
Equity, Attributable to Noncontrolling Interest 5,311   8,202
Entergy Mississippi [Member] | MS Sunflower Partnership, LLC [Member]      
Variable Interest Entity [Line Items]      
Assets 155,400   157,800
Ownership Interest in Partnership, Carrying Value $ 136,900   $ 132,700
v3.25.2
Revenue (Schedule of Disaggregation of Revenue) (Details) - USD ($)
$ in Thousands
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Disaggregation of Revenue [Line Items]        
Revenues $ 3,328,849 $ 2,953,620 $ 6,175,723 $ 5,748,248
Entergy Arkansas [Member]        
Disaggregation of Revenue [Line Items]        
Revenues 697,687 608,798 1,311,198 1,230,843
Entergy Louisiana [Member]        
Disaggregation of Revenue [Line Items]        
Revenues 1,510,063 1,276,124 2,811,610 2,478,564
Entergy Mississippi [Member]        
Disaggregation of Revenue [Line Items]        
Revenues 491,875 442,894 915,584 857,750
Entergy New Orleans [Member]        
Disaggregation of Revenue [Line Items]        
Revenues 210,000 199,341 391,055 392,302
Entergy Texas [Member]        
Disaggregation of Revenue [Line Items]        
Revenues 531,641 519,077 973,580 963,568
Electricity, US Regulated [Member]        
Disaggregation of Revenue [Line Items]        
Revenue Not from Contract with Customer 3,158 11,955 (1,316) 26,962
Revenues 3,274,945 2,906,047 6,032,811 5,612,553
Electricity, US Regulated [Member] | Entergy Arkansas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue Not from Contract with Customer 1,147 2,232 2,346 4,804
Revenues 697,687 608,798 1,311,198 1,230,843
Electricity, US Regulated [Member] | Entergy Louisiana [Member]        
Disaggregation of Revenue [Line Items]        
Revenue Not from Contract with Customer 1,256 6,464 (5,149) 13,442
Revenues 1,495,504 1,261,444 2,767,450 2,434,237
Electricity, US Regulated [Member] | Entergy Mississippi [Member]        
Disaggregation of Revenue [Line Items]        
Revenue Not from Contract with Customer 623 2,453 1,220 4,887
Revenues 491,875 442,894 915,584 857,750
Electricity, US Regulated [Member] | Entergy New Orleans [Member]        
Disaggregation of Revenue [Line Items]        
Revenue Not from Contract with Customer 107 1,307 212 2,732
Revenues 183,781 178,664 322,706 335,605
Electricity, US Regulated [Member] | Entergy Texas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue Not from Contract with Customer 30 50 60 (104)
Revenues 531,641 519,077 973,580 963,568
Natural Gas, US Regulated [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 40,778 35,357 112,509 101,024
Revenues 40,778 35,357 112,509 101,024
Natural Gas, US Regulated [Member] | Entergy Arkansas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 0 0 0 0
Natural Gas, US Regulated [Member] | Entergy Louisiana [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 14,559 14,680 44,160 44,327
Revenues 14,559 14,680 44,160 44,327
Natural Gas, US Regulated [Member] | Entergy Mississippi [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 0 0 0 0
Natural Gas, US Regulated [Member] | Entergy New Orleans [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 26,219 20,677 68,349 56,697
Revenues 26,219 20,677 68,349 56,697
Natural Gas, US Regulated [Member] | Entergy Texas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 0 0 0 0
Product and Service, Other [Member]        
Disaggregation of Revenue [Line Items]        
Revenues 13,126 12,216 30,403 34,671
Residential [Member] | Electricity, US Regulated [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 1,091,035 1,009,836 2,204,340 2,080,177
Residential [Member] | Electricity, US Regulated [Member] | Entergy Arkansas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 212,265 204,822 486,871 480,574
Residential [Member] | Electricity, US Regulated [Member] | Entergy Louisiana [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 408,293 353,975 786,531 699,003
Residential [Member] | Electricity, US Regulated [Member] | Entergy Mississippi [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 172,575 163,049 358,883 341,666
Residential [Member] | Electricity, US Regulated [Member] | Entergy New Orleans [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 73,279 71,842 138,969 139,520
Residential [Member] | Electricity, US Regulated [Member] | Entergy Texas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 224,623 216,148 433,086 419,414
Commercial [Member] | Electricity, US Regulated [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 771,097 713,282 1,455,104 1,405,133
Commercial [Member] | Electricity, US Regulated [Member] | Entergy Arkansas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 141,468 132,950 273,085 274,258
Commercial [Member] | Electricity, US Regulated [Member] | Entergy Louisiana [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 306,916 265,869 570,116 522,565
Commercial [Member] | Electricity, US Regulated [Member] | Entergy Mississippi [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 147,052 142,173 282,925 274,491
Commercial [Member] | Electricity, US Regulated [Member] | Entergy New Orleans [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 58,133 57,360 105,755 110,585
Commercial [Member] | Electricity, US Regulated [Member] | Entergy Texas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 117,528 114,930 223,223 223,234
Industrial [Member] | Electricity, US Regulated [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 945,901 792,721 1,720,020 1,541,679
Industrial [Member] | Electricity, US Regulated [Member] | Entergy Arkansas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 174,555 138,786 323,620 288,193
Industrial [Member] | Electricity, US Regulated [Member] | Entergy Louisiana [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 570,303 458,420 1,036,010 880,017
Industrial [Member] | Electricity, US Regulated [Member] | Entergy Mississippi [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 53,629 49,180 100,974 95,607
Industrial [Member] | Electricity, US Regulated [Member] | Entergy New Orleans [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 7,800 7,602 13,454 14,580
Industrial [Member] | Electricity, US Regulated [Member] | Entergy Texas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 139,614 138,733 245,962 263,282
Governmental [Member] | Electricity, US Regulated [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 70,623 65,861 133,441 131,172
Governmental [Member] | Electricity, US Regulated [Member] | Entergy Arkansas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 4,911 4,433 9,130 9,133
Governmental [Member] | Electricity, US Regulated [Member] | Entergy Louisiana [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 23,622 21,223 45,290 43,044
Governmental [Member] | Electricity, US Regulated [Member] | Entergy Mississippi [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 14,544 14,061 28,234 27,390
Governmental [Member] | Electricity, US Regulated [Member] | Entergy New Orleans [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 20,656 19,167 37,185 37,521
Governmental [Member] | Electricity, US Regulated [Member] | Entergy Texas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 6,890 6,977 13,602 14,084
Billed Retail [Member] | Electricity, US Regulated [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 2,878,656 2,581,700 5,512,905 5,158,161
Billed Retail [Member] | Electricity, US Regulated [Member] | Entergy Arkansas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 533,199 480,991 1,092,706 1,052,158
Billed Retail [Member] | Electricity, US Regulated [Member] | Entergy Louisiana [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 1,309,134 1,099,487 2,437,947 2,144,629
Billed Retail [Member] | Electricity, US Regulated [Member] | Entergy Mississippi [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 387,800 368,463 771,016 739,154
Billed Retail [Member] | Electricity, US Regulated [Member] | Entergy New Orleans [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 159,868 155,971 295,363 302,206
Billed Retail [Member] | Electricity, US Regulated [Member] | Entergy Texas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 488,655 476,788 915,873 920,014
Sales for Resale [Member] | Electricity, US Regulated [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 146,457 54,579 198,330 133,583
Sales for Resale [Member] | Electricity, US Regulated [Member] | Entergy Arkansas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 84,533 43,842 121,262 82,807
Sales for Resale [Member] | Electricity, US Regulated [Member] | Entergy Louisiana [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 109,243 80,823 220,791 163,551
Sales for Resale [Member] | Electricity, US Regulated [Member] | Entergy Mississippi [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 61,713 21,260 89,810 69,193
Sales for Resale [Member] | Electricity, US Regulated [Member] | Entergy New Orleans [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 10,027 8,575 13,917 21,075
Sales for Resale [Member] | Electricity, US Regulated [Member] | Entergy Texas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 5,195 3,015 7,590 4,922
Other Electric [Member] | Electricity, US Regulated [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 246,674 257,813 322,892 293,847
Other Electric [Member] | Electricity, US Regulated [Member] | Entergy Arkansas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 78,808 81,733 94,884 91,074
Other Electric [Member] | Electricity, US Regulated [Member] | Entergy Louisiana [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 75,871 74,670 113,861 112,615
Other Electric [Member] | Electricity, US Regulated [Member] | Entergy Mississippi [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 41,739 50,718 53,538 44,516
Other Electric [Member] | Electricity, US Regulated [Member] | Entergy New Orleans [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 13,779 12,811 13,214 9,592
Other Electric [Member] | Electricity, US Regulated [Member] | Entergy Texas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 37,761 39,224 50,057 38,736
Customer [Member] | Electricity, US Regulated [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 3,271,787 2,894,092 6,034,127 5,585,591
Customer [Member] | Electricity, US Regulated [Member] | Entergy Arkansas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 696,540 606,566 1,308,852 1,226,039
Customer [Member] | Electricity, US Regulated [Member] | Entergy Louisiana [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 1,494,248 1,254,980 2,772,599 2,420,795
Customer [Member] | Electricity, US Regulated [Member] | Entergy Mississippi [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 491,252 440,441 914,364 852,863
Customer [Member] | Electricity, US Regulated [Member] | Entergy New Orleans [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax 183,674 177,357 322,494 332,873
Customer [Member] | Electricity, US Regulated [Member] | Entergy Texas [Member]        
Disaggregation of Revenue [Line Items]        
Revenue from Contract with Customer, Excluding Assessed Tax $ 531,611 $ 519,027 $ 973,520 $ 963,672
v3.25.2
Acquisitions, Held for Sale, and Dispositions (Narrative) (Details) - USD ($)
$ in Thousands
 1 Months Ended 3 Months Ended 6 Months Ended
Jul. 31, 2025
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Jul. 01, 2025
Dec. 31, 2024
Asset Acquisition [Line Items]              
Asset Impairment Charges   $ 0 $ 0 $ 0 $ 131,775    
Disposal Group, Held-for-Sale, Not Discontinued Operations | Entergy New Orleans and Entergy Louisiana natural gas distribution businesses              
Asset Acquisition [Line Items]              
Income (Loss) from Individually Significant Component Disposed of or Held-for-Sale, Excluding Discontinued Operations, Attributable to Parent, before Income Tax   9,484 7,527 31,500 27,459    
Disposal Group, Including Discontinued Operation, Goodwill, Noncurrent   6,517   6,517     $ 6,474
Disposal Group, Liabilities, Regulatory Liability, Noncurrent   2,579   2,579     1,611
Disposal Group, Assets, Public Utilities, Property, Plant, and Equipment, Natural Gas   697,812   697,812     679,502
Subsequent Event [Member] | Disposal Group, Held-for-Sale, Not Discontinued Operations | Entergy New Orleans and Entergy Louisiana natural gas distribution businesses              
Asset Acquisition [Line Items]              
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal $ 11,000            
Disposal Group, Including Discontinued Operation, Goodwill, Noncurrent           $ 7,000  
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal, net of tax 6,000            
Entergy Arkansas [Member]              
Asset Acquisition [Line Items]              
Asset Impairment Charges   0 0 0 131,775    
Entergy Louisiana [Member] | Disposal Group, Held-for-Sale, Not Discontinued Operations | Entergy Louisiana natural gas distribution business              
Asset Acquisition [Line Items]              
Income (Loss) from Individually Significant Component Disposed of or Held-for-Sale, Excluding Discontinued Operations, Attributable to Parent, before Income Tax   2,272 2,754 12,047 12,858    
Disposal Group, Including Discontinued Operation, Goodwill, Noncurrent   0   0     0
Disposal Group, Liabilities, Regulatory Liability, Noncurrent   945   945     1,214
Disposal Group, Assets, Public Utilities, Property, Plant, and Equipment, Natural Gas   311,898   311,898     303,193
Entergy Louisiana [Member] | Subsequent Event [Member] | Disposal Group, Held-for-Sale, Not Discontinued Operations | Entergy Louisiana natural gas distribution business              
Asset Acquisition [Line Items]              
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal 12,000            
Disposal Group, Not Discontinued Operations, Transaction Costs           20,000  
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal, net of tax 9,000            
Disposal Group, Including Discontinued Operation, Consideration           203,000  
Entergy New Orleans [Member] | Disposal Group, Held-for-Sale, Not Discontinued Operations | Entergy New Orleans natural gas distribution business              
Asset Acquisition [Line Items]              
Income (Loss) from Individually Significant Component Disposed of or Held-for-Sale, Excluding Discontinued Operations, Attributable to Parent, before Income Tax   7,212 $ 4,773 19,453 $ 14,601    
Disposal Group, Including Discontinued Operation, Goodwill, Noncurrent   0   0     0
Disposal Group, Liabilities, Regulatory Liability, Noncurrent   1,634   1,634     397
Disposal Group, Assets, Public Utilities, Property, Plant, and Equipment, Natural Gas   $ 385,914   $ 385,914     $ 376,309
Entergy New Orleans [Member] | Subsequent Event [Member] | Disposal Group, Held-for-Sale, Not Discontinued Operations | Entergy New Orleans natural gas distribution business              
Asset Acquisition [Line Items]              
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal 5,000            
Disposal Group, Not Discontinued Operations, Transaction Costs           19,000  
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal, net of tax 4,000            
Disposal Group, Liabilities, Regulatory Liability, Noncurrent           4,000  
Disposal Group, Including Discontinued Operation, Consideration           $ 288,000  
Asset Impairment Charges $ 12,000            
v3.25.2
Acquisitions, Held for Sale, and Dispositions (Disposal Groups, Including Discontinued Operations) (Details) - USD ($)
$ in Thousands
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Dec. 31, 2024
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]          
Disposal Group, Including Discontinued Operation, Assets, Current $ 19,602   $ 19,602   $ 15,574
Disposal Group, Including Discontinued Operation, Assets, Noncurrent 472,528   472,528   462,797
Entergy Louisiana [Member]          
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]          
Disposal Group, Including Discontinued Operation, Assets, Current 4,845   4,845   2,474
Disposal Group, Including Discontinued Operation, Assets, Noncurrent 178,746   178,746   173,669
Entergy New Orleans [Member]          
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]          
Disposal Group, Including Discontinued Operation, Assets, Current 14,757   14,757   13,100
Disposal Group, Including Discontinued Operation, Assets, Noncurrent 289,126   289,126   284,738
Disposal Group, Held-for-Sale, Not Discontinued Operations | Entergy New Orleans and Entergy Louisiana natural gas distribution businesses          
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]          
Disposal Group, Assets, Deferred Fuel Cost 5,829   5,829   5,608
Disposal Group, Assets, Energy Related Inventory 4,828   4,828   4,493
Disposal Group, Assets, Public Utilities, Inventory 7,604   7,604   5,451
Disposal Group, Including Discontinued Operation, Prepaid and Other Assets, Current 1,341   1,341   22
Disposal Group, Including Discontinued Operation, Assets, Current 19,602   19,602   15,574
Disposal Group, Assets, Public Utilities, Property, Plant, and Equipment, Natural Gas 697,812   697,812   679,502
Disposal Group, Assets, Public Utilities, Property, Plant, and Equipment, Construction Work In Progress 2,710   2,710   2,959
Disposal Group, Assets, Public Utilities, Property, Plant, and Equipment, Accumulated Depreciation (283,404)   (283,404)   (276,388)
Disposal Group, Assets, Regulatory Asset, Noncurrent 33,523   33,523   35,381
Disposal Group, Including Discontinued Operation, Goodwill, Noncurrent 6,517   6,517   6,474
Disposal Group, Assets, Defined Benefit Plan, Noncurrent 15,171   15,171   14,663
Disposal Group, Assets, Other Assets, Noncurrent 199   199   206
Disposal Group, Including Discontinued Operation, Assets, Noncurrent 472,528   472,528   462,797
Disposal Group, Including Discontinued Operation, Accounts Payable, Current 2,945   2,945   702
Disposal Group, Liabilities, Contract with Customer, Refund Liability, Current 5,327   5,327   6,214
Disposal Group, Liabilities, Taxes Payable, Current 0   0   13
Disposal Group, Including Discontinued Operation, Other Liabilities, Current 1,352   1,352   1,401
Disposal Group, Including Discontinued Operation, Liabilities, Current 9,624   9,624   8,330
Disposal Group, Liabilities, Regulatory Liability for Income Taxes - net 28,438   28,438   31,575
Disposal Group, Liabilities, Regulatory Liability, Noncurrent 2,579   2,579   1,611
Disposal Group, Liabilities, Defined Benefit Plan, Noncurrent 4,236   4,236   3,976
Disposal Group, Including Discontinued Operation, Other Liabilities, Noncurrent 4,146   4,146   3,844
Disposal Group, Including Discontinued Operation, Liabilities, Noncurrent 39,399   39,399   41,006
Income (Loss) from Individually Significant Component Disposed of or Held-for-Sale, Excluding Discontinued Operations, Attributable to Parent, before Income Tax 9,484 $ 7,527 31,500 $ 27,459  
Disposal Group, Held-for-Sale, Not Discontinued Operations | Entergy Louisiana natural gas distribution business | Entergy Louisiana [Member]          
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]          
Disposal Group, Assets, Deferred Fuel Cost 3,324   3,324   727
Disposal Group, Assets, Energy Related Inventory 295   295   702
Disposal Group, Assets, Public Utilities, Inventory 1,172   1,172   1,045
Disposal Group, Including Discontinued Operation, Prepaid and Other Assets, Current 54   54   0
Disposal Group, Including Discontinued Operation, Assets, Current 4,845   4,845   2,474
Disposal Group, Assets, Public Utilities, Property, Plant, and Equipment, Natural Gas 311,898   311,898   303,193
Disposal Group, Assets, Public Utilities, Property, Plant, and Equipment, Construction Work In Progress 1,730   1,730   1,085
Disposal Group, Assets, Public Utilities, Property, Plant, and Equipment, Accumulated Depreciation (141,818)   (141,818)   (139,556)
Disposal Group, Assets, Regulatory Asset, Noncurrent 6,936   6,936   8,947
Disposal Group, Including Discontinued Operation, Goodwill, Noncurrent 0   0   0
Disposal Group, Assets, Defined Benefit Plan, Noncurrent 0   0   0
Disposal Group, Assets, Other Assets, Noncurrent 0   0   0
Disposal Group, Including Discontinued Operation, Assets, Noncurrent 178,746   178,746   173,669
Disposal Group, Including Discontinued Operation, Accounts Payable, Current 295   295   702
Disposal Group, Liabilities, Contract with Customer, Refund Liability, Current 2,572   2,572   1,984
Disposal Group, Liabilities, Taxes Payable, Current 0   0   13
Disposal Group, Including Discontinued Operation, Other Liabilities, Current 536   536   589
Disposal Group, Including Discontinued Operation, Liabilities, Current 3,403   3,403   3,288
Disposal Group, Liabilities, Regulatory Liability for Income Taxes - net 3,193   3,193   4,981
Disposal Group, Liabilities, Regulatory Liability, Noncurrent 945   945   1,214
Disposal Group, Liabilities, Defined Benefit Plan, Noncurrent 4,643   4,643   4,525
Disposal Group, Including Discontinued Operation, Other Liabilities, Noncurrent 1,414   1,414   1,194
Disposal Group, Including Discontinued Operation, Liabilities, Noncurrent 10,195   10,195   11,914
Income (Loss) from Individually Significant Component Disposed of or Held-for-Sale, Excluding Discontinued Operations, Attributable to Parent, before Income Tax 2,272 2,754 12,047 12,858  
Disposal Group, Held-for-Sale, Not Discontinued Operations | Entergy New Orleans natural gas distribution business | Entergy New Orleans [Member]          
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]          
Disposal Group, Assets, Deferred Fuel Cost 2,505   2,505   4,881
Disposal Group, Assets, Energy Related Inventory 4,533   4,533   3,791
Disposal Group, Assets, Public Utilities, Inventory 6,432   6,432   4,406
Disposal Group, Including Discontinued Operation, Prepaid and Other Assets, Current 1,287   1,287   22
Disposal Group, Including Discontinued Operation, Assets, Current 14,757   14,757   13,100
Disposal Group, Assets, Public Utilities, Property, Plant, and Equipment, Natural Gas 385,914   385,914   376,309
Disposal Group, Assets, Public Utilities, Property, Plant, and Equipment, Construction Work In Progress 980   980   1,874
Disposal Group, Assets, Public Utilities, Property, Plant, and Equipment, Accumulated Depreciation (141,586)   (141,586)   (136,832)
Disposal Group, Assets, Regulatory Asset, Noncurrent 23,667   23,667   23,682
Disposal Group, Including Discontinued Operation, Goodwill, Noncurrent 0   0   0
Disposal Group, Assets, Defined Benefit Plan, Noncurrent 19,952   19,952   19,499
Disposal Group, Assets, Other Assets, Noncurrent 199   199   206
Disposal Group, Including Discontinued Operation, Assets, Noncurrent 289,126   289,126   284,738
Disposal Group, Including Discontinued Operation, Accounts Payable, Current 2,650   2,650   0
Disposal Group, Liabilities, Contract with Customer, Refund Liability, Current 2,755   2,755   4,230
Disposal Group, Liabilities, Taxes Payable, Current 0   0   0
Disposal Group, Including Discontinued Operation, Other Liabilities, Current 816   816   812
Disposal Group, Including Discontinued Operation, Liabilities, Current 6,221   6,221   5,042
Disposal Group, Liabilities, Regulatory Liability for Income Taxes - net 25,245   25,245   26,594
Disposal Group, Liabilities, Regulatory Liability, Noncurrent 1,634   1,634   397
Disposal Group, Liabilities, Defined Benefit Plan, Noncurrent 1,610   1,610   1,197
Disposal Group, Including Discontinued Operation, Other Liabilities, Noncurrent 2,732   2,732   2,650
Disposal Group, Including Discontinued Operation, Liabilities, Noncurrent 31,221   31,221   $ 30,838
Income (Loss) from Individually Significant Component Disposed of or Held-for-Sale, Excluding Discontinued Operations, Attributable to Parent, before Income Tax $ 7,212 $ 4,773 $ 19,453 $ 14,601  
v3.25.2
Acquisitions, Held for Sale, and Dispositions (Schedule of Income (Loss) from Individually Significant Component Disposed of or Held-for-Sale) (Details) - Disposal Group, Held-for-Sale, Not Discontinued Operations - USD ($)
$ in Thousands
 3 Months Ended 6 Months Ended
Jun. 30, 2025
Jun. 30, 2024
Jun. 30, 2025
Jun. 30, 2024
Entergy New Orleans and Entergy Louisiana natural gas distribution businesses        
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]        
Income (Loss) from Individually Significant Component Disposed of or Held-for-Sale, Excluding Discontinued Operations, Attributable to Parent, before Income Tax $ 9,484 $ 7,527 $ 31,500 $ 27,459
Entergy Louisiana [Member] | Entergy Louisiana natural gas distribution business        
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]        
Income (Loss) from Individually Significant Component Disposed of or Held-for-Sale, Excluding Discontinued Operations, Attributable to Parent, before Income Tax 2,272 2,754 12,047 12,858
Entergy New Orleans [Member] | Entergy New Orleans natural gas distribution business        
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]        
Income (Loss) from Individually Significant Component Disposed of or Held-for-Sale, Excluding Discontinued Operations, Attributable to Parent, before Income Tax $ 7,212 $ 4,773 $ 19,453 $ 14,601