JERSEY CENTRAL POWER & LIGHT CO, 10-K filed on 2/18/2026
Annual Report
v3.25.4
Cover Page - USD ($)
 12 Months Ended
Dec. 31, 2025
Jan. 31, 2026
Jun. 30, 2025
Document Information [Line Items]      
Document Type 10-K    
Document Annual Report true    
Document Period End Date Dec. 31, 2025    
Current Fiscal Year End Date --12-31    
Document Transition Report false    
Entity File Number 333-21011    
Entity Registrant Name FIRSTENERGY CORP.    
Entity Incorporation, State or Country Code OH    
Entity Tax Identification Number 34-1843785    
Entity Address, Address Line One 341 White Pond Drive    
Entity Address, City or Town Akron    
Entity Address, State or Province OH    
Entity Address, Postal Zip Code 44320    
City Area Code (800)    
Local Phone Number 736-3402    
Title of 12(b) Security Common Stock, $0.10 par value per share    
Trading Symbol FE    
Security Exchange Name NYSE    
Entity Well-known Seasoned Issuer No    
Entity Voluntary Filers No    
Entity Current Reporting Status Yes    
Entity Interactive Data Current Yes    
Entity Filer Category Large Accelerated Filer    
Entity Small Business false    
Entity Emerging Growth Company false    
ICFR Auditor Attestation Flag true    
Document Financial Statement Error Correction false    
Entity Shell Company false    
Entity Public Float     $ 23,208,851,454
Entity Common Stock Shares Outstanding   577,932,879  
Documents Incorporated by Reference
Documents Incorporated By Reference
 PART OF FORM 10-K INTO WHICH
DOCUMENTDOCUMENT IS INCORPORATED
Portions of the Definitive Proxy Statement for the 2026 Annual Meeting of Shareholders of FirstEnergy Corp. to be held May 20, 2026.Part III
    
Entity Central Index Key 0001031296    
Document Fiscal Year Focus 2025    
Document Fiscal Period Focus FY    
Amendment Flag false    
JERSEY CENTRAL POWER & LIGHT COMPANY      
Document Information [Line Items]      
Entity File Number 1-3141    
Entity Registrant Name JERSEY CENTRAL POWER & LIGHT COMPANY    
Entity Incorporation, State or Country Code NJ    
Entity Tax Identification Number 21-0485010    
Entity Address, Address Line One 300 Madison Avenue    
Entity Address, City or Town Morristown    
Entity Address, State or Province NJ    
Entity Address, Postal Zip Code 07962    
City Area Code (800)    
Local Phone Number 736-3402    
Entity Well-known Seasoned Issuer No    
Entity Voluntary Filers No    
Entity Current Reporting Status Yes    
Entity Interactive Data Current Yes    
Entity Filer Category Non-accelerated Filer    
ICFR Auditor Attestation Flag false    
Entity Shell Company false    
Entity Common Stock Shares Outstanding   13,628,447  
Documents Incorporated by Reference
Documents Incorporated By Reference
 PART OF FORM 10-K INTO WHICH
DOCUMENTDOCUMENT IS INCORPORATED
Portions of the Definitive Proxy Statement for the 2026 Annual Meeting of Shareholders of FirstEnergy Corp. to be held May 20, 2026.Part III
    
v3.25.4
Audit Information
 12 Months Ended
Dec. 31, 2025
Auditor [Line Items]  
Auditor Name PricewaterhouseCoopers LLP
Auditor Location Cleveland, Ohio
Auditor Firm ID 238
JERSEY CENTRAL POWER & LIGHT COMPANY  
Auditor [Line Items]  
Auditor Name PricewaterhouseCoopers LLP
Auditor Location Cleveland, Ohio
Auditor Firm ID 238
v3.25.4
CONSOLIDATED STATEMENTS OF INCOME - USD ($)
shares in Millions, $ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
REVENUES:      
Total revenues [1] $ 15,090 $ 13,472 $ 12,870
OPERATING EXPENSES:      
Fuel 652 464 538
Purchased power 4,583 3,912 4,108
Other operating expenses 4,122 4,044 3,579
Provision for depreciation 1,664 1,581 1,461
Deferral of regulatory assets, net (109) (231) (261)
General taxes 1,345 1,212 1,164
Ohio settlement charges (Note 13.) 275 0 0
Impairment of assets (Note 1.) 352 115 15
Total operating expenses 12,884 11,097 10,604
OPERATING INCOME 2,206 2,375 2,266
OTHER INCOME (EXPENSE):      
Debt redemption costs (Note 11.) (24) (85) (36)
Equity method investment earnings, net (Note 1.) 0 58 175
Miscellaneous income, net 156 189 164
Pension and OPEB mark-to-market adjustments (Note 4.) 253 (22) (78)
Interest expense (1,217) (1,144) (1,124)
Capitalized financing costs 185 133 97
Total other expense (647) (871) (802)
INCOME BEFORE INCOME TAXES 1,559 1,504 1,464
INCOME TAXES 288 377 267
INCOME FROM CONTINUING OPERATIONS 1,271 1,127 1,197
Discontinued operations (Note 1.) [2] 0 0 (21)
NET INCOME 1,271 1,127 1,176
Income attributable to noncontrolling interest (continuing operations) 251 149 74
EARNINGS ATTRIBUTABLE TO FIRSTENERGY CORP. 1,020 978 1,102
EARNINGS ATTRIBUTABLE TO FIRSTENERGY CORP.      
Earnings from continuing operations 1,020 978 1,123
Earnings from discontinued operations [2] 0 0 (21)
EARNINGS ATTRIBUTABLE TO FIRSTENERGY CORP. $ 1,020 $ 978 $ 1,102
EARNINGS PER SHARE ATTRIBUTABLE TO FIRSTENERGY CORP. (Note 3.)      
Basic - continuing operations (in dollars per share) $ 1.77 $ 1.70 $ 1.96
Basic - discontinued operations (in dollars per share) 0 0 (0.04)
Basic (in dollars per share) 1.77 1.70 1.92
Diluted - continuing operations (in dollars per share) 1.76 1.70 1.96
Diluted - discontinued operations (in dollars per share) 0 0 (0.04)
Diluted (in dollars per share) $ 1.76 $ 1.70 $ 1.92
WEIGHTED AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:      
Basic (in shares) 577 575 573
Diluted (in shares) 578 577 574
Distribution services and retail generation      
REVENUES:      
Total revenues $ 12,189 $ 10,976 $ 10,405
Transmission      
REVENUES:      
Total revenues 2,311 2,148 2,049
Other      
REVENUES:      
Total revenues $ 590 $ 348 $ 416
[1] Includes excise and gross receipts tax collections of $463 million, $429 million and $420 million in 2025, 2024 and 2023, respectively.
[2] Consists of income taxes of $21 million in 2023.
v3.25.4
CONSOLIDATED STATEMENTS OF INCOME (Parenthetical) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Income Statement [Abstract]      
Excise tax collections included in revenue $ 463 $ 429 $ 420
Net of income tax benefit (expense)     $ 21
v3.25.4
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Statement of Comprehensive Income [Abstract]      
Net income $ 1,271 $ 1,127 $ 1,176
OTHER COMPREHENSIVE INCOME (LOSS):      
Pension and OPEB prior service costs 0 1 (6)
Amortized losses on derivative hedges 0 3 2
Other comprehensive income (loss) 0 4 (4)
Income tax expense (benefits) on other comprehensive loss 0 1 (1)
Other comprehensive income (loss), net of tax 0 3 (3)
COMPREHENSIVE INCOME 1,271 1,130 1,173
Comprehensive income attributable to noncontrolling interest 251 149 74
COMPREHENSIVE INCOME ATTRIBUTABLE TO FIRSTENERGY CORP. $ 1,020 $ 981 $ 1,099
v3.25.4
CONSOLIDATED BALANCE SHEETS - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
CURRENT ASSETS:    
Cash and cash equivalents $ 57 $ 111
Restricted cash 42 43
Receivables-    
Customers 1,783 1,585
Less — Allowance for uncollectible customer receivables 57 55
Receivable 1,726 1,530
Other, net of allowance for uncollectible accounts of $11 in 2025 and $6 in 2024 295 303
Materials and supplies, at average cost 577 549
Prepaid taxes and other 282 240
Total current assets 2,979 2,776
PROPERTY, PLANT AND EQUIPMENT:    
In service 56,213 52,896
Less — Accumulated provision for depreciation 15,189 14,548
Net Plant 41,024 38,348
Construction work in progress 3,389 2,754
Total 44,413 41,102
INVESTMENTS AND OTHER NONCURRENT ASSETS:    
Goodwill 5,618 5,618
Investments 641 652
Regulatory assets 829 617
Other 1,424 1,279
Total investments and other noncurrent assets 8,512 8,166
TOTAL ASSETS [1] 55,904 52,044
CURRENT LIABILITIES:    
Currently payable long-term debt 723 977
Short-term borrowings 325 550
Accounts payable 2,002 1,575
Accrued interest 373 269
Accrued taxes 768 727
Accrued compensation and benefits 286 205
Dividends payable 257 245
Customer deposits 250 233
Other 287 216
Total current liabilities 5,271 4,997
NONCURRENT LIABILITIES:    
Long-term debt and other long-term obligations 25,508 22,496
Accumulated deferred income taxes 6,032 5,613
Retirement benefits 1,469 1,698
Regulatory liabilities 1,185 995
Other 2,513 2,525
Total noncurrent liabilities 36,707 33,327
TOTAL LIABILITIES [1] 41,978 38,324
Common stockholders' equity-    
Common stock, $0.10 par value, authorized 700,000,000 shares - 577,851,052 and 576,612,245 shares outstanding as of December 31, 2025 and 2024, respectively 58 58
Other paid-in capital 12,431 12,368
Accumulated other comprehensive loss (14) (14)
Retained earnings 35 43
Total common stockholders' equity 12,510 12,455
Noncontrolling interest 1,416 1,265
TOTAL EQUITY 13,926 13,720
COMMITMENTS, GUARANTEES AND CONTINGENCIES (Note 14.)
TOTAL LIABILITIES AND EQUITY 55,904 52,044
Customer    
Receivables-    
Customers 1,783 1,585
Less — Allowance for uncollectible customer receivables 57 55
Receivable $ 1,726 $ 1,530
[1] As of December 31, 2025 and 2024, the combined assets of the VIEs were $13,269 million and $12,053 million, respectively, that can only be used to settle obligations of the VIEs. As of December 31, 2025 and 2024, these assets include, respectively: Cash and cash equivalents of $8 million and $8 million, Restricted cash of $40 million and $40 million, Accounts receivable of $92 million and $96 million, Materials and supplies, at average cost of $1 million and $1 million, Prepaid taxes and other current assets of $41 million and $22 million, Property, plant, and equipment of $12,475 million and $11,217 million, Goodwill of $224 million and $224 million, Investments of $19 million and $19 million,
Regulatory assets of $21 million and $92 million, and Other noncurrent assets of $348 million and $334 million. The consolidated liabilities as of December 31, 2025 and 2024, include $10,176 million and $9,147 million, respectively, of liabilities of VIEs whose creditors have no recourse to FE. As of December 31, 2025 and 2024, these liabilities include, respectively: Currently payable long-term debt of $126 million and $674 million, Short-term borrowings of $245 million and $300 million, Accrued interest of $108 million and $76 million, Accrued taxes of $335 million and $306 million, other current liabilities of $9 million and $10 million, Long-term debt and other long-term obligations of $6,884 million and $5,544 million, Accumulated deferred income taxes of $1,540 million and $1,411 million, Regulatory liabilities of $598 million and $526 million, and Other noncurrent liabilities of $331 million and $300 million.
v3.25.4
CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Receivables-    
Less — Allowance for uncollectible customer receivables $ 57 $ 55
Common stockholders' equity-    
Common stock, par value (in dollars per share) $ 0.10 $ 0.10
Common stock, authorized (in shares) 700,000,000 700,000,000
Common stock, outstanding (in shares) 577,851,052 576,612,245
CommonStockSharesIssuedNotDisclosed true  
Assets [1] $ 55,904 $ 52,044
Cash and cash equivalents 57 111
Restricted cash 42 43
Accounts receivable 1,726 1,530
Materials and supplies, at average cost 577 549
Prepaid taxes and other 282 240
Total PP&E 44,413 41,102
Goodwill 5,618 5,618
Investments 641 652
Regulatory assets 829 617
Other noncurrent assets 1,424 1,279
Total liabilities [1] 41,978 38,324
Currently payable long-term debt 723 977
Short-term borrowings 325 550
Accrued interest 373 269
Accrued taxes 768 727
Other current liabilities 287 216
Long-term debt and other long-term obligations 25,508 22,496
Accumulated deferred income taxes 6,032 5,613
Regulatory liabilities 1,185 995
Other noncurrent liabilities 2,513 2,525
Variable Interest Entity, Primary Beneficiary    
Common stockholders' equity-    
Assets 13,269 12,053
Cash and cash equivalents 8 8
Restricted cash 40 40
Materials and supplies, at average cost 1 1
Prepaid taxes and other 41 22
Total PP&E 12,475 11,217
Goodwill 224 224
Investments 19 19
Regulatory assets 21 92
Other noncurrent assets 348 334
Total liabilities 10,176 9,147
Currently payable long-term debt 126 674
Short-term borrowings 245 300
Accrued interest 108 76
Accrued taxes 335 306
Other current liabilities 9 10
Long-term debt and other long-term obligations 6,884 5,544
Accumulated deferred income taxes 1,540 1,411
Regulatory liabilities 598 526
Other noncurrent liabilities 331 300
Other Receivables    
Receivables-    
Less — Allowance for uncollectible customer receivables 11 6
Customer Receivables    
Receivables-    
Less — Allowance for uncollectible customer receivables 57 55
Common stockholders' equity-    
Accounts receivable 1,726 1,530
Customer Receivables | Variable Interest Entity, Primary Beneficiary    
Common stockholders' equity-    
Accounts receivable $ 92 $ 96
[1] As of December 31, 2025 and 2024, the combined assets of the VIEs were $13,269 million and $12,053 million, respectively, that can only be used to settle obligations of the VIEs. As of December 31, 2025 and 2024, these assets include, respectively: Cash and cash equivalents of $8 million and $8 million, Restricted cash of $40 million and $40 million, Accounts receivable of $92 million and $96 million, Materials and supplies, at average cost of $1 million and $1 million, Prepaid taxes and other current assets of $41 million and $22 million, Property, plant, and equipment of $12,475 million and $11,217 million, Goodwill of $224 million and $224 million, Investments of $19 million and $19 million,
Regulatory assets of $21 million and $92 million, and Other noncurrent assets of $348 million and $334 million. The consolidated liabilities as of December 31, 2025 and 2024, include $10,176 million and $9,147 million, respectively, of liabilities of VIEs whose creditors have no recourse to FE. As of December 31, 2025 and 2024, these liabilities include, respectively: Currently payable long-term debt of $126 million and $674 million, Short-term borrowings of $245 million and $300 million, Accrued interest of $108 million and $76 million, Accrued taxes of $335 million and $306 million, other current liabilities of $9 million and $10 million, Long-term debt and other long-term obligations of $6,884 million and $5,544 million, Accumulated deferred income taxes of $1,540 million and $1,411 million, Regulatory liabilities of $598 million and $526 million, and Other noncurrent liabilities of $331 million and $300 million.
v3.25.4
CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY - USD ($)
$ in Millions
Total
Total Common Stockholders' Equity
Common Stock
OPIC
AOCI
Retained Earnings (Accumulated Deficit)
NCI
Beginning balance (in shares) at Dec. 31, 2022     572,000,000        
Beginning balance at Dec. 31, 2022 $ 10,643 $ 10,166 $ 57 $ 11,322 $ (14) $ (1,199) $ 477
Increase (Decrease) in Stockholders' Equity [Roll Forward]              
Net income 1,176 1,102       1,102 74
Other comprehensive (loss) income, net of tax (3) (3)     (3)    
Cash dividends declared on common stock [1] (917) (917)   (917)      
Stock Investment Plan and share-based benefit plans (in shares)     2,000,000        
Stock Investment Plan and share-based benefit plans 89 89   89      
Noncontrolling interest distributions declared (72)           (72)
Ending balance (in shares) at Dec. 31, 2023     574,000,000        
Ending balance at Dec. 31, 2023 10,916 10,437 $ 57 10,494 (17) (97) 479
Increase (Decrease) in Stockholders' Equity [Roll Forward]              
Net income 1,127 978       978 149
Other comprehensive (loss) income, net of tax 3 3     3    
Cash dividends declared on common stock [1] (979) (979)   (141)   (838)  
Stock Investment Plan and share-based benefit plans (in shares)     3,000,000        
Stock Investment Plan and share-based benefit plans 74 74 $ 1 73      
FET Equity Interest Sale (Note 1.) 2,665 1,934   1,934     731
Noncontrolling interest distributions declared (86)           (86)
Other $ 0 8   8     (8)
Ending balance (in shares) at Dec. 31, 2024 576,612,245   577,000,000        
Ending balance at Dec. 31, 2024 $ 13,720 12,455 $ 58 12,368 (14) 43 1,265
Increase (Decrease) in Stockholders' Equity [Roll Forward]              
Net income 1,271 1,020       1,020 251
Other comprehensive (loss) income, net of tax 0            
Cash dividends declared on common stock [1] (1,028) (1,028)       (1,028)  
Stock Investment Plan and share-based benefit plans (in shares)     1,000,000        
Stock Investment Plan and share-based benefit plans 60 60   60      
Noncontrolling interest distributions declared (100)           (100)
Other $ 3 3   3      
Ending balance (in shares) at Dec. 31, 2025 577,851,052   578,000,000        
Ending balance at Dec. 31, 2025 $ 13,926 $ 12,510 $ 58 $ 12,431 $ (14) $ 35 $ 1,416
[1] Dividends declared for each share of common stock totaled: $1.78, $1.70 and $1.60, during 2025, 2024 and 2023, respectively.
v3.25.4
CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (Parenthetical) - $ / shares
 3 Months Ended 12 Months Ended
Dec. 31, 2025
Sep. 30, 2025
Jun. 30, 2025
Mar. 31, 2025
Dec. 31, 2024
Sep. 30, 2024
Jun. 30, 2024
Mar. 31, 2024
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Statement of Stockholders' Equity [Abstract]                      
Dividends declared (in dollars per share) $ 0.445 $ 0.890 $ 0 $ 0.445 $ 0.425 $ 0.850 $ 0 $ 0.425 $ 1.78 $ 1.70 $ 1.60
v3.25.4
CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
CASH FLOWS FROM OPERATING ACTIVITIES:      
Net income $ 1,271 $ 1,127 $ 1,176
Adjustments to reconcile net income to net cash from operating activities-      
Depreciation and amortization 1,607 1,446 1,255
Impairment of assets 352 142 15
Charges (credits) associated with changes in ARO (Note 9.) (54) 200 10
Employee benefit costs, net 14 (32) (9)
Pension and OPEB mark-to-market adjustments (253) 22 78
Deferred income taxes and investment tax credits, net 219 316 252
Transmission revenue collections, net 197 113 (180)
Pension trust contribution 0 0 (750)
Loss (gain) on disposal, net of tax 0 0 21
Changes in current assets and liabilities-      
Receivables (186) (249) (13)
Materials and supplies (28) (37) (91)
Prepaid taxes and other current assets (24) (33) (43)
Accounts payable 210 124 (141)
Accrued taxes 105 (126) 32
Accrued interest 104 (23) 38
Ohio settlement customer restitution and refunds (Note 13.) 275 0 0
Other current liabilities 4 (141) 41
Cash collateral, net 4 90 (218)
Employee benefit plan funding and related payments (49) (59) (50)
Other (68) 11 (36)
Net cash provided from operating activities 3,700 2,891 1,387
CASH FLOWS FROM INVESTING ACTIVITIES:      
Capital investments (4,705) (4,030) (3,356)
Sales of investment securities held in trusts 102 121 38
Purchases of investment securities held in trusts (114) (134) (50)
Asset removal costs (376) (305) (274)
Other 28 (2) (10)
Net cash used for investing activities (5,065) (4,350) (3,652)
New financing-      
Long-term debt 5,925 2,100 3,150
Short-term borrowings, net 0 0 675
Redemptions and repayments-      
Long-term debt (3,129) (2,760) (537)
Short-term borrowings, net (225) (225) 0
Proceeds from FET Equity Interest Sale (Note 1.) 0 3,500 0
Noncontrolling interest cash distributions (100) (86) (72)
Common stock dividend payments (1,016) (970) (906)
Debt issuance and redemption costs, and other (145) (125) (72)
Net cash provided from financing activities 1,310 1,434 2,238
Net change in cash, cash equivalents and restricted cash (55) (25) (27)
Cash, cash equivalents, and restricted cash at beginning of period 154 179 206
Cash, cash equivalents, and restricted cash at end of period 99 154 179
SUPPLEMENTAL CASH FLOW INFORMATION:      
Interest (net of amounts capitalized) 999 1,062 1,002
Income taxes, net of refunds 73 161 58
Significant non-cash transactions:      
Accrued capital investments 361 315 252
McElroy Run Transfer $ 99 $ 0 $ 0
v3.25.4
JCP&L STATEMENTS OF INCOME AND COMPREHENSIVE INCOME - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
REVENUES [1] $ 15,090 $ 13,472 $ 12,870
OPERATING EXPENSES:      
Purchased power 4,583 3,912 4,108
Other operating expenses 4,122 4,044 3,579
Provision for depreciation 1,664 1,581 1,461
Deferral of regulatory assets, net (109) (231) (261)
General taxes 1,345 1,212 1,164
Total operating expenses 12,884 11,097 10,604
OPERATING INCOME 2,206 2,375 2,266
OTHER INCOME (EXPENSE):      
Miscellaneous income, net 156 189 164
Pension and OPEB mark-to-market adjustments (Note 4.) 253 (22) (78)
Interest expense (1,217) (1,144) (1,124)
Capitalized financing costs 185 133 97
Total other expense (647) (871) (802)
INCOME BEFORE INCOME TAXES 1,559 1,504 1,464
INCOME TAXES 288 377 267
NET INCOME 1,271 1,127 1,176
STATEMENTS OF COMPREHENSIVE INCOME      
Net income 1,271 1,127 1,176
OTHER COMPREHENSIVE INCOME:      
Pension and OPEB prior service costs 0 1 (6)
Other comprehensive income (loss) 0 4 (4)
Income taxes on other comprehensive income 0 1 (1)
Other comprehensive income (loss), net of tax 0 3 (3)
COMPREHENSIVE INCOME 1,271 1,130 1,173
JERSEY CENTRAL POWER & LIGHT COMPANY      
REVENUES 2,638 2,315 2,027
OPERATING EXPENSES:      
Purchased power 1,402 1,155 1,037
Other operating expenses [2] 680 654 555
Provision for depreciation 263 249 231
Deferral of regulatory assets, net (134) (124) (67)
General taxes 23 21 21
Total operating expenses 2,234 1,955 1,777
OPERATING INCOME 404 360 250
OTHER INCOME (EXPENSE):      
Miscellaneous income, net 49 34 42
Pension and OPEB mark-to-market adjustments (Note 4.) 55 24 (29)
Capitalized financing costs 43 28 19
Total other expense 9 (31) (92)
INCOME BEFORE INCOME TAXES 413 329 158
INCOME TAXES 107 87 33
NET INCOME 306 242 125
STATEMENTS OF COMPREHENSIVE INCOME      
Net income 306 242 125
OTHER COMPREHENSIVE INCOME:      
Pension and OPEB prior service costs 0 1 0
Other comprehensive income (loss) 0 1 0
Income taxes on other comprehensive income 0 0 0
Other comprehensive income (loss), net of tax 0 1 0
COMPREHENSIVE INCOME 306 243 125
JERSEY CENTRAL POWER & LIGHT COMPANY | Nonrelated Party      
OTHER INCOME (EXPENSE):      
Interest expense (132) (97) (110)
JERSEY CENTRAL POWER & LIGHT COMPANY | Related Party      
REVENUES 1 1 1
OPERATING EXPENSES:      
Other operating expenses 116 118 122
OTHER INCOME (EXPENSE):      
Interest expense $ (6) $ (20) $ (14)
[1] Includes excise and gross receipts tax collections of $463 million, $429 million and $420 million in 2025, 2024 and 2023, respectively.
[2] Includes affiliated operating expenses of $116 million, $118 million and $122 million in 2025, 2024 and 2023, respectively.
v3.25.4
JCP&L STATEMENTS OF INCOME AND COMPREHENSIVE INCOME (Parenthetical) - USD ($)
$ in Millions
 3 Months Ended 6 Months Ended 9 Months Ended 12 Months Ended
Sep. 30, 2025
Jun. 30, 2025
Mar. 31, 2025
Sep. 30, 2024
Jun. 30, 2024
Mar. 31, 2024
Jun. 30, 2025
Jun. 30, 2024
Sep. 30, 2025
Sep. 30, 2024
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Other operating expenses                     $ 4,122 $ 4,044 $ 3,579
JERSEY CENTRAL POWER & LIGHT COMPANY                          
Other operating expenses $ 158 $ 137 $ 145 $ 180 $ 157 $ 186 $ 282 $ 343 $ 440 $ 523 680 [1] 654 [1] 555 [1]
Related Party | JERSEY CENTRAL POWER & LIGHT COMPANY                          
Other operating expenses                     $ 116 $ 118 $ 122
[1] Includes affiliated operating expenses of $116 million, $118 million and $122 million in 2025, 2024 and 2023, respectively.
v3.25.4
JCP&L BALANCE SHEETS - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Receivables-    
Customers $ 1,783 $ 1,585
Less: Uncollectible Reserve 57 55
Receivable 1,726 1,530
Prepaid taxes and other 282 240
Total current assets 2,979 2,776
PROPERTY, PLANT AND EQUIPMENT:    
In service 56,213 52,896
Less — Accumulated provision for depreciation 15,189 14,548
Net Plant 41,024 38,348
Construction work in progress 3,389 2,754
Total 44,413 41,102
INVESTMENTS AND OTHER NONCURRENT ASSETS:    
Goodwill 5,618 5,618
Investments 641 652
Regulatory assets 829 617
Other 1,424 1,279
Total investments and other noncurrent assets 8,512 8,166
TOTAL ASSETS [1] 55,904 52,044
CURRENT LIABILITIES:    
Currently payable long-term debt 723 977
Short-term borrowings 325 550
Accounts payable 2,002 1,575
Accrued compensation and benefits 286 205
Customer deposits 250 233
Accrued taxes 768 727
Accrued interest 373 269
Other 287 216
Total current liabilities 5,271 4,997
NONCURRENT LIABILITIES:    
Long-term debt and other long-term obligations 25,508 22,496
Accumulated deferred income taxes, net 6,032 5,613
Retirement benefits 1,469 1,698
Other 2,513 2,525
Total noncurrent liabilities 36,707 33,327
TOTAL LIABILITIES [1] 41,978 38,324
COMMON STOCKHOLDER'S EQUITY:    
Common stock, $10 par value, authorized 16,000,000 shares - 13,628,447 shares outstanding 58 58
Other paid-in capital 12,431 12,368
Accumulated other comprehensive loss (14) (14)
Retained earnings 35 43
Total common stockholders' equity 12,510 12,455
COMMITMENTS, GUARANTEES AND CONTINGENCIES (NOTE 14.)
TOTAL LIABILITIES AND EQUITY 55,904 52,044
Customer    
Receivables-    
Customers 1,783 1,585
Less: Uncollectible Reserve 57 55
Receivable 1,726 1,530
JERSEY CENTRAL POWER & LIGHT COMPANY    
Receivables-    
Customers 330 284
Less: Uncollectible Reserve 6 6
Receivable 324 278
Prepaid taxes and other 33 29
Total current assets 404 379
PROPERTY, PLANT AND EQUIPMENT:    
In service 9,267 8,731
Less — Accumulated provision for depreciation 2,439 2,439
Net Plant 6,828 6,292
Construction work in progress 880 620
Total 7,708 6,912
INVESTMENTS AND OTHER NONCURRENT ASSETS:    
Goodwill 1,811 1,811
Investments 297 282
Regulatory assets 515 247
Prepaid OPEB costs 243 215
Other 131 67
Total investments and other noncurrent assets 2,997 2,622
TOTAL ASSETS 11,109 9,913
CURRENT LIABILITIES:    
Currently payable long-term debt 2 1
Short-term borrowings 93 22
Accrued compensation and benefits 34 33
Customer deposits 35 34
Accrued taxes 11 21
Accrued interest 44 23
Other 41 34
Total current liabilities 538 345
NONCURRENT LIABILITIES:    
Long-term debt and other long-term obligations 3,023 2,339
Accumulated deferred income taxes, net 1,348 1,192
Nuclear fuel disposal costs 245 235
Retirement benefits 32 71
Other 763 764
Total noncurrent liabilities 5,411 4,601
TOTAL LIABILITIES 5,949 4,946
COMMON STOCKHOLDER'S EQUITY:    
Common stock, $10 par value, authorized 16,000,000 shares - 13,628,447 shares outstanding 136 136
Other paid-in capital 3,530 3,523
Accumulated other comprehensive loss (4) (4)
Retained earnings 1,498 1,312
Total common stockholders' equity 5,160 4,967
COMMITMENTS, GUARANTEES AND CONTINGENCIES (NOTE 14.)
TOTAL LIABILITIES AND EQUITY 11,109 9,913
JERSEY CENTRAL POWER & LIGHT COMPANY | Related Party    
Receivables-    
Receivable 22 44
CURRENT LIABILITIES:    
Accounts payable 103 1
JERSEY CENTRAL POWER & LIGHT COMPANY | Nonrelated Party    
Receivables-    
Receivable 25 28
CURRENT LIABILITIES:    
Accounts payable 175 176
JERSEY CENTRAL POWER & LIGHT COMPANY | Customer    
Receivables-    
Customers 330 284
Less: Uncollectible Reserve 6 6
Receivable $ 324 $ 278
[1] As of December 31, 2025 and 2024, the combined assets of the VIEs were $13,269 million and $12,053 million, respectively, that can only be used to settle obligations of the VIEs. As of December 31, 2025 and 2024, these assets include, respectively: Cash and cash equivalents of $8 million and $8 million, Restricted cash of $40 million and $40 million, Accounts receivable of $92 million and $96 million, Materials and supplies, at average cost of $1 million and $1 million, Prepaid taxes and other current assets of $41 million and $22 million, Property, plant, and equipment of $12,475 million and $11,217 million, Goodwill of $224 million and $224 million, Investments of $19 million and $19 million,
Regulatory assets of $21 million and $92 million, and Other noncurrent assets of $348 million and $334 million. The consolidated liabilities as of December 31, 2025 and 2024, include $10,176 million and $9,147 million, respectively, of liabilities of VIEs whose creditors have no recourse to FE. As of December 31, 2025 and 2024, these liabilities include, respectively: Currently payable long-term debt of $126 million and $674 million, Short-term borrowings of $245 million and $300 million, Accrued interest of $108 million and $76 million, Accrued taxes of $335 million and $306 million, other current liabilities of $9 million and $10 million, Long-term debt and other long-term obligations of $6,884 million and $5,544 million, Accumulated deferred income taxes of $1,540 million and $1,411 million, Regulatory liabilities of $598 million and $526 million, and Other noncurrent liabilities of $331 million and $300 million.
v3.25.4
JCP&L BALANCE SHEETS (Parenthetical) - $ / shares
Dec. 31, 2025
Dec. 31, 2024
COMMON STOCKHOLDER'S EQUITY:    
Common stock, par value (in dollars per share) $ 0.10 $ 0.10
Common stock, authorized (in shares) 700,000,000 700,000,000
Common stock, outstanding (in shares) 577,851,052 576,612,245
JERSEY CENTRAL POWER & LIGHT COMPANY    
COMMON STOCKHOLDER'S EQUITY:    
Common stock, par value (in dollars per share) $ 10 $ 10
Common stock, authorized (in shares) 16,000,000 16,000,000
Common stock, outstanding (in shares) 13,628,447 13,628,447
v3.25.4
JCP&L STATEMENTS OF COMMON STOCKHOLDER’S EQUITY - USD ($)
$ in Millions
Total
Common Stock
Other Paid-In Capital
AOCI
Retained Earnings
 [2]
JERSEY CENTRAL POWER & LIGHT COMPANY
JERSEY CENTRAL POWER & LIGHT COMPANY
Common Stock
JERSEY CENTRAL POWER & LIGHT COMPANY
Other Paid-In Capital
JERSEY CENTRAL POWER & LIGHT COMPANY
AOCI
JERSEY CENTRAL POWER & LIGHT COMPANY
Retained Earnings
Beginning balance (in shares) at Dec. 31, 2022   572,000,000         13,628,447      
Beginning balance at Dec. 31, 2022           $ 3,968 $ 136 $ 2,742 $ (5) $ 1,095
Increase (Decrease) in Stockholders' Equity [Roll Forward]                    
Net income $ 1,102         125       125
Comprehensive income (3)     $ (3)   0        
Stock-based compensation [1]           5   5    
Equity contribution from parent           30   30    
Cash dividend declared on common stock [2] (917)   $ (917)              
Ending balance (in shares) at Dec. 31, 2023   574,000,000         13,628,447      
Ending balance at Dec. 31, 2023           4,128 $ 136 2,777 (5) 1,220
Increase (Decrease) in Stockholders' Equity [Roll Forward]                    
Net income           (9)        
Ending balance at Mar. 31, 2024           4,261        
Beginning balance (in shares) at Dec. 31, 2023   574,000,000         13,628,447      
Beginning balance at Dec. 31, 2023           4,128 $ 136 2,777 (5) 1,220
Increase (Decrease) in Stockholders' Equity [Roll Forward]                    
Net income 978         242       242
Comprehensive income 3     $ 3   1     1  
Stock-based compensation [1]           6   6    
Equity contribution from parent           740   740    
Cash dividend declared on common stock $ (979) [2]   $ (141) [2]   $ (838) $ (150)       (150)
Ending balance (in shares) at Dec. 31, 2024 576,612,245 577,000,000       13,628,447 13,628,447      
Ending balance at Dec. 31, 2024 $ 12,455         $ 4,967 $ 136 3,523 (4) 1,312
Beginning balance at Mar. 31, 2024           4,261        
Increase (Decrease) in Stockholders' Equity [Roll Forward]                    
Net income           55        
Ending balance at Jun. 30, 2024           4,917        
Increase (Decrease) in Stockholders' Equity [Roll Forward]                    
Net income           107        
Ending balance at Sep. 30, 2024           5,026        
Beginning balance at Dec. 31, 2024 $ 12,455         4,967 $ 136 3,523 (4) 1,312
Increase (Decrease) in Stockholders' Equity [Roll Forward]                    
Net income           47        
Ending balance at Mar. 31, 2025           $ 4,986        
Beginning balance (in shares) at Dec. 31, 2024 576,612,245 577,000,000       13,628,447 13,628,447      
Beginning balance at Dec. 31, 2024 $ 12,455         $ 4,967 $ 136 3,523 (4) 1,312
Increase (Decrease) in Stockholders' Equity [Roll Forward]                    
Net income 1,020         306       306
Comprehensive income 0         0        
Stock-based compensation [1]           7   7    
Cash dividend declared on common stock $ (1,028) [2]       $ (1,028) $ (120)       (120)
Ending balance (in shares) at Dec. 31, 2025 577,851,052 578,000,000       13,628,447 13,628,447      
Ending balance at Dec. 31, 2025 $ 12,510         $ 5,160 $ 136 $ 3,530 $ (4) $ 1,498
Beginning balance at Mar. 31, 2025           4,986        
Increase (Decrease) in Stockholders' Equity [Roll Forward]                    
Net income           62        
Ending balance at Jun. 30, 2025           5,049        
Increase (Decrease) in Stockholders' Equity [Roll Forward]                    
Net income           118        
Ending balance at Sep. 30, 2025           $ 5,079        
[1] In the form of FE common equity granted to certain JCP&L employees primarily related to the 401(k) Savings Plan.
[2] Dividends declared for each share of common stock totaled: $1.78, $1.70 and $1.60, during 2025, 2024 and 2023, respectively.
v3.25.4
JCP&L STATEMENTS OF CASH FLOWS - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
CASH FLOWS FROM OPERATING ACTIVITIES:      
Net income $ 1,271 $ 1,127 $ 1,176
Adjustments to reconcile net income to net cash from operating activities-      
Depreciation, amortization, and impairments 1,607 1,446 1,255
Transmission revenue collections, net 197 113 (180)
Deferred income taxes and investment tax credits, net 219 316 252
Employee benefit costs, net 14 (32) (9)
Pension and OPEB mark-to-market adjustments (253) 22 78
Changes in current assets and liabilities-      
Receivables (186) (249) (13)
Prepaid taxes and other current assets (24) (33) (43)
Accounts payable 210 124 (141)
Accrued taxes 105 (126) 32
Accrued interest 104 (23) 38
Other current liabilities 4 (141) 41
Collateral, net 4 90 (218)
Employee benefit plan funding and related payments (49) (59) (50)
Other (68) 11 (36)
Net cash provided from operating activities 3,700 2,891 1,387
CASH FLOWS FROM INVESTING ACTIVITIES:      
Capital investments (4,705) (4,030) (3,356)
Sales of investment securities held in trusts 102 121 38
Purchases of investment securities held in trusts (114) (134) (50)
Asset removal costs (376) (305) (274)
Other 28 (2) (10)
Net cash used for investing activities (5,065) (4,350) (3,652)
New financing-      
Long-term debt 5,925 2,100 3,150
Short-term borrowings 0 0 675
Redemptions and repayments-      
Long-term debt (3,129) (2,760) (537)
Short-term borrowings (225) (225) 0
Common stock dividend payments (1,016) (970) (906)
Other (145) (125) (72)
Net cash provided from financing activities 1,310 1,434 2,238
Cash, cash equivalents, and restricted cash at beginning of period 154 179 206
Cash, cash equivalents, and restricted cash at end of period 99 154 179
SUPPLEMENTAL CASH FLOW INFORMATION:      
Interest (net of amounts capitalized) 999 1,062 1,002
Income taxes, net of refunds 73 161 58
Significant non-cash transactions:      
Accrued capital investments 361 315 252
JERSEY CENTRAL POWER & LIGHT COMPANY      
CASH FLOWS FROM OPERATING ACTIVITIES:      
Net income 306 242 125
Adjustments to reconcile net income to net cash from operating activities-      
Depreciation, amortization, and impairments 130 172 152
Transmission revenue collections, net 21 6 (14)
Deferred income taxes and investment tax credits, net 143 230 48
Spent nuclear fuel disposal trust income 13 12 12
New Jersey temporary rate credits, net (20) 0 0
Employee benefit costs, net (24) (22) (27)
Pension and OPEB mark-to-market adjustments (55) (24) 29
Changes in current assets and liabilities-      
Receivables (21) (32) (6)
Prepaid taxes and other current assets 0 6 (9)
Accounts payable 87 (7) (6)
Accrued taxes (10) 17 1
Accrued interest 21 (4) 1
Other current liabilities 4 0 (3)
Collateral, net 0 29 (57)
Employee benefit plan funding and related payments 0 (7) (7)
Other (24) (9) 25
Net cash provided from operating activities 571 609 264
CASH FLOWS FROM INVESTING ACTIVITIES:      
Capital investments (1,105) (879) (633)
Sales of investment securities held in trusts 102 121 38
Purchases of investment securities held in trusts (114) (134) (50)
Asset removal costs (84) (57) (45)
Other (3) 0 0
Net cash used for investing activities (1,204) (949) (690)
New financing-      
Long-term debt 1,350 700 0
Redemptions and repayments-      
Long-term debt (650) (500) 0
Equity contribution from parent 0 740 30
Common stock dividend payments (120) (150) 0
Other (18) (10) (1)
Net cash provided from financing activities 633 340 426
Net change in cash, cash equivalents and restricted cash 0 0 0
Cash, cash equivalents, and restricted cash at beginning of period 0 0 0
Cash, cash equivalents, and restricted cash at end of period 0 0 0
SUPPLEMENTAL CASH FLOW INFORMATION:      
Interest (net of amounts capitalized) 99 96 108
Income taxes, net of refunds (15) (101) (11)
Significant non-cash transactions:      
Accrued capital investments 92 82 59
JERSEY CENTRAL POWER & LIGHT COMPANY | Related Party      
New financing-      
Short-term borrowings 71 0 197
Redemptions and repayments-      
Short-term borrowings 0 (240) 0
JERSEY CENTRAL POWER & LIGHT COMPANY | Nonrelated Party      
New financing-      
Short-term borrowings 0 0 200
Redemptions and repayments-      
Short-term borrowings $ 0 $ (200) $ 0
v3.25.4
ORGANIZATION AND BASIS OF PRESENTATION
 12 Months Ended
Dec. 31, 2025
Organization, Consolidation and Presentation of Financial Statements [Abstract]  
ORGANIZATION AND BASIS OF PRESENTATION ORGANIZATION AND BASIS OF PRESENTATION
Defined terms and abbreviations used herein have the meanings set forth in the accompanying Glossary of Terms. This is a combined set of financial statements filed separately for FirstEnergy and JCP&L. Unless otherwise indicated, the disclosures in these notes apply to each of the Registrants. For clarification purposes, disclosures made herein on behalf of FirstEnergy should be read to be made on behalf of JCP&L unless expressly stated otherwise.

FirstEnergy

FE was incorporated under Ohio law in 1996. FE’s principal business is the holding, directly or indirectly, of all of the outstanding equity of its principal subsidiaries: OE, CEI, TE, FE PA, JCP&L, FESC, MP, AGC, PE and KATCo. Additionally, FET is a VIE of FE, and is the parent company of ATSI, MAIT and TrAIL. FirstEnergy continues to evaluate the legal, financial, operational and branding benefits of consolidating the Ohio Companies into a single Ohio power company.

FET also owns a 34% equity interest in Valley Link. On November 25, 2024, FET, DominionHV, and Transource formed Valley Link, which is the holding company responsible for managing and executing those projects awarded by PJM, and entered into a limited liability agreement. Valley Link is the owner of the Valley Link Subsidiaries, which are organized in various states. The Valley Link Subsidiaries comprise the entities that are expected to develop, construct, own, operate and maintain those transmission projects awarded by PJM.
In addition, FE holds all of the outstanding equity of other direct subsidiaries including FEV, which previously held a 33-1/3% equity ownership in Global Holding, the holding company for a joint venture in the Signal Peak mining and coal transportation operations. On July 16, 2025, FEV sold its entire 33-1/3% equity ownership in Global Holding, the holding company for a joint venture in the Signal Peak mining and coal transportation operations, at book value to WMB Marketing Ventures, LLC and Pinesdale LLC for $47.5 million.
FESC provides legal, financial and other corporate support services at cost, in accordance with its cost allocation manual, to affiliated FirstEnergy companies. FE does not bill directly or allocate any of its costs to any subsidiary company. Costs are charged to FE's subsidiaries for services received from FESC either through direct billing or through an allocation process. Allocated costs are for services that are provided on behalf of more than one company and are allocated using formulas developed by FESC and are generally settled under commercial terms within thirty days.
FE and its subsidiaries are principally involved in the transmission, distribution, and generation of electricity. FirstEnergy’s electric operating companies comprise one of the nation’s largest investor-owned electric systems, serving over six million customers in the Midwest and Mid-Atlantic regions. FirstEnergy’s transmission operations include more than 24,000 miles of transmission lines and two regional transmission operation centers, and MP and AGC control 3,610 MWs of total generation capacity.
JCP&L

JCP&L owns property and does business as an electric public utility in New Jersey, providing distribution services to approximately 1.2 million customers, as well as transmission services in northern, western, and east central New Jersey. JCP&L serves an area that has a population of approximately 2.8 million. JCP&L plans, operates, and maintains its transmission system in accordance with NERC reliability standards, and other applicable regulatory requirements. In addition, JCP&L complies with the regulations, orders, policies and practices prescribed by FERC and the NJBPU.
Revision of Previously Issued Financial Statements of JCP&L

During the fourth quarter of 2025, JCP&L identified an error in the recording of certain expenses for smart meter cost of removal associated with the deployment of its AMI program, resulting in an understatement of expense on the Statements of Income and Comprehensive Income and Regulatory assets/liabilities on the Balance Sheets since 2023. The identified error impacted JCP&L's previously issued 2023 and 2024 annual financial statements, and interim periods in 2024 and 2025. JCP&L evaluated the error, and the specific impact on each affected prior period was not material, however, as a result of the cumulative impact, JCP&L determined to revise previously issued financial statements to correct the error and in doing so also corrected certain other previously identified immaterial errors, including the misclassification of certain retired assets. As such, JCP&L has revised the previously issued Statements of Income and Comprehensive Income, Statement of Cash Flows and Statements of Common Stockholder’s Equity for the annual periods ended December 31, 2024 and 2023 in this Form 10-K as well as the Balance Sheets as of December 31, 2024 and 2023, and any applicable footnote disclosures.

A summary of the corrections to the impacted financial statement line items in JCP&L’s previously issued Statements of Income and Comprehensive Income, Balance Sheets, Statements of Cash Flows and the Statements of Common Stockholder’s Equity for each interim affected period is presented in Note 17., “Revision of Previously Issued Quarterly Financial Statements (JCP&L)," of the Combined Notes to Financial Statements of the Registrants. The amounts in the tables below summarize the adjustments to revise JCP&L previously reported audited annual financial statements. JCP&L will also revise previously reported financial information for this error in its future filings, as applicable.
JCP&L Annual Statements of Income and Comprehensive Income

For the Year Ended December 31, 2024For the Year Ended December 31, 2023
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
Deferral of regulatory assets, net$(135)$11 $(124)$(74)$7 $(67)
Other operating expenses656 (2)654 555 — 555 
Total operating expenses 1,946 9 1,955 1,770 7 1,777 
Operating income369 (9)360 257 (7)250 
Income before income taxes338 (9)329 165 (7)158 
Income taxes90 (3)87 35 (2)33 
Net income248 (6)242 130 (5)125 
Comprehensive income 249 (6)243 130 (5)125 

JCP&L Annual Balance Sheets
As of December 31, 2024As of December 31, 2023
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
PP&E - In service$8,697 $34 $8,731 $8,278 $10 $8,288 
Accumulated provision for depreciation 2,409 30 2,439 2,365 8 2,373 
PP&E Excluding CWIP6,288 4 6,292 5,913 2 5,915 
Total PP&E6,908 4 6,912 6,388 2 6,390 
Regulatory assets/(liabilities)265 (18)247 (48)(8)(56)
Total investments and other noncurrent assets2,640 (18)2,622 2,330 — 2,330 
Total assets 9,927 (14)9,913 9,100 2 9,102 
Accumulated deferred income taxes, net1,196 (4)1,192 957 (2)955 
Total noncurrent liabilities4,605 (4)4,601 3,717 6 3,723 
Total liabilities4,950 (4)4,946 4,968 6 4,974 
Retained earnings 1,322 (10)1,312 1,224 (4)1,220 
Total common stockholder's equity4,977 (10)4,967 4,132 (4)4,128 

JCP&L Annual Statements of Common Stockholder's Equity
For the Years Ended December 31, 2024 and 2023
(In millions)As Reported AdjustmentAs Revised
Balance, January 1, 2023$3,967 $1 $3,968 
Net income130 (5)125 
Balance, December 31, 20234,132 (4)4,128 
Net income248 (6)242 
Balance, December 31, 20244,977 (10)4,967 
JCP&L Annual Statements of Cash Flows
For the Year Ended
December 31, 2024		For the Year Ended
December 31, 2023
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income$248 $(6)$242 $130 $(5)$125 
Adjustments to reconcile net income to net cash from operating activities-
Depreciation, amortization and impairments161 11 172 145 7 152 
Deferred income taxes and investment tax credits, net233 (3)230 50 (2)48 
Net cash provided from operating activities607 2 609 264 — 264 
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital investments$(877)$(2)$(879)$(633)$— $(633)
Net cash used for investing activities(947)(2)(949)(690)— (690)
Net change in cash, cash equivalents, and restricted cash$— $— $— $— $— $— 
Basis of Presentation

The Registrants follow GAAP and comply with the related regulations, orders, policies and practices prescribed by the SEC, FERC, and, as applicable, the PUCO, the PPUC, the MDPSC, the NYPSC, the WVPSC, the VSCC and the NJBPU. The preparation of financial statements in conformity with GAAP requires management to make periodic estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and disclosure of contingent assets and liabilities. Actual results could differ from these estimates. The reported results of operations are not necessarily indicative of results of operations for any future period. The Registrants have evaluated events and transactions for potential recognition or disclosure through the date the financial statements were issued.

The Registrants consolidate all majority-owned subsidiaries over which they exercise control and, when applicable, entities for which they have a controlling financial interest. Intercompany transactions and balances are eliminated in consolidation as appropriate and permitted pursuant to GAAP. The Registrants consolidate a variable interest entity when it is determined that it is the primary beneficiary. Investments in affiliates over which the Registrants have the ability to exercise significant influence, but do not have a controlling financial interest, follow the equity method of accounting. Under the equity method, the interest in the entity is reported as an investment on the Balance Sheets and the percentage of ownership share of the entity’s earnings is reported in the Statements of Income.

During the second quarter of 2025, FirstEnergy identified certain corporate support operating expenses recognized in 2024 that should have been capitalized as CWIP or PP&E. As a result, in the second quarter of 2025, FirstEnergy recognized a $21 million net increase to income before income taxes. In addition, during the fourth quarter of 2025, JCP&L identified an error in the recording of certain expenses for smart meter cost of removal associated with the deployment of its AMI program. As a result, FirstEnergy recognized a $24 million net decrease to income before income taxes in the fourth quarter of 2025, of which $18 million is related to prior years. These adjustments were immaterial to FirstEnergy’s 2025 and prior period financial statements.

Certain prior year amounts have been reclassified to conform to the current year presentation.

Economic Conditions

While supply lead times have not fully returned to levels prior to the COVID-19 pandemic, FirstEnergy continues to monitor the situation in light of demand increases across the industry, including due to data center usage, and the imposition of tariffs and retaliatory tariffs that have been, and may be, imposed by the U.S. government in response. FirstEnergy continues to implement mitigation strategies to address supply constraints and does not expect any corresponding service disruptions or any material impact on its capital investment plan. However, the situation remains fluid, and a prolonged continuation or further increase in demand, or the continuation of uncertain or adverse macroeconomic conditions, including inflationary pressures and new or increased existing tariffs, could lead to an increase in supply chain disruptions that could, in turn, have an adverse effect on the Registrants’ results of operations, cash flow and financial condition.
The U.S. presidential administration has imposed widespread and substantial tariffs on imports, with additional tariffs to potentially be adopted in the future. The imposition of these or any other new or increased tariffs or resultant trade wars, and uncertainties associated with the same, could have an adverse effect on the Registrants’ results of operations, cash flow and financial condition.

Reorganization

On March 24, 2025, FirstEnergy internally announced organizational changes that are intended to align the organization with its new business model, which is designed to make FirstEnergy more efficient and sustainable while placing responsibility and accountability closer to customers, employees and regulators. The changes are also consistent with FirstEnergy’s focus on operations and maintenance expense discipline. As a result, FirstEnergy recognized a pre-tax charge of approximately $26 million ($5 million at JCP&L) in the first quarter of 2025, which is included within “Other operating expenses” on each of the Registrants' Statements of Income and Comprehensive Income.

Discontinued Operations - FirstEnergy

On February 27, 2020, certain former competitive subsidiaries of FE emerged from bankruptcy and were deconsolidated from FirstEnergy’s consolidated federal income tax group. The bankruptcy, emergence and deconsolidation resulted in FirstEnergy recognizing certain income tax benefits and charges, which were classified as discontinued operations. During 2023, FirstEnergy recognized a $21 million tax-effected charge to income tax expense as a result of identifying an out of period adjustment related to the allocation of certain deferred income tax liabilities associated with such former subsidiaries and their tax return deconsolidation in 2020. This adjustment was immaterial to the 2023 and prior period financial statements.

Discontinued operations are reflected at Corporate/Other for FirstEnergy segment reporting and within “Discontinued Operations” on the FirstEnergy Consolidated Statements of Income and Comprehensive Income and “Loss on disposal, net of tax” on the FirstEnergy Consolidated Statements of Cash Flow.
ACCOUNTING FOR THE EFFECTS OF REGULATION

The Registrants are subject to regulation that sets the prices (rates) they are permitted to charge customers based on costs that the regulatory agencies determine are permitted to be recovered. At times, regulatory agencies permit the future recovery of costs that would be currently charged to expense by an unregulated company. The ratemaking process results in the recording of regulatory assets and liabilities based on anticipated future cash inflows and outflows.

The Registrants review the probability of recovery of regulatory assets, and settlement of regulatory liabilities, at each balance sheet date and whenever new events occur. Factors that may affect probability include changes in the regulatory environment, issuance of a regulatory commission order, or passage of new legislation. Upon material changes to these factors, where applicable, the Registrants will record new regulatory assets or liabilities and will assess whether it is probable that currently recorded regulatory assets and liabilities will be recovered or settled in future rates. If recovery of a regulatory asset is no longer probable, the Registrants will write off that regulatory asset as a charge against earnings. The Registrants consider the entire regulatory asset balance as the unit of account for the purposes of balance sheet classification rather than the next years recovery and, as such, net regulatory assets and liabilities are presented in the noncurrent section on the Registrants' Balance Sheets. See Note 13., "Regulatory Matters," of the Combined Notes to Financial Statements of the Registrants for additional information.
FirstEnergy has regulatory assets of $829 million and $617 million, and regulatory liabilities of $1,185 million and $995 million as of December 31, 2025 and 2024, respectively. The following table provides information about the composition of FirstEnergy's net regulatory assets and liabilities as of December 31, 2025 and 2024, and the changes during the year 2025:
As of December 31,
Net Regulatory Assets (Liabilities) by Source - FirstEnergy20252024Change
 (In millions)
Customer payables for future income taxes$(2,041)$(2,234)$193 
Spent nuclear fuel disposal costs(76)(72)(4)
Asset removal costs(675)(681)6 
Deferred transmission costs(43)190 (233)
Deferred generation costs405 481 (76)
Deferred distribution costs466 287 179 
Storm-related costs1,122 1,015 107 
Energy efficiency program costs462 349 113 
New Jersey societal benefit costs80 87 (7)
Vegetation management153 125 28 
Ohio settlement charges(250)— (250)
Other41 75 (34)
Net Regulatory Liabilities included on FirstEnergy's Consolidated Balance Sheets$(356)$(378)$22 

The following table provides information about the composition of JCP&L's net regulatory assets and liabilities as of December 31, 2025 and 2024, and the changes during the year 2025:
As of December 31,
Net Regulatory Assets (Liabilities) by Source - JCP&L20252024Change
(In millions)
Customer payables for future income taxes$(393)$(410)$17 
Spent nuclear fuel disposal costs(76)(72)(4)
Asset removal costs (1)
(87)(101)14 
Deferred transmission costs(25)(3)(22)
Deferred distribution costs318 206 112 
Storm-related costs367 310 57 
Energy efficiency program costs316 208 108 
New Jersey societal benefit costs80 87 (7)
Other15 22 (7)
Net Regulatory Assets included on JCP&L's Balance Sheets$515 $247 $268 
(1) Previously issued 2024 JCP&L amounts have been revised due to the correction of immaterial errors as discussed in Note 1., "Organization and Basis of Presentation," of the Combined Notes to Financial Statements of the Registrants.
The following table provides information about the composition of FirstEnergy's net regulatory assets that do not earn a current return as of December 31, 2025 and 2024, of which approximately $802 million and $698 million, respectively, are currently being recovered through rates over varying periods, through 2068, depending on the nature of the deferral and the jurisdiction:
Regulatory Assets by Source Not Earning aAs of December 31,
Current Return - FirstEnergy20252024Change
(In millions)
Deferred generation costs$280 $314 $(34)
Deferred distribution costs199 153 46 
Storm-related costs844 694 150 
Other102 82 20 
FirstEnergy Regulatory Assets Not Earning a Current Return$1,425 $1,243 $182 

The following table provides information about the composition of JCP&L's net regulatory assets that do not earn a current return as of December 31, 2025 and 2024, of which approximately $76 million and $45 million, respectively, are currently being recovered through rates over varying periods, through 2068, depending on the nature of the deferral:
Regulatory Assets by Source Not Earning aAs of December 31,
Current Return - JCP&L20252024Change
(In millions)
Deferred distribution costs$147 $101 $46 
Storm-related costs367 310 57 
Other24 28 (4)
JCP&L Regulatory Assets Not Earning a Current Return$538 $439 $99 
DERIVATIVES

FirstEnergy may use various market risk sensitive instruments, including derivative contracts, primarily to manage the risk of price and interest rate fluctuations. FirstEnergy’s Enterprise Risk Management Committee, comprised of members of senior management, provides general oversight for risk management activities throughout FirstEnergy, including market risk.
The Registrants account for derivative instruments on the Balance Sheets at fair value unless they meet the normal purchases and normal sales criteria. Derivative instruments meeting the normal purchases and normal sales criteria are accounted for under the accrual method of accounting with their effects included in earnings at the time of contract performance.
EQUITY METHOD INVESTMENTS
Investments over which the Registrants have the ability to exercise significant influence, but do not have a controlling financial interest, follow the equity method of accounting. Under the equity method, the interest in the entity is reported in “Investments” on the Registrants Balance Sheets. The percentage of ownership share of the entity’s earnings is reported in the Registrants Statement of Income and reflected in “Other income (expense)”. Equity method investments are assessed for impairment annually or whenever events and changes in circumstances indicate that the carrying amount of the investment may not be recoverable. If the decline in value is considered to be other than temporary, the investment is written down to its estimated fair value, which establishes a new cost basis in the investment.
Equity method investments included within "Investments" on FirstEnergy's Consolidated Balance Sheets were $38 million and $84 million as of December 31, 2025 and 2024, respectively. JCP&L did not have any equity method investments as of December 31, 2025 or 2024.
Global Holdings - On July 16, 2025, FEV sold its entire 33-1/3% equity ownership in Global Holding, the holding company for a joint venture in the Signal Peak mining and coal transportation operations, at book value to WMB Marketing Ventures, LLC and Pinesdale LLC for $47.5 million, which is classified in other within “Cash from Investing Activities” of FirstEnergy’s Consolidated Statements of Cash Flows.
In previous periods, FEV was not the primary beneficiary of the joint venture, as it did not have control over the significant activities affecting the joint venture’s economic performance. FEV's ownership interest was subject to the equity method of accounting. For the years ended December 31, 2024 and 2023, pre-tax equity earnings, excluding impairments, related to FEV’s ownership in Global Holding was $72 million and $175 million, respectively. FEV’s pre-tax equity earnings and investment in Global Holding are included in Corporate/Other for segment reporting. In 2024, a $13 million (pre-tax) impairment charge was
recognized in the fourth quarter of 2024 and is included within "Equity method investment earnings, net” on the Consolidated Statements of Income and within Corporate/Other for segment reporting.
As of December 31, 2024, the carrying value of the equity method investment was $45 million. During 2024 and 2023, FEV received cash dividends from Global Holding totaling $80 million and $165 million, respectively, which were classified with “Cash from Operating Activities” on FirstEnergy’s Consolidated Statements of Cash Flow.
Valley Link - On February 21, 2025, FET, DominionHV and Transource entered into the Valley Link Operating Agreement, which established the general framework for Valley Link and the Valley Link Subsidiaries to accept, design, develop, construct, own, operate and finance those transmission projects awarded by PJM to Valley Link. This general framework includes parameters regarding the relationship among the three members, confers governance rights to its members so long as certain ownership percentages are maintained, as described below, and defines the list of projects that Valley Link will have the right to develop. Valley Link is the owner of the Valley Link Subsidiaries, which are organized in various states. On February 26, 2025, in response to the PJM 2024 RTEP Long-Term Proposal Window #1, PJM awarded two electric transmission projects to Valley Link estimated to be approximately $3 billion, with FET’s share estimated to be approximately $1 billion.
As of February 21, 2025, the relative ownership interests of the members are FET (34%), DominionHV (30%), and Transource (36%), and Valley Link will not be consolidated with FET for financial or tax reporting purposes and expects to be accounted for under equity method accounting. As of December 31, 2025, and 2024, there were no investment balances recorded on FirstEnergy’s Consolidated Balance Sheets.
PATH WV - A subsidiary of FE owns 50% of the West Virginia Series (PATH-WV), which is a joint venture with a subsidiary of AEP. FirstEnergy is not the primary beneficiary of PATH-WV, as it does not have control over the significant activities affecting the economics of PATH-WV. FirstEnergy's ownership interest in PATH-WV is subject to the equity method of accounting.
In March 2024, PATH completed the process of terminating all of its FERC-jurisdictional rates and facilities, with the result that PATH no longer is a “public utility” and no longer is subject to FERC jurisdiction. FirstEnergy and its non-affiliated joint venture partner are in the process of terminating the PATH corporate entities. As of December 31, 2025 and 2024, the carrying value of the equity method investment was $17 million, which is expected to be recovered through a distribution. FirstEnergy's pre-tax equity earnings in PATH-WV were immaterial for the years ended December 31, 2025, 2024 and 2023.
GOODWILL

In a business combination, the excess of the purchase price over the estimated fair value of the assets acquired and liabilities assumed is recognized as goodwill. The Registrants evaluates goodwill for impairment annually on July 31 and more frequently if indicators of impairment arise. In evaluating goodwill for impairment, the Registrants assess qualitative factors to determine whether it is more likely than not (that is, likelihood of more than 50%) that the fair value of a reporting unit is less than its carrying value (including goodwill). If the Registrants conclude that it is not more likely than not that the fair value of a reporting unit is less than its carrying value, then no further testing is required. However, if the Registrants conclude that it is more likely than not that the fair value of a reporting unit is less than its carrying value or bypasses the qualitative assessment, then the quantitative goodwill impairment test is performed to identify a potential goodwill impairment and measure the amount of impairment to be recognized, if any.

As of July 31, 2025, the Registrants performed a qualitative assessment of its reporting units' goodwill, assessing economic, industry and market considerations in addition to the reporting units' overall financial performance. Key factors used in the assessment included: growth rates, interest rates, expected investments, utility sector market performance, regulatory and legal developments, and other market considerations. It was determined that the fair values of these reporting units were, more likely than not, greater than their carrying values and a quantitative analysis was not necessary.

FirstEnergy's reporting units are consistent with its reportable segments and consist of Distribution, Integrated and Stand-Alone Transmission. The following table presents goodwill by reporting unit as of December 31, 2025 and 2024:
(In millions)Distribution SegmentIntegrated SegmentStand-Alone Transmission SegmentFirstEnergy Consolidated
Goodwill$3,222 $1,953 $443 $5,618 

JCP&L's reporting units are consistent with its reportable segments and consist of Distribution and Transmission. The following table presents goodwill by reporting unit as of December 31, 2025 and 2024:
(In millions)Distribution Segment Transmission SegmentJCP&L
Goodwill$1,213 $598 $1,811 
IMPAIRMENT OF LONG-LIVED ASSETS
The Registrants evaluate long-lived assets classified as held and used for impairment when events or changes in circumstances indicate the carrying value of the long-lived assets may not be recoverable. First, the estimated undiscounted future cash flows attributable to the assets is compared with the carrying value of the assets. If the carrying value is greater than the undiscounted future cash flows, an impairment charge is recognized equal to the amount the carrying value of the assets exceeds its estimated fair value.

The following impairment charges were recognized in the years ended December 31, 2025 and 2024:

•In the fourth quarter of 2025, FirstEnergy recognized a $352 million pre-tax charge, included within “Impairment of assets” on FirstEnergy’s Consolidated Statements of Income, as a result of the November 2025 Ohio Base Rate Case order that disallowed from future recovery certain previously capitalized amounts at the Ohio Companies. The charge was reflected at FirstEnergy’s Distribution segment. See Note 13., "Regulatory Matters," of the Combined Notes to Financial Statements of the Registrants for additional details.

•In the first quarter of 2024, JCP&L recognized a $53 million pre-tax charge (included within “Impairment of assets” on the FirstEnergy Consolidated Statements of Income and "Other operating expenses" on the JCP&L Statements of Income and Comprehensive Income) associated with certain corporate support costs recorded to capital accounts from the FERC Audit that were determined, as a result of the base rate case settlement agreement, to be disallowed from future recovery. The charge was reflected at JCP&L's Distribution segment, and FirstEnergy's Integrated segment.

•The Akron general office building was classified as held-for-sale during the third quarter of 2024. Upon classification as held-for-sale, FirstEnergy recognized a $62 million ($9 million at JCP&L and included within "Other operating expenses") pre-tax impairment charge within “Impairment of assets” on the FirstEnergy Consolidated Statements of Income and "Other operating expenses" on the JCP&L Statements of Income and Comprehensive Income. Of the $62 million, $17 million is included within the Integrated segment, $31 million is included within Distribution segment, $11 million is included within Stand-Alone Transmission segment and $3 million at Corporate/Other for FirstEnergy's segment reporting. During the third quarter of 2025, the sale of the Akron general office building was completed.
INVENTORY

Materials and supplies inventory primarily includes fuel inventory, the distribution, transmission and electric generation facility materials, net of reserve for excess and obsolete inventory as well as emission allowances. Materials charged to inventory are at weighted average cost when purchased and expensed or capitalized, as appropriate, when used or installed. Fuel inventory consists primarily of coal and reagents that are consumed at MP's electric generation facilities, and is accounted for at weighted average cost when purchased and recorded to fuel expense when consumed.

Emission allowances are accounted for as inventory at cost when purchased. FirstEnergy’s emission allowance compliance obligation, principally associated with MP's electric generation facility operations, is accrued to fuel expense at a weighted average cost based on each month’s emissions. When emission allowances are submitted to the EPA, inventory and the compliance obligation are reduced. Due to the ENEC, fuel, emission allowances and other fuel-related expenses have no material impact on current period earnings.
NONCONTROLLING INTEREST

FirstEnergy - FirstEnergy maintains a controlling financial interest in certain less than wholly owned subsidiaries. As a result, FirstEnergy presents the third-party investors’ ownership portion of FirstEnergy's net income, net assets and comprehensive income as noncontrolling interest. Noncontrolling interest is included as a component of equity on the Consolidated Balance Sheets.

On May 31, 2022, Brookfield acquired 19.9% of the issued and outstanding membership interests of FET. On February 2, 2023, FE, along with FET, entered into the FET P&SA II with Brookfield and the Brookfield Guarantors, pursuant to which FE agreed to sell to Brookfield at the closing, and Brookfield agreed to purchase from FE, an incremental 30% equity interest in FET for a purchase price of $3.5 billion. The FET Equity Interest Sale closed on March 25, 2024 and FET continues to be consolidated in FirstEnergy’s financial statements. The difference between the purchase price, net of transaction costs and taxes of approximately $32 million and $803 million, respectively, and the carrying value of the NCI of $731 million, was recorded as an increase to OPIC by $1.9 billion during 2024. As of December 31, 2025, FE’s equity ownership in FET is 50.1% and Brookfield’s is 49.9%.
The purchase price of the FET Equity Interest Sale was paid in part by the issuance of two promissory notes at closing having an aggregate principal amount of $1.2 billion with: (i) one promissory note having an aggregate principal amount of $750 million, at an interest rate of 5.75% per annum, with a maturity date of September 25, 2025 and (ii) one promissory note having an aggregate principal amount of $450 million, at an interest rate of 7.75% per annum, with a maturity date of December 31, 2024. The remaining $2.3 billion of the purchase price was paid in cash at closing. On July 17, 2024, Brookfield paid FE approximately $1.2 billion in full satisfaction of the promissory notes. Interest income associated with the promissory notes was $24 million for the year ended December 31, 2024 and is reported within “Miscellaneous income, net” on FirstEnergy’s Consolidated Statements of Income.

Pursuant to the terms of the FET P&SA II, in connection with the closing, Brookfield, FET and FE entered into the A&R FET LLC Agreement, which amended and restated in its entirety the Third Amended and Restated Limited Liability Company Agreement of FET. The A&R FET LLC Agreement, among other things, provides for the governance, exit, capital and distribution, and other arrangements for FET from and following the closing. Under the A&R FET LLC Agreement, as of the closing, the FET Board of Directors consists of five directors, two of whom are appointed by Brookfield and three of whom are appointed by FE.
PROPERTY, PLANT AND EQUIPMENT

PP&E reflects original cost (net of any impairments recognized), including payroll and related costs such as taxes, employee benefits, administrative and general costs, and financing costs incurred to place the assets in service. The costs of normal maintenance, repairs and minor replacements are expensed as incurred. The Registrants' recognize liabilities for planned major maintenance projects as they are incurred.

FirstEnergy

PP&E balances by segment as of December 31, 2025 and 2024, were as follows:
December 31, 2025
Segment
In Service(1)
Accumulated. Depreciation(2)
Net PlantCWIPTotalUseful Service Life
(In millions)
(years)
Distribution $21,944 $(7,511)$14,433 $682 $15,115 
5 - 80
Integrated 18,380 (4,154)14,226 1,314 15,540 
5 - 80
Stand-Alone Transmission 14,759 (2,878)11,881 1,333 13,214 
5 - 85
Corporate/Other1,130 (646)484 60 544 
3 - 63
Total PP&E$56,213 $(15,189)$41,024 $3,389 $44,413 
December 31, 2024
Segment
In Service(1)
Accumulated. Depreciation(2)
Net PlantCWIPTotal
Useful Service Life
(In millions)(years)
Distribution$21,245 $(7,338)$13,907 $618 $14,525 
5 - 80
Integrated17,080 (3,943)13,137 1,076 14,213 
5 - 100
Stand-Alone Transmission13,509 (2,660)10,849 986 11,835 
5 - 85
Corporate/Other1,062 (607)455 74 529 
3 - 63
Total PP&E$52,896 $(14,548)$38,348 $2,754 $41,102 
(1) Includes finance leases of $48 million and $46 million as of December 31, 2025 and 2024, respectively.
(2) Includes finance lease accumulated amortization of $17 million and $14 million as of December 31, 2025 and 2024, respectively.

Integrated has approximately $2.3 billion of total regulated generation PP&E as of December 31, 2025.

FirstEnergy provides for depreciation on a straight-line basis at various rates over the estimated lives of property included in plant in service. The respective annual composite depreciation rates for FirstEnergy were approximately 2.8%, 2.9% and 2.8% in 2025, 2024 and 2023, respectively.

For the years ended December 31, 2025, 2024 and 2023, capitalized financing costs on FirstEnergy's Consolidated Statements of Income include $108 million, $60 million and $44 million, respectively, of allowance for equity funds used during construction and $77 million, $73 million and $53 million, respectively, of capitalized interest.

Jointly Owned Electric Generation Facility

AGC owns an undivided 16.25% interest (487 MWs) in the 3,003 MW Bath County pumped-storage, hydroelectric station in
Virginia, operated by the 60% owner, VEPCO, a non-affiliated utility. Total PP&E includes $142 million representing AGC's share in this facility as of December 31, 2025. AGC is obligated to pay its share of the costs of this jointly owned facility in the same proportion as its ownership interests using its own financing. AGC's share of direct expenses of the joint electric generation facility is included in operating expenses on FirstEnergy's Consolidated Statements of Income. AGC provides the generation capacity from this facility to its owner, MP, which is recovered through the ENEC.
JCP&L

PP&E by segment as of December 31, 2025 and 2024, were as follows:
December 31, 2025
Segment
In Service(1)
Accumulated. Depreciation(2)
Net PlantCWIPTotal Useful Service Life
(In millions)
(years)
Distribution$6,679 $(1,925)$4,754 $270 $5,024 
5 - 75
Transmission2,588 (514)2,074 610 2,684 
5 - 80
Total PP&E$9,267 $(2,439)$6,828 $880 $7,708 
December 31, 2024
Segment
In Service(1)
Accumulated. Depreciation(2)
Net PlantCWIPTotal Useful Service Life
(In millions)
(years)
Distribution$6,438 $(1,938)$4,500 $187 $4,687 
10 - 75
Transmission2,293 (501)1,792 433 2,225 
55 - 80
Total PP&E (3)
$8,731 $(2,439)$6,292 $620 $6,912 
(1) Includes finance leases of $12 million and $11 million as of December 31, 2025 and 2024, respectively.
(2) Includes finance lease accumulated amortization of $6 million and $5 million as of December 31, 2025 and 2024, respectively.
(3) Previously issued 2024 JCP&L amounts have been revised due to the correction of immaterial errors as discussed in Note 1., "Organization and Basis of Presentation," of the Combined Notes to Financial Statements of the Registrants.

JCP&L provides for depreciation on a straight-line basis at various rates over the estimated lives of property included in plant in service. Depreciation expense was approximately 2.9%, 2.9% and 2.8% of average depreciable property in 2025, 2024 and 2023, respectively.
For the years ended December 31, 2025, 2024 and 2023, capitalized financing costs on JCP&L's Statements of Income and Comprehensive Income include $28 million, $5 million and $5 million, respectively, of allowance for equity funds used during construction and $15 million, $23 million and $14 million, respectively, of capitalized interest.
NEW ACCOUNTING PRONOUNCEMENTS

Recently Adopted Pronouncements - ASU 2023-09, "Income taxes (Topic 280): Improvements to Income Tax Disclosures" (Issued in December 2023): ASU 2023-09 enhances disclosures primarily related to existing rate reconciliation and income taxes paid information to help investors better assess how a company’s operations and related tax risks and tax planning and operational opportunities affect the tax rate and prospects for future cash flows. Disclosure requirements include a tabular reconciliation using both percentages and amounts, separated out into specific categories with certain reconciling items at or above 5% of the statutory tax as well as by nature and/or jurisdiction. In addition, entities will be required to disclose income taxes paid (net of refunds received), broken out between federal, state/local and foreign, and amounts paid to an individual jurisdiction when 5% or more of the total income taxes are paid to such jurisdiction. ASU 2023-09 was effective for the Registrants beginning with this Annual Report on Form 10-K for the year ended December 31, 2025, see Note 6., “Taxes,” of the Combined Notes to Financial Statements of the Registrants for the applicable disclosures, which are provided for all periods presented.

Recently Issued Pronouncements - The following new authoritative accounting guidance issued by the FASB has not yet been adopted. Unless otherwise indicated, the Registrants’ management is currently assessing the impact such guidance may have on their financial statements and disclosures, as well as the potential to early adopt where applicable. Management has assessed other FASB issuances of new standards not described below based upon the current expectation that such new standards will not significantly impact the Registrants’ financial statements.

ASU 2024-03, "Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures (Subtopic 220-40)" (Issued in November 2024 and subsequently updated within ASU 2025-01): ASU 2024-03 requires disaggregated disclosure of income statement expenses for public business entities. The ASU does not change the expense captions an entity presents on the face of the income statement; rather, it requires disaggregation of certain expense captions into specified
categories in disclosures within the footnotes to the financial statements. ASU 2024-03 is effective for the Registrants beginning with the Annual Report on Form 10-K for the year ended December 31, 2027, with early adoption permitted. The guidance is permitted to be applied prospectively, and comparative disclosures are not required for reporting periods beginning before the effective date. Entities can elect to apply the new standard retrospectively to any or all prior periods presented in the financial statements.

ASU 2025-06, “Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Targeted Improvements to the Accounting for Internal-Use Software" (Issued in September 2025): ASU 2025-06 amends the existing standard that refers to various stages of a software development project to align better with current software development methods, such as agile programming. Under the new standard, entities will start capitalizing eligible costs when (1) management has authorized and committed to funding the software project, and (2) it is probable that the project will be completed and the software will be used to perform the function intended. In evaluating whether it is probable the project will be completed; an entity is required to consider whether there is significant uncertainty associated with the development activities of the software. ASU 2025-06 is effective for the Registrants beginning with the financials for the first quarter of 2028. The guidance is permitted to be applied using a prospective, retrospective or modified transition approach. Early adoption is permitted.

ASU 2025-10, Government Grants (Topic 832): Accounting for Government Grants Received by Business Entities (Issued in December 2025): ASU 2025-10 establishes authoritative guidance for the recognition, measurement, presentation, and disclosure of government grants received by business entities. ASU 2025-10 requires that a government grant be recognized when it is probable that the entity will comply with the conditions of the grant and that the grant will be received and permits two approaches for asset related grants: (1) the cost reduction method (reduce the carrying amount of the asset) and (2) deferred income method (recognize income over the useful life of the asset). Income-related grants are recognized systematically in income as the related costs are incurred. ASU 2025-10 is effective for the Registrants beginning with financials for the first quarter of 2029, with early adoption permitted. The guidance is permitted to be applied using a modified prospective, modified retrospective or full retrospective approach.
v3.25.4
REVENUE
 12 Months Ended
Dec. 31, 2025
Revenue from Contract with Customer [Abstract]  
REVENUE REVENUE
The disclosures in this note apply to both Registrants, unless indicated otherwise.

The Registrants account for revenues from contracts with customers under ASC 606, “Revenue from Contracts with Customers.” Revenue from leases, financial instruments, other contractual rights or obligations and other revenues that are not from contracts with customers are outside the scope of the standard and accounted for under other existing GAAP.

The Electric Companies distribute electricity through FirstEnergy’s utility operating companies and also control 3,610 MWs of regulated electric generation capacity located primarily in West Virginia and Virginia. Each of the Electric Companies earns revenue from state-regulated rate tariffs under which it provides distribution services to residential, commercial and industrial customers in its service territory. The Electric Companies are obligated under the regulated construct to deliver power to customers reliably, as it is needed, which creates an implied monthly contract with the end-use customer. See Note 13., “Regulatory Matters,” of the Combined Notes to Financial Statements of the Registrants for additional information on rate recovery mechanisms. Distribution and electric revenues are recognized over time as electricity is distributed and delivered to the customer and the customers consume the electricity immediately as delivery occurs.

Retail generation sales relate to Provider of Last Resort, SOS, Standard Service Offer and default service requirements in Ohio, Pennsylvania, New Jersey and Maryland, as well as generation sales in West Virginia that are regulated by the WVPSC. Certain of the Electric Companies have default service obligations to provide power to non-shopping customers who have elected to continue to receive service under regulated retail tariffs. The volume of these sales varies depending on the level of shopping that occurs. Supply plans vary by state and by service territory. Default service for the Ohio Companies, FE PA, JCP&L and PE’s Maryland jurisdiction are provided through a competitive procurement process approved by each state’s respective commission. Retail generation revenues are recognized over time as electricity is delivered and consumed immediately by the customer.

Wholesale sales primarily consist of generation and capacity sales into the PJM market from FirstEnergy’s regulated electric generation capacity and NUGs. Certain of the Electric Companies may also purchase power in the PJM markets to supply power to their customers. Generally, these power sales from generation and purchases to serve load are netted hourly and reported as either revenues or purchased power on the Consolidated Statements of Income based on whether the entity was a net seller or buyer each hour. Capacity revenues are recognized ratably over the PJM planning year at prices cleared in the annual PJM Reliability Pricing Model Base Residual Auction and Incremental Auctions. Capacity purchases and sales through PJM capacity auctions are reported within revenues on the Consolidated Statements of Income. Certain capacity income (bonuses) and charges (penalties) related to the availability of units that have cleared in the auctions are unknown and not recorded in revenue until, and unless, they occur.

The Electric Companies’ distribution customers are metered on a cycle basis. An estimate of unbilled revenues is calculated to recognize electric service provided from the last meter reading through the end of the month. This estimate includes many factors, among which are historical customer usage, load profiles, estimated weather impacts, customer shopping activity and prices in effect for each class of customer. In each accounting period, the Electric Companies accrue the estimated unbilled
amount as revenue and reverse the related prior period estimate. Customer payments vary by state but are generally due within 30 days.

ASC 606 excludes industry-specific accounting guidance for recognizing revenue from Alternative Revenue Programs as these programs represent contracts between the utility and its regulators, as opposed to customers. Therefore, revenues from these programs are not within the scope of ASC 606 and regulated utilities are permitted to continue to recognize such revenues in accordance with existing practice but are presented separately from revenue arising from contracts with customers.

Transmission infrastructure owned and operated by the Transmission Companies and certain of FirstEnergy's Electric Companies (JCP&L, MP and PE) transmits electricity from generation sources to distribution facilities. Transmission revenues are derived primarily from forward-looking formula rates. See Note 13., “Regulatory Matters,” of the Combined Notes to Financial Statements of the Registrants for additional information. Forward-looking formula rates recover costs that the regulatory agencies determine are permitted to be recovered and provide a return on transmission capital investment. Under forward-looking formula rates, the revenue requirement is updated annually based on a projected rate base and projected costs, which is subject to an annual true-up based on rate base and actual costs. Revenues and cash receipts for the stand-ready obligation of providing transmission service are recognized ratably over time.

The Registrants have elected to exclude sales taxes and other similar taxes collected on behalf of third parties from revenue as prescribed in the standard. As a result, tax collections and remittances are excluded from recognition in the income statement and instead recorded through the balance sheet. Excise and gross receipts taxes that are assessed on the Registrants are not subject to the election and are included in revenue. The Registrants have elected the optional invoice practical expedient for most of its revenues and utilizes the optional short-term contract exemption for transmission revenues due to the annual establishment of revenue requirements, which eliminates the need to provide certain revenue disclosures regarding unsatisfied performance obligations.
The following represents a disaggregation of FirstEnergy's revenue from contracts with customers for the years ended December 31, 2025, 2024 and 2023:

FirstEnergyFor the Years Ended December 31,
(In millions)202520242023
 Distribution
Retail generation and distribution services
Residential $4,948 $4,514 $4,344 
Commercial 1,699 1,522 1,528 
Industrial 651 588 726 
Other 73 73 72 
Wholesale 16 6 20 
Other revenue from contracts with customers (1)
78 80 89 
Total revenues from contracts with customers7,465 6,783 6,779 
Other revenue unrelated to contracts with customers (2)
82 80 75 
Total Distribution$7,547 $6,863 $6,854 
Integrated
Retail generation and distribution services
Residential$2,877 $2,528 $2,137 
Commercial1,294 1,142 1,023 
Industrial615 577 545 
Other32 32 30 
Wholesale377 146 208 
Transmission 425 380 318 
Other revenue from contracts with customers(1)
6 19 24 
Total revenues from contracts with customers5,626 4,824 4,285 
ARP (3)
— 10 — 
Other revenue unrelated to contracts with customers(2)
57 42 35 
Total Integrated $5,683 $4,876 $4,320 
Stand-Alone Transmission
ATSI $1,058 $980 $967 
TrAIL 260 269 279 
MAIT 483 436 394 
KATCo85 85 89 
Other — (2)2 
Total revenues from contracts with customers1,886 1,768 1,731 
Other revenue unrelated to contracts with customers19 19 17 
Total Stand-Alone Transmission $1,905 $1,787 $1,748 
Corporate/Other, Eliminations and Reconciling Adjustments (4)
Wholesale$18 $9 $11 
Eliminations and reconciling adjustments (63)(63)(63)
Total Corporate/Other, Eliminations and Reconciling Adjustments$(45)$(54)$(52)
FirstEnergy Total Revenues $15,090 $13,472 $12,870 
(1) Primarily includes amounts collected from customers to administer and repay securitization bonds and pole attachment revenue.
(2) Primarily includes late payment charges and revenue from FTRs.
(3) Related to lost distribution revenues associated with energy efficiency in New Jersey.
(4) Includes eliminations and reconciling adjustments of inter-segment revenues.
The following table represents a disaggregation of JCP&L's revenue from contracts with customers for the years ended December 31, 2025, 2024 and 2023:
For the Years Ended December 31,
(In millions)202520242023
 Distribution
Retail generation and distribution services
Residential $1,705 $1,470 $1,240 
Commercial 728 627 579 
Industrial 76 70 68 
Street lighting
21 20 21 
Wholesale 6 6 5
Other revenue from contracts with customers (1)
14 18 18
Total revenues from contracts with customers2,550 2,211 1,931 
ARP(2)
— 10 — 
Other revenue unrelated to contracts with customers4 4 3
Total Distribution Segment Revenue $2,554 $2,225 $1,934 
Transmission
Total Transmission Segment Revenue $259 $242 $204 
 Reconciling Adjustments(3)
Retail generation and distribution services$(175)$(152)$(111)
JCP&L Total Revenues $2,638 $2,315 $2,027 
(1) Primarily includes pole attachment revenue.
(2) Related to lost distribution revenues associated with energy efficiency in New Jersey.
(3) Includes eliminations and reconciling adjustments of inter-segment revenues.
RECEIVABLES

Receivables from contracts with customers include retail electric sales and distribution deliveries to residential, commercial and industrial customers of the Electric Companies. Billed and unbilled customer receivables as of December 31, 2025 and 2024, are included below.
Customer ReceivablesFirstEnergy JCP&L
As of December 31, 2025202420252024
 (In millions)
Billed(1)
$939 $867 $178 $166 
Unbilled844 718 152 118 
1,783 1,585 330 284 
Less: Uncollectible Reserve 57 55 6 6 
Total Customer Receivables $1,726 $1,530 $324 $278 
(1) Includes approximately $323 million and $284 million for FirstEnergy as of December 31, 2025 and 2024, respectively, that are past due by greater than 30 days.
The allowance for uncollectible customer receivables is based on historical loss information comprised of a rolling 36-month average net write-off percentage of revenues, in conjunction with a qualitative assessment of elements that impact the collectability of receivables to determine if allowances for uncollectible customer receivables should be further adjusted in accordance with the accounting guidance for credit losses.

The Registrants review allowance for uncollectible customer receivables utilizing a quantitative and qualitative assessment. Management contemplates available current information such as changes in economic factors, regulatory matters, industry trends, customer credit factors, amount of receivable balances that are past-due, payment options and programs available to customers, and the methods that the Electric Companies are able to utilize to ensure payment. The Registrants’ uncollectible risk on PJM receivables, resulting from transmission and wholesale sales, is minimal due to the nature of PJM’s settlement process
and as a result there is no current allowance for doubtful accounts.
Activity in the allowance for uncollectible accounts on customer receivables for the years ended December 31, 2025, 2024 and 2023 are as follows:
Customer Receivables FirstEnergy JCP&L
(In millions)
Balance, January 1, 2023$137 $21 
Provision for expected credit losses(1)(2)
8 (1)
Charged to other accounts(3)
34 3 
Write-offs(115)(14)
Balance, December 31, 2023649
Provision for expected credit losses(1)(2)
73 5 
Charged to other accounts(3)
39 4 
Write-offs(121)(12)
Balance, December 31, 202455 6 
Provision for expected credit losses(1)(2)
94 8 
Charged to other accounts(3)
37 3 
Write-offs(129)(11)
Balance, December 31, 2025$57 $6 
(1) Customer receivable amounts charged (credited) to income for FirstEnergy for the years ended December 31, 2025, 2024 and 2023, include approximately $31 million, $17 million, and $(15) million, respectively, deferred for future recovery (refund).
(2) Customer receivable amounts charged (credited) to income for JCP&L include approximately $8 million, $5 million and $(1) million deferred for future recovery (refund) for the years ended December 31, 2025, 2024 and 2023 respectively.
(3) Represents recoveries and reinstatements of accounts written off for uncollectible accounts.
Activity in the allowance for uncollectible accounts on other receivables for the years ended December 31, 2025, 2024 and 2023 are as follows:
Other Receivables FirstEnergy JCP&L
(In millions)
Balance, January 1, 2024$11 $6 
Provision for expected credit losses7 — 
Charged to other accounts(1)
(1)— 
Write-offs(2)— 
Balance, December 31, 202315 6 
Provision for expected credit losses1 — 
Charged to other accounts(1)
(5)(6)
Write-offs(5)— 
Balance, December 31, 20246 — 
Provision for expected credit losses9 1 
Charged to other accounts(1)
— — 
Write-offs(4)(1)
Balance, December 31, 2025$11 $— 
(1) Represents recoveries and reinstatements of accounts written off for uncollectible accounts.
v3.25.4
EARNINGS PER SHARE OF COMMON STOCK
 12 Months Ended
Dec. 31, 2025
Earnings Per Share [Abstract]  
EARNINGS PER SHARE OF COMMON STOCK EARNINGS PER SHARE OF COMMON STOCK
The disclosures in this note apply to FirstEnergy only.

EPS is calculated by dividing earnings attributable to FE by the weighted average number of common shares outstanding.

Basic EPS is computed using the weighted average number of common shares outstanding during the relevant period as the denominator. The denominator for diluted EPS of common stock reflects the weighted average of common shares outstanding plus the potential additional common shares that could result if dilutive securities and other agreements to issue common stock were exercised.
Diluted EPS reflects the dilutive effect of potential common shares from share-based awards and convertible securities. The dilutive effect of outstanding share-based awards was computed using the treasury stock method, which assumes any proceeds that could be obtained upon the exercise of the award would be used to purchase common stock at the average market price for the period. The dilutive effect of the 2026 Convertible Notes, 2029 Convertible Notes and the 2031 Convertible Notes, as further discussed in Note 11., "Capitalization" under Long-term debt and other long-term obligations, is computed using the if-converted method.

The following table reconciles basic and diluted EPS attributable to FE:

For the Years Ended December 31,
Reconciliation of Basic and Diluted EPS of Common Stock202520242023
(In millions, except per share amounts)
Earnings Attributable to FE - continuing operations$1,020 $978 $1,123 
Earnings Attributable to FE - discontinued operations, net of tax— — (21)
Earnings Attributable to FE$1,020 $978 $1,102 
Share Count information:
Weighted average number of basic shares outstanding577 575 573 
Assumed exercise of dilutive share-based awards1 2 1 
Weighted average number of diluted shares outstanding578 577 574 
EPS Attributable to FE:
Income from continuing operations, basic$1.77 $1.70 $1.96 
Discontinued operations, basic — — (0.04)
Basic EPS$1.77 $1.70 $1.92 
Income from continuing operations, diluted$1.76 $1.70 $1.96 
Discontinued operations, diluted— — (0.04)
Diluted EPS$1.76 $1.70 $1.92 

For the years ended December 31, 2025, 2024 and 2023, there was no material amount of shares excluded from the calculation of diluted shares outstanding, as their inclusion would be antidilutive.

The dilutive effect of the convertible notes is limited to the conversion obligation in excess of the aggregate principal amount of the convertible notes being converted. For the years ended December 31, 2025, 2024 and 2023, there was no dilutive effect resulting from the outstanding convertible notes as the average market price of FE shares of common stock was below the initial conversion price of $47.78 per share for the 2029 and 2031 Convertible Notes, and $46.42 per share for the 2026 Convertible Notes. See Note 10., "Fair Value Measurements," of the Combined Notes to Financial Statements of the Registrants for additional information on the convertible notes.
v3.25.4
PENSION AND OTHER POSTEMPLOYMENT BENEFITS
 12 Months Ended
Dec. 31, 2025
Retirement Benefits [Abstract]  
PENSION AND OTHER POSTEMPLOYMENT BENEFITS PENSION AND OTHER POSTEMPLOYMENT BENEFITS
The disclosures in this note apply to both Registrants, unless indicated otherwise.
FirstEnergy provides qualified benefit plans, through the FirstEnergy Master Pension Plan and the FirstEnergy Welfare Plan that cover substantially all employees and non-qualified defined benefit plans that cover certain employees, including employees of JCP&L. FirstEnergy’s pension and OPEB plans are neither multiemployer nor multiple-employer plans.
The pension plans provide defined benefits based on years of service and compensation levels. Under the cash-balance portion of the pension plan (for employees hired on or after January 1, 2014), FirstEnergy credits amounts to eligible employee notional cash-balance accounts based on a pay credit and an interest credit.
In addition, FirstEnergy provides a minimum amount of noncontributory life insurance to retired employees in addition to optional contributory insurance to a closed group of retired employees. Health care benefits, which include certain employee contributions, deductibles and co-payments, are also available upon retirement to certain employees, their dependents and, under certain circumstances, their survivors. The expected cost of providing pension and OPEB to employees and their beneficiaries and covered dependents is recognized from the time employees are hired until they become eligible to receive those benefits. FirstEnergy also has obligations to former or inactive employees after employment, but before retirement, for disability-related benefits.

FirstEnergy’s pension funding policy is based on actuarial computations using the projected unit credit method. FirstEnergy does not currently expect to have a required contribution to the pension plan until 2027, which based on various assumptions, including an expected rate of return on assets of 8.0% for 2026, is expected to be approximately $250 million. However, FirstEnergy may elect to contribute to the pension plan voluntarily. JCP&L is not expected to make a contribution.
Pension and OPEB costs are affected by employee demographics (including age, compensation levels and employment periods), the level of contributions made to the plans and earnings on plan assets. Pension and OPEB costs may also be affected by changes in key assumptions, including anticipated rates of return on plan assets, the discount rates and health care trend rates used in determining the projected benefit obligations for pension and OPEB costs. FirstEnergy uses a December 31 measurement date for its pension and OPEB plans or whenever a plan is determined to qualify for a remeasurement. The fair value of the plan assets represents the actual market value as of the measurement date.
In January 2025, FirstEnergy executed a lift-out transaction with MetLife, that transferred approximately $640 million of plan assets and $652 million of plan obligations, associated with approximately 2,000 former competitive generation employees, who will assume future and full responsibility to fund and administer their benefit payments. Similar to the lift-out in 2023, there was no change to the pension benefits for any participant as a result of the transfer and the transaction was funded by pension plan assets. FirstEnergy believes that this lift-out transaction, in addition to the lift-out in 2023, further de-risked potential volatility with the pension plan assets and liabilities. FirstEnergy will continue to evaluate other lift-outs in the future based on market and other conditions. Due to the timing of the lift-out transaction and its proximity to the 2024 annual remeasurement, FirstEnergy elected a practical expedient and did not remeasure pension plan assets and obligations when the lift-out occurred in January 2025.

FirstEnergy’s cash flows from operating activities for the years ended December 31, 2025 and 2024, include approximately $49 million (none at JCP&L) and $59 million ($7 million at JCP&L), respectively, of employee benefit plan funding and related payments. These payments are primarily related to short-term benefit payment liabilities owed to retirees under plan obligations in the respective periods.
Actuarial Assumptions PensionOPEB
20252024
2023 (2)
20252024
2023 (2)
Assumptions Related to Benefit Obligations:
Discount rate5.59 %5.72 %5.05 %5.37 %5.60 %4.97 %
Rate of compensation increase4.30 %4.30 %4.30 %N/AN/AN/A
Cash balance weighted average interest crediting rate4.64 %4.37 %4.94 %N/AN/AN/A
Assumptions Related to Benefit Costs:(1)
Effective rate for interest on benefit obligations 5.41 %4.92 %
5.10% / 4.80%
5.28 %4.88 %5.06 %
Effective rate for service costs 5.89 %5.17 %
5.34% / 5.11%
5.98 %5.23 %5.41 %
Effective rate for interest on service costs 5.66 %5.05 %
5.22% /4.94%
5.88 %5.16 %5.33 %
Expected return on plan assets8.50 %8.00 %8.00 %7.00 %7.00 %7.00 %
Rate of compensation increase4.30 %4.30 %4.30 %N/AN/AN/A
Assumed Health Care Cost Trend Rates:
Health care cost trend rate assumed (pre/post-Medicare)N/AN/AN/A
6.50% - 5.80%
7.00%-
6.00%
7.00%-
6.50%
Rate to which the cost trend rate is assumed to decline (ultimate trend rate)N/AN/AN/A4.50 %4.50 %4.50 %
Year that the rate reaches the ultimate trend rateN/AN/AN/A203620352033
(1) Excludes impact of pension and OPEB mark-to-market adjustments.
(2) As a result of the interim plan remeasurement during 2023, different rates were in effect from January 1, 2023, through April 30, 2023 compared to May 1, 2023 through December 31, 2023.

Discount Rate - The discount rate is determined using currently available rates of return on high-quality fixed income investments expected to be available during the period to maturity of the pension and OPEB obligations. FirstEnergy utilizes a spot rate approach in the estimation of the components of benefit cost by applying specific spot rates along the full yield curve to the relevant projected cash flows. FirstEnergy utilizes an analytical tool developed by its actuary to determine the discount rates.

Expected Return on Plan Assets - The expected return on pension and OPEB assets is based on input from investment consultants, including the trusts’ asset allocation targets, the historical performance of risk-based and fixed income securities and other factors. The gains or losses generated as a result of the difference between expected and actual returns on plan assets is recognized as a pension and OPEB mark-to-market adjustment in the fourth quarter of each fiscal year and whenever a plan is determined to qualify for remeasurement.

FirstEnergy Pension and OPEB Returns202520242023
 Actual gains or (losses) on plan assets - $ millions$880 $3 $751 
Actual gains or (losses) on plan assets - %15.4 %0.7 %11.2 %
Expected return on plan assets - $ millions$499 $565 $601 
Expected return on plan assets - %
8.50% for pension

7.00% for OPEB
8.00% for pension

7.00% for OPEB
8.00% for pension

7.00% for OPEB

Mortality Rates - During 2025, the Society of Actuaries elected not to release a new mortality improvement scale. Management, in discussions with its actuary, determined that the Pri-2012 mortality table with projection scale MP-2021, actuarially adjusted to reflect increased mortality due to the ongoing impact of COVID-19, was most appropriate and such was utilized to determine the obligation as of December 31, 2025, for the FirstEnergy pension and OPEB plans. This adjustment acknowledges COVID-19 cannot be eradicated and assumes reductions in other causes will not offset future COVID-19 deaths enough to produce a normal level of improvements.

Net Periodic Benefit Costs (Credits) - In addition to service costs, interest on obligations, expected return on plan assets, and prior service costs, FirstEnergy recognizes in net periodic benefit costs a pension and OPEB mark-to-market adjustment for the change in the fair value of plan assets and net actuarial gains and losses annually in the fourth quarter of each fiscal year and whenever a plan is determined to qualify for a remeasurement. Service costs, net of amounts capitalized, are reported within "Other operating expenses" on the Registrants' Statements of Income. Non-service costs, other than the pension and OPEB mark-to-market adjustment, which is separately shown, are reported within "Miscellaneous income, net", within "Other Income (Expense)" on the Registrants' Statements of Income.
FirstEnergy Components of Net Periodic Benefit Costs (Credits) for the Years Ended December 31,PensionOPEB
202520242023202520242023
 (In millions)
Service cost(1)
$131 $140 $139 $2 $3 $2 
Interest cost 374 398 428 20 20 21 
Expected return on plan assets (461)(530)(570)(38)(35)(31)
Amortization of prior service costs (credits)1 2 2 (1)(1)(8)
Special termination benefits(2)
— — 21 — — 8 
Pension & OPEB mark-to-market adjustments(231)66 108 (22)(44)(30)
Net periodic benefit costs (credits)$(186)$76 $128 $(39)$(57)$(38)
(1) Includes amounts capitalized.
(2) Related to benefits provided in connection with the PEER.

For the years ended December 31, 2025, 2024 and 2023, approximately $(29) million, $(8) million and $36 million, respectively, of the annual pension and OPEB mark-to-market adjustment charges (credits) were allocated to companies under forward-looking formula rates, and expected to be refunded or recovered through formula transmission rates.

The Registrants recognize a pension and OPEB mark-to-market adjustment for the change in fair value of plan assets and net actuarial gains and losses annually in the fourth quarter of each fiscal year and whenever a plan is determined to qualify for remeasurement.

In the fourth quarter of 2025, FirstEnergy recognized a $253 million ($55 million at JCP&L) pension and OPEB mark-to-market adjustment gain, primarily reflecting higher than expected return on assets partially offset by a decrease in the discount rate used to measure pension benefit obligations.

FirstEnergy PensionOPEB
Obligations/Funded Status - Qualified and Non-Qualified Plans2025202420252024
(In millions)
Change in benefit obligation:
Benefit obligation as of January 1$7,824 $8,363$407 $441
Service cost131 1402 3
Interest cost374 39820 20
Plan participants’ contributions— —3 4
Medicare retiree drug subsidy— —— 1
Lift-out transaction (652)—— —
Actuarial loss (gain)129 (526)11 (14)
Benefits paid(526)(551)(45)(48)
Benefit obligation as of December 31$7,280 $7,824$398 $407
Change in fair value of plan assets:
Fair value of plan assets as of January 1$6,296 $6,879$567 $516
Actual return on plan assets809 (62)71 65
Lift-out transaction (640)—— —
Company contributions28 3021 30
Plan participants’ contributions— —3 4
Benefits paid(526)(551)(45)(48)
Fair value of plan assets as of December 31$5,967 $6,296$617 $567
Funded Status:
Qualified plan$(952)$(1,165)$— $—
Non-qualified plans(361)(363)— —
Funded Status - Net asset (liability) as of December 31 (1)
$(1,313)$(1,528)$219$160
Accumulated benefit obligation$7,047 $7,572 $— $— 
Amounts Recognized in AOCI:
Prior service cost (credit)$1 $2 $1 $1 
(1) The pension net liability is included in “Retirement benefits,” on the Consolidated Balance Sheets. The OPEB net asset is included in “Other” noncurrent assets on the Consolidated Balance Sheets.
The following tables set forth FirstEnergy's pension financial assets that are accounted for at fair value by level within the fair value hierarchy. See Note 10., "Fair Value Measurements," of the Combined Notes to Financial Statements of the Registrants for a description of each level of the fair value hierarchy. There were no significant transfers between levels during 2025 and 2024.
December 31, 2025Asset Allocation
FirstEnergyLevel 1Level 2Level 3Total
(In millions)
Cash and short-term securities$— $402 $— $402 7 %
Public equity1,976 6 — 1,982 33 %
Fixed income— 1,507 — 1,507 25 %
Derivatives(21)18 — (3)— %
Total(1)
$1,955 $1,933 $— $3,888 65 %
Private - equity and debt funds(2)
1,278 22 %
Insurance-linked securities(2)
7 — %
Hedge funds(2)
270 5 %
Real estate funds(2)
498 8 %
Total Investments$5,941 100 %
(1) Excludes $26 million as of December 31, 2025, of receivables, payables, taxes, cash collateral for derivatives and accrued income associated with financial instruments reflected within the fair value table.
(2) NAV used as a practical expedient to approximate fair value.

December 31, 2024Asset Allocation
FirstEnergyLevel 1Level 2Level 3Total
(In millions)
Cash and short-term securities$— $1,173 $— $1,173 19 %
Public equity1,585 5 — 1,590 25 %
Fixed income— 1,425 — 1,425 23 %
Derivatives(95)37 — (58)(1)%
Total(1)
$1,490 $2,640 $— $4,130 66 %
Private - equity and debt funds(2)
1,273 20 %
Insurance-linked securities(2)
39 1 %
Hedge funds(2)
253 4 %
Real estate funds(2)
554 9 %
Total Investments$6,249 100 %
(1) Excludes $47 million as of December 31, 2024, of receivables, payables, taxes and accrued income associated with financial instruments reflected within the fair value table.
(2) NAV used as a practical expedient to approximate fair value.

Private – equity and debt funds: Private equity and private debt funds primarily include limited partnerships that invest in equity or directly originated senior loans of high-quality middle market operating companies. Distributions are received periodically through the liquidation of underlying assets in each fund. For most private equity and debt funds, immediate access to capital at the limited partner’s discretion is not available and such funds prevent full redemption and return of capital until fund liquidation. The purpose of each fund is to maximize total return of capital with an emphasis on minimizing default risk. Each fund’s NAV is made available to fund participants quarterly.

Insurance-Linked Securities funds: The insurance linked securities funds invest in securities which indirectly participate in portfolios of reinsurance and retrocession contracts which primarily cover catastrophe property risks. Redemptions can be achieved with 90-day notices with gating factors that may apply. The purpose of these investments is to generate attractive risk-adjusted returns that are demonstrably uncorrelated with traditional asset classes. Each fund’s NAV is made available to fund participants monthly.

Hedge funds: The hedge funds invest in a combination of long and short equity, multi-strategy, global macro and structured credit strategies. Redemptions can be achieved with 90-day notices with gating factors that may apply. The purpose of these investments is to deliver diversified risk-adjusted returns to traditional asset classes. Each fund’s NAV is made available to fund participants monthly.

Real estate funds: The real estate funds primarily invest in U.S commercial real estate markets that include office, residential, retail, industrial, life science/lab space, storage and student housing. The investment values of the real estate properties are determined on a quarterly basis by independent market appraisers hired by the board of directors of each fund. Distributions from each fund will be received as the underlying investments of the fund are liquidated. Each investor’s ability to withdraw capital from certain funds may be limited depending on whether a queue has been established. The purpose of each fund is to invest in real estate and real estate related assets that generate a total return from current income and capital appreciation which exceeds the applicable fund’s index. Each fund’s NAV is made available to fund participants quarterly.

As of December 31, 2025, and 2024, the FirstEnergy OPEB trust investments measured at fair value were as follows:
December 31, 2025Asset Allocation
FirstEnergyLevel 1Level 2Level 3Total
(In millions)
Cash and short-term securities$— $128 $— $128 20 %
Public equity361 — — 361 57 %
Fixed income— 141 — 141 23 %
Total(1)
$361 $269 $— $630 100 %
(1) Excludes $(13) million as of December 31, 2025, of receivables, payables, taxes and accrued income associated with financial instruments reflected within the fair value table.

December 31, 2024Asset Allocation
FirstEnergyLevel 1Level 2Level 3Total
(In millions)
Cash and short-term securities$— $112 $— $112 20 %
Public equity314 — — 314 55 %
Fixed income:— 146 — 146 25 %
Total(1)
$314 $258 $— $572 100 %
(1) Excludes $(5) million as of December 31, 2024, of receivables, payables, taxes and accrued income associated with financial instruments reflected within the fair value table.

FirstEnergy’s target asset allocations for its pension and OPEB trust portfolios as of December 31, 2025 were as follows:
Target Asset Allocations
Pension OPEB
Equities30 %50 %
Fixed income28.5 %50 %
Alternative investments 5 %— %
Real estate10 %— %
Private - equity and debt funds20 %— %
Cash and derivatives 6.5 %— %
100 %100 %
FirstEnergy follows a total return investment approach using a mix of equities, fixed income and other available investments while taking into account the pension plan liabilities to optimize the long-term return on plan assets for a prudent level of risk. Risk tolerance is established through careful consideration of plan liabilities, plan funded status and corporate financial condition. The investment portfolio contains a diversified blend of equity and fixed-income investments. Equity investments are diversified across U.S. and non-U.S. stocks, as well as growth, value, and small and large capitalization funds. Other assets such as real estate and private equity are used to enhance long-term returns while improving portfolio diversification. Derivatives may be used to gain market exposure in an efficient and timely manner; however, derivatives are not used to leverage the portfolio beyond the market value of the underlying investments. Investment risk is measured and monitored on a continuing basis through periodic investment portfolio reviews, annual liability measurements and periodic asset/liability studies.

Taking into account estimated employee future service, FirstEnergy expects to make the following benefit payments from plan assets and other payments, net of participant contribution.
OPEB
Pension Benefit Payments
Benefit Payments (1)
Subsidy Receipts
(In millions)
2026$517 $40 $1 
2027522 39 1 
2028526 38 — 
2029530 37 — 
2030532 35 — 
Years 2031-20352,660 155 2 
(1) Net of participant contributions.
JCP&L

JCP&L recognizes its allocated portion of the expected cost of providing pension and OPEB to employees and their beneficiaries and covered dependents from the time employees are hired until they become eligible to receive those benefits. JCP&L also recognizes its allocated portion of obligations to former or inactive employees after employment, but before retirement, for disability-related benefits. In addition to the net periodic benefit costs for its current and former employees and retirees, JCP&L is also allocated pension and OPEB net periodic benefit costs/(credits) from its affiliates, primarily FESC.
JCP&L’s net periodic benefit costs (credits) for pension and OPEB were as follows:

PensionOPEB
For the Years Ended December 31,202520242023202520242023
(In millions)
JCP&L's share of net periodic benefit credits (1)(2)
$(37)$(12)$10 $(28)$(27)$(29)
Allocated net periodic benefit costs from affiliates (1)(3)
$(1)$6 $40 $1 $— $1 
(1) Includes amounts capitalized.
(2) Includes JCP&L’s pension and OPEB mark-to-market adjustment gain (loss) of $45 million, $22 million and $2 million for the years ended December 31, 2025, 2024 and 2023, respectively.
(3) Included in these net periodic benefit costs/(credits) from its affiliates are $10 million, $2 million and $(31) million of mark-to-market adjustment gain (loss), for the years ended December 31, 2025, 2024 and 2023, respectively.

Summary of Plan Status PensionOPEB
As of December 31, (in millions)
2025202420252024
JCP&L's share of FirstEnergy funded status(2)
$(29)$(67)$243 $215 
(1) OPEB amounts include a $7 million contribution from JCP&L in 2024.
(2) Excludes $492 million and $502 million as of December 31, 2025 and 2024, respectively, of affiliated noncurrent liabilities included within "Other" noncurrent liabilities on JCP&L's Balance Sheets related to pension and OPEB mark-to-market costs allocated to JCP&L and amounts associated with a reallocation of OPEB assets among certain FirstEnergy companies in 2022.
v3.25.4
STOCK-BASED COMPENSATION PLANS
 12 Months Ended
Dec. 31, 2025
Share-Based Payment Arrangement [Abstract]  
STOCK-BASED COMPENSATION PLANS STOCK-BASED COMPENSATION PLANS
The disclosures in this note apply to both Registrants, unless indicated otherwise.

FirstEnergy grants, including to JCP&L employees, stock-based awards through the ICP 2020, primarily in the form of restricted stock, time-based RSUs and performance-based RSUs. No shares are available for future grants or issuance under ICP 2015.

The ICP 2020 and ICP 2015 include shareholder authorization to each issue 10 million shares of common stock or their equivalent. Shares not issued due to forfeitures or cancellations originally granted through the ICP 2015 may be added back to the ICP 2020. As of December 31, 2025, approximately 7.4 million shares were available for future grants under the ICP 2020 assuming maximum performance metrics are achieved for the outstanding cycles of RSUs. Shares granted under the ICP 2020 are issued from authorized but unissued common stock. Vesting periods for stock-based awards range from less than a year, primarily due to the issuance of prorated awards to newly hired executives, to four years, with the majority of awards having a vesting period of three years. FirstEnergy also issues stock through its 401(k) savings plan and DCPD.

FirstEnergy records the compensation costs for stock-based compensation awards that will be paid in stock over the vesting period based on the fair value on the grant date. FirstEnergy accounts for forfeitures as they occur.

FirstEnergy adjusts the compensation costs for stock-based compensation awards that will be paid in cash based on changes in the fair value of the award as of each reporting date. FirstEnergy records the actual tax benefit realized from tax deductions when awards are exercised or settled. Actual income tax benefits realized during the years ended December 31, 2025, 2024 and 2023, were $7 million, $17 million and $6 million, respectively. The income tax effects of awards are recognized in the income statement when the awards vest, are settled or are forfeited.

The following table reflects the pre-tax portion of stock-based compensation costs that were charged to expense, including amounts capitalized, and net of amounts capitalized, for the years ended December 31, 2025, 2024 and 2023:
For the Years Ended December 31,
Components of Stock-based Compensation Plan Costs 202520242023
(In millions)
Restricted stock units $35 $32 $39 
Restricted stock4 7 5 
401(k) savings plan39 41 38 
EDCP & DCPD7 6 1 
   Total stock based compensation costs $85 $86 $83 
Stock-based compensation costs, net of amounts capitalized$39 $43 $44 
Income tax benefits associated with stock-based compensation plan expense were $1 million, $5 million and $6 million for the years ended December 31, 2025, 2024 and 2023, respectively.

Restricted Stock Units

For RSU awards granted prior to 2025, two-thirds of each performance-based RSU award will be paid in FE common stock and one-third will be paid in cash, if and as earned. RSUs payable in stock provide the participant the right to receive, at the end of the period of restriction, a number of shares of common stock equal to the number of stock units set forth in the agreement, subject to adjustment based on FirstEnergy's performance relative to financial targets applicable to each award. The grant date fair market value of the stock portion of the RSU award is measured based on the average of the high and low prices of FE common stock on the date of grant. The estimated grant date fair value for these awards is calculated using the Monte Carlo simulation method. RSUs include a relative total shareholder return as a performance metric, weighted at 35%, utilizing the S&P 500 Utility Index as a comparator group and 65% based upon three year cumulative earnings targets. In addition, outstanding awards are subject to an absolute total shareholder return, if FirstEnergy's total shareholder return is negative for the three-year cumulative performance period, RSU awards will be capped at a payout of 100%.

RSUs payable in cash provide the participant the right to receive cash based on the number of stock units set forth in the agreement and value of the equivalent number of shares of FE common stock as of the vesting date. The cash portion of the RSU award is considered a liability award, which is remeasured each period based on FE's stock price and projected performance adjustments. The liability recorded for the portion of performance-based RSUs payable in cash in the future as of December 31, 2025, was $17 million. During 2025, approximately $6 million was paid in relation to the cash portion of RSU obligations that vested in 2025.

Beginning with RSU awards granted in 2025, RSU awards no longer are partially paid in cash and instead are paid fully in FE common stock, with 40% of the award being time-based and 60% performance-based. The time-based RSUs vest over a three-year performance period and pays out in stock if the participant remains employed with FirstEnergy on the vest date (generally, March 1). The performance-based RSUs maintain a relative total shareholder return as a performance metric, weighted at 35%, utilizing the S&P 500 Utility Index as a comparator group and 65% based on three year cumulative earnings targets. The grant date fair market value is measured based on the average of the high and low prices of FE common stock on the date of grant. The estimated grant date fair value for these awards is also calculated using the Monte Carlo simulation method. In addition, outstanding awards are subject to an absolute total shareholder return, if FirstEnergy's total shareholder return is negative for the three-year cumulative performance period, RSU awards will be capped at a payout of 100%.

The vesting period for RSU awards granted in 2025, 2024 and 2023, were each approximately three years. Dividend equivalents are received on the RSUs and are reinvested in additional RSUs and subject to the same performance conditions as the underlying award.

Restricted stock unit activity for the year ended December 31, 2025, was as follows:
Restricted Stock Unit Activity
Shares
(in millions)
Weighted-Average Grant Date Fair Value (per share)
Nonvested as of January 1, 20252.8 $37.32 
Granted in 20251.1 39.94 
Forfeited in 2024(0.4)39.48 
Vested in 2025(1)
(0.6)38.38 
Nonvested as of December 31, 20252.9 $36.38 
(1) Excludes dividend equivalents of approximately 67 thousand shares earned during vesting period.

The weighted-average fair value per share of awards granted in 2025, 2024 and 2023 was $39.94, $36.79 and $38.36 per share, respectively. During the years ended 2025, 2024 and 2023, the fair value of RSUs vested was $23 million, $55 million, and $24 million, respectively. As of December 31, 2025, there was approximately $38 million of total unrecognized compensation cost related to nonvested share-based compensation arrangements granted for RSUs, which is expected to be recognized over a period of approximately three years.

Restricted Stock

Certain employees may receive awards of FE restricted stock (as opposed to RSUs described above) subject to restrictions that lapse over a defined period of time. The fair value of restricted stock is measured based on the average of the high and low prices of FE common stock on the date of grant. Dividends are received on the restricted stock and are reinvested in additional shares of restricted stock, subject to the vesting conditions of the underlying award. Restricted stock activity for the year ended 2025, was as follows:
Restricted Stock Activity
Shares
(in millions)
Weighted-Average Grant Date Fair Value (per share)
Nonvested as of January 1, 20250.27 $38.29 
Granted in 20250.06 41.98 
Forfeited in 2025(0.01)38.16 
Vested in 2025(0.08)39.71 
Nonvested as of December 31, 20250.24 $38.70 
The weighted average vesting period for restricted stock granted in 2025 was 1.86 years. As of December 31, 2025, there was $3 million of total unrecognized compensation cost related to non-vested restricted stock, which is expected to be recognized over a period of approximately 2.5 years.

401(k) Savings Plan

In each of 2025 and 2024, approximately 1 million shares of FE common stock, respectively, were issued and contributed to employee participants' accounts.

EDCP

Under the EDCP, certain employees can defer a portion of their compensation, including base salary, annual incentive awards and/or long-term incentive awards, into unfunded accounts. Annual incentive and long-term incentive awards may be deferred in FE stock accounts, where they are tracked as units. Base salary and annual incentive awards may be deferred into a retirement cash account which earns interest. Dividend equivalents are calculated quarterly on stock units outstanding and are credited in the form of additional stock units. Awards deferred into a retirement stock account will convert to cash upon separation, including retirement, death or disability, and pay out in cash as a lump sum or over a defined period of time period as elected by the participant. Interest accrues on the cash allocated to the retirement cash account. The liability recognized for EDCP of approximately $153 million ($3 million at JCP&L) and $166 million ($3 million at JCP&L) as of December 31, 2025 and 2024, respectively, is included in “Retirement benefits,” on the Registrants' Balance Sheets.

DCPD

Under the DCPD, members of the FE Board can elect to defer all or a portion of their equity retainers to a deferred stock account and their cash retainers to deferred stock or deferred cash accounts. The net liability recognized for DCPD of approximately $4 million as of December 31, 2025 and 2024, respectively, is included in “Retirement benefits,” on the FirstEnergy's Balance Sheets.
v3.25.4
TAXES
 12 Months Ended
Dec. 31, 2025
Income Tax Disclosure [Abstract]  
TAXES TAXES
The disclosures in this note apply to both Registrants, unless indicated otherwise.
The Registrants record income taxes in accordance with the liability method of accounting. Deferred income taxes reflect the net tax effect of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts recognized for tax purposes. Investment tax credits, which were deferred when utilized, are being amortized over the recovery period of the related property. Deferred income tax liabilities related to temporary tax and accounting basis differences and tax credit carryforward items are recognized at the statutory income tax rates in effect when the liabilities are expected to be paid. Deferred tax assets are recognized based on income tax rates expected to be in effect when they are settled.

FE and its subsidiaries, other than FET and its subsidiaries, are parties to an intercompany income tax allocation agreement that provides for the allocation of consolidated tax liabilities. For periods subsequent to the closing of the FET Equity Interest Sale, FET and its subsidiaries are no longer members of the FirstEnergy consolidated group for federal income tax purposes and, instead, file their own consolidated federal income tax return and have their own income tax allocation agreement.

During 2025, FERC issued orders to a non-affiliate concluding that, based on certain previously issued IRS private letter rulings, certain NOL carryforward deferred tax assets, as computed on a separate return basis, should be included in rate base for ratemaking purposes. FirstEnergy determined in the third quarter of 2025 that these rulings and orders also would apply to certain of its subsidiaries, resulting in a benefit from a reduction in regulatory liabilities, reflected as the remeasurement of excess deferred income taxes, and an increase in accumulated deferred income tax assets for ratemaking purposes, which will increase overall rate base. FirstEnergy made the appropriate updates in its annual formula rates for the impacted subsidiaries. FirstEnergy will continue to evaluate whether regulatory filings are required in other jurisdictions to implement similar adjustments to NOL carryforward deferred tax assets for ratemaking purposes.

On July 4, 2025, President Trump signed into law the OBBBA, which, among other things, makes permanent certain corporate tax incentives that were set to expire in the TCJA, and terminates tax credits for most wind and solar projects placed in service
after 2027. Because many of the provisions of the TCJA will be continued under the OBBBA, and as FirstEnergy is not materially impacted by tax incentives associated with wind and solar projects, FirstEnergy does not expect to be materially impacted by the OBBBA.

On September 30, 2025, the IRS issued additional guidance on the corporate AMT. While FirstEnergy continues to believe, more likely than not, it will be subject to corporate AMT, additional IRS guidance or revised U.S. Treasury regulations, which are expected to be issued in the future, as well as potential tax legislation or presidential executive orders could provide certain adjustments to regulated utilities in calculating corporate AMT, which may reduce or otherwise significantly change FirstEnergy’s AMT estimates or its conclusions as to whether it is an AMT payer. JCP&L is party to an intercompany income tax allocation agreement with FirstEnergy and, accordingly, may be allocated a share of any corporate AMT paid by the FirstEnergy consolidated tax group. Any adverse developments concerning corporate AMT liability, including guidance from the U.S. Treasury and/or the IRS or unfavorable regulatory treatment by FERC and/or applicable state regulatory authorities, could negatively impact FirstEnergy’s cash flows, results of operations and financial condition.

On March 25, 2024, FirstEnergy closed on the FET Equity Interest Sale realizing an approximate $7 billion tax gain from the combined sale of 49.9% of the equity interests of FET for consideration received and recapture of negative tax basis in FET, a majority of such gain utilizing existing federal NOL carryforwards. In the first quarter of 2024, FirstEnergy recognized a net tax charge of approximately $46 million, comprised of updates to estimated deferred tax liability for the deferred gain from the 19.9% FET equity interest sale in May 2022, deferred tax liability related to its ongoing investment in FET, and valuation allowance associated with the expected utilization of certain state NOL carryforwards impacted by the sale and the PA Consolidation, and recognized a reduction to OPIC of approximately $803 million for federal and state income tax associated with the tax gain from closing on the FET Equity Interest Sale.

The following table provides the composite of income taxes on income from continuing operations of FirstEnergy for the years ended 2025, 2024 and 2023:

INCOME TAXES ON INCOME FROM CONTINUING OPERATIONS - FIRSTENERGYFor the Years Ended December 31,
202520242023
(In millions)
Currently payable -
Federal$58 $32 $14 
State11 291
69 61 15 
Deferred, net -   
Federal(1)
135 190 279 
State88 130 (24)
223 320 255 
Investment tax credit amortization(4)(4)(3)
Total income taxes on income from continuing operations$288 $377 $267 
(1) Excludes $21 million of federal tax expense associated with discontinued operations for the year ended December 31, 2023.
The following table provides the composite of income taxes of JCP&L for the years ended 2025, 2024 and 2023:

JCP&L (1)
For the Years Ended December 31,
INCOME TAXES:202520242023
(In millions)
Currently receivable -
Federal$(36)$(143)$(7)
State— — (8)
(36)(143)(15)
Deferred, net -
Federal108 200 34 
State35 30 14 
143 230 48 
Total income taxes$107 $87 $33 

(1) Previously issued 2024 and 2023 JCP&L amounts have been revised due to the correction of immaterial errors as discussed in Note 1., "Organization and Basis of Presentation," of the Combined Notes to Financial Statements of the Registrants.

Tax rates are affected by permanent items, such as AFUDC equity and other flow-through items, as well as discrete items that may occur in any given period but are not consistent from period to period. The following tables present a reconciliation of income tax expense at the U.S. federal statutory tax rate to the actual tax expense from continuing operations for the years ended December 31, 2025, 2024 and 2023:
For the Year Ended December 31, 2025
(In millions) FirstEnergy JCP&L
Amount %Amount%
Income before income taxes$1,559 $413 
Federal statutory income tax$327 21.0 %$87 21.0 %
Federal
Tax credits(5)(0.3)%— — %
Nontaxable and Nondeductible
AFUDC equity income(23)(1.5)%(6)(1.4)%
AFUDC equity depreciation4 0.3 %— — %
Tax related to FE's equity investment in FET13 0.8 %— — %
Changes in valuation allowances3 0.2 %— — %
Other
Excess deferred tax amortization(42)(2.7)%(1)(0.2)%
Remeasurement of excess deferred income taxes(70)(4.5)%— — %
Federal and state related flow-through(37)(2.4)%(2)(0.5)%
Deferred taxes associated with FET equity interest sale6 0.4 %— — %
Other 2 0.1 %— — %
Changes in unrecognized tax benefits1 0.1 %— — %
State and municipal income taxes, net of federal effect (1) (2)
109 7.0 %29 7.0 %
Total income taxes (3)
$288 18.5 %$107 25.9 %
(1) Valuation allowances have been established for certain state NOL carryforwards that reduce deferred tax assets to an amount that will be realized on a more-likely-than-not basis. The net change in the total valuation allowance is included in state income tax, net of federal income tax effect, in the above tables.
(2) Jurisdictions that make up the majority of the Registrants' respective domestic state income taxes, net of federal effect, are Pennsylvania for FirstEnergy and New Jersey for JCP&L.
(3) There were no amounts for the year ended December 31, 2025 at FirstEnergy or JCP&L related to cross-border tax laws, changes in laws or rates, or foreign tax effects.
For the Year Ended December 31, 2024
(In millions) FirstEnergy
JCP&L (4)
Amount%Amount%
Income before income taxes $1,504 $329 
Federal statutory income tax$316 21.0 %$69 21.0 %
Federal
Tax credits(6)(0.4)%— — %
Nontaxable and Nondeductible— %
AFUDC equity income(13)(0.9)%(1)(0.3)%
AFUDC equity depreciation1 0.1 %— — %
Nondeductible SEC and OAG Settlements27 1.8 %— — %
Tax related to FE's equity investment in FET16 1.1 %— — %
Changes in valuation allowances1 0.1 %— — %
Other
Excess deferred tax amortization(52)(3.5)%(4)(1.3)%
Remeasurement of excess deferred income taxes(43)(2.9)%— — %
Federal and state related flow-through(18)(1.2)%— — %
Deductions associated with certain equity investments(19)(1.3)%— — %
Deferred taxes associated with FET equity interest sale6 0.4 %— — %
Other 6 0.4 %— — %
State and municipal income taxes, net of federal effect (1) (2)
155 10.3 %23 7.0 %
Total income taxes (3)
$377 25.1 %$87 26.4 %
(1) Valuation allowances have been established for certain state NOL carryforwards that reduce deferred tax assets to an amount that will be realized on a more-likely-than-not basis. The net change in the total valuation allowance is included in state income tax, net of federal income tax effect, in the above tables.
(2) Jurisdictions that make up the majority of the Registrants' respective domestic state income taxes, net of federal effect, are Pennsylvania and West Virginia for FirstEnergy; and New Jersey for JCP&L.
(3) There were no amounts for the year ended December 31, 2024 at FirstEnergy or JCP&L related to cross-border tax laws, changes in laws or rates, foreign tax effects, or changes in unrecognized tax benefits.
(4) Previously issued 2024 JCP&L amounts have been revised due to the correction of immaterial errors as discussed in Note 1., "Organization and Basis of Presentation," of the Combined Notes to Financial Statements of the Registrants.
For the Year Ended December 31, 2023
(In millions )FirstEnergy
JCP&L (4)
Amount %Amount%
Income from continuing operations, before income taxes$1,464 $158 
Federal statutory income tax$307 21.0 %$33 21.0 %
Federal
Tax credits(6)(0.4)%— — %
Nontaxable and Nondeductible
AFUDC equity income(9)(0.6)%(1)(0.6)%
AFUDC equity depreciation6 0.4 %— — %
Changes in valuation allowances(33)(2.3)%— — %
Other
Excess deferred tax amortization(46)(3.1)%(4)(2.6)%
Federal and state related flow-through(27)(1.8)%— — %
Deferred taxes associated with FET equity interest sale58 4.0 %— — %
Other 9 0.6 %(1)(0.6)%
Changes in unrecognized tax benefits41 2.8 %(28)(17.8)%
State and municipal income taxes, net of federal effect (1) (2)
(33)(2.3)%34 21.5 %
Total income taxes on income from continuing operations$267 18.2 %$33 20.9 %
(1) Valuation allowances have been established for certain state NOL carryforwards at FirstEnergy that reduce deferred tax assets to an amount that will be realized on a more-likely-than-not basis. The net change in the total valuation allowance is included in state income tax, net of federal income tax effect, in the above tables.
(2) Jurisdictions that make up the majority of the Registrants' respective domestic state income taxes, net of federal effect, are Pennsylvania and West Virginia for FirstEnergy; and New Jersey for JCP&L.
(3) There were no amounts for the year ended December 31, 2023 at FirstEnergy or JCP&L related to cross-border tax laws, changes in laws or rates, or foreign tax effects
(4) Previously issued 2023 JCP&L amounts have been revised due to the correction of immaterial errors as discussed in Note 1., "Organization and Basis of Presentation," of the Combined Notes to Financial Statements of the Registrants.
Net accumulated deferred income tax liabilities (assets) as of December 31, 2025 and 2024, are as follows:
FirstEnergyAs of December 31,
(In millions)20252024
Property basis differences$6,579 $6,079 
Pension and OPEB(249)(322)
Regulatory asset/liability732 744 
Loss carryforwards and tax credits(920)(762)
Valuation allowances245 240 
Other(355)(366)
Net accumulated deferred income tax liability$6,032 $5,613 
JCP&L (1)
As of December 31,
(In millions)20252024
Property basis differences$1,330 $1,167 
Pension and OPEB(78)(99)
Regulatory asset/liability366 296 
Loss and credit carryforwards(199)(116)
Nuclear fuel disposal costs(66)(59)
Other(5)3 
Net accumulated deferred income tax liability$1,348 $1,192 
(1) Previously issued 2024 JCP&L amounts have been revised due to the correction of immaterial errors as discussed in Note 1., "Organization and Basis of Presentation," of the Combined Notes to Financial Statements of the Registrants.
FirstEnergy has recorded as deferred income tax assets the effect of federal NOLs and tax credits that will more likely than not be realized through future operations and through the reversal of existing temporary differences. As of December 31, 2025, FirstEnergy's loss carryforwards primarily consisted of approximately $2.2 billion ($454 million, net of tax) of federal NOL carryforwards, none of which have an expiration, but are subject to usage limitations in any single taxable year, and $18 million of corporate AMT credit carryforwards, which have no expiration.

The table below summarizes FirstEnergy's pre-tax NOL carryforwards and their respective anticipated expirations for state and local income tax purposes of approximately $13.7 billion ($447 million, net of tax), of which approximately $5.2 billion ($226 million, net of tax) is expected to be utilized based on current estimates and assumptions. The ultimate utilization of these state and local NOLs may be impacted by statutory limitations on the use of NOLs imposed by state and local tax jurisdictions, changes in statutory tax rates, and changes in business which, among other things, impact both future profitability and the manner in which future taxable income is apportioned to various state and local tax jurisdictions.
Expiration Period (FirstEnergy)StateLocal
(In millions)
2026-2030$1,658 $6,161 
2031-20351,168 — 
2036-20401,026 — 
2041-20451,216 — 
Indefinite2,451 — 
$7,519 $6,161 
JCP&L has recorded as deferred income tax assets the effect of NOLs and tax credits that will more likely than not be realized through future operations and through the reversal of existing temporary differences. As of December 31, 2025, JCP&L's loss carryforwards consisted primarily of approximately $299 million ($63 million, net of tax) of federal NOL carryforwards, none of which have an expiration, but are subject to usage limitations in any single taxable year, and approximately $1.9 billion ($135 million, net of tax) of state NOL carryforwards that are expected to be utilized based on current estimates and assumptions prior to expiration, which will begin in 2032.

The following table summarizes the changes in valuation allowances on federal, state, and local deferred tax assets related to business interest expense carryforwards and employee compensation deduction limitations under section 162(m), in addition to state and local NOLs discussed above for the years ended December 31, 2025, 2024 and 2023:

FirstEnergy (In millions)202520242023
Beginning of year balance$240 $226 $440 
Charged to income5 14 (214)
Charged to other accounts— — — 
Write-offs— — — 
End of year balance$245 $240 $226 

The Registrants account for uncertainty in income taxes recognized in its financial statements. A recognition threshold and measurement attribute are utilized for financial statement recognition and measurement of tax positions taken or expected to be taken on the tax return. If ultimately recognized in future years, all of the unrecognized income tax benefits would impact the effective tax rate.
The following table summarizes the changes (gross) in uncertain tax positions for the years ended December 31, 2025, 2024 and 2023:
(In millions)FirstEnergyJCP&L
Balance, January 1, 2023$42 $25 
Prior year increases88 — 
Effectively settled with taxing authorities(24)(24)
        Decrease for lapse in statute(1)— 
Balance, December 31, 2023$105 $1 
Prior year increases— — 
Effectively settled with taxing authorities— — 
        Decrease for lapse in statute— — 
Balance, December 31, 2024$105 $1 
Prior years increases— — 
Effectively settled with taxing authorities— — 
        Decrease for lapse in statute— — 
Balance, December 31, 2025$105 $1 

The Registrants recognize interest expense or income and penalties related to uncertain tax positions in income taxes by applying the applicable statutory interest rate to the difference between the tax position recognized and the amount previously taken, or expected to be taken, on the tax return. The Registrants include interest expense or income and penalties in the provision for income taxes. Due to uncertain tax positions that were effectively settled with tax authorities during 2023, approximately $9 million in net interest was reversed at JCP&L. During 2025, the Registrants recognized an immaterial amount of interest associated with their unrecognized tax benefits, and their respective cumulative net interest payable balance as of December 31, 2025 was also not material.

FirstEnergy's consolidated federal income tax returns for years 2022 and forward remain open to potential IRS examination. JCP&L is a party to the FirstEnergy consolidated group for federal income taxes, and as a result, is included in FirstEnergy's consolidated federal income tax returns. FET and subsidiaries are parties to their own consolidated federal income tax return for the period starting in 2024 subsequent to the closing of the FET Equity Interest Sale, and such return remains open to potential IRS examination. Prior to the FET Equity Interest Sale, FET and its subsidiaries were also parties to the FirstEnergy consolidated group for federal income taxes. FirstEnergy's state and local income tax returns remain open to potential examination in various jurisdictions from 2021 and forward. JCP&L's state income tax return in New Jersey remains open to potential examinations from 2021 and forward.
Income taxes paid, net of refunds, for the years ended December 31, 2025, 2024 and 2023, are as follows:

For the Years Ended December 31,
FirstEnergyJCP&L
(In millions)202520242023202520242023
Federal payments (receipts)
Internal Revenue Service$48 $146 $49 $(15)$(93)$(11)
Total Federal48 146 49 (15)(93)(11)
State & Municipal payments (receipts)
New Jersey— (8)— — (8)— 
Pennsylvania21 21 8 — — — 
Other4 2 1 — — — 
Total State & Municipal25 15 9 — (8)— 
Total Income Taxes Paid (net of Refunds)$73 $161 $58 $(15)$(101)$(11)

General Taxes

General tax expense for the years ended December 31, 2025, 2024 and 2023, recognized in continuing operations is summarized as follows:
FirstEnergy (In millions)For the Years Ended December 31,
202520242023
kWh excise$189 $186 $185 
State gross receipts278 247 235 
Real and personal property735 642 615 
Social security and unemployment126 113 113 
Other17 24 16 
Total general taxes$1,345 $1,212 $1,164 

JCP&L (In millions)For the Years Ended December 31,
202520242023
Real and personal property$7 $6 $7 
Social security and unemployment16 15 14 
Total general taxes$23 $21 $21 
v3.25.4
LEASES
 12 Months Ended
Dec. 31, 2025
Leases [Abstract]  
LEASES LEASES
The disclosures in this note apply to both Registrants, unless indicated otherwise.

The Registrants primarily lease vehicles as well as building space, office equipment, and other property and equipment under cancellable and non-cancelable leases. The Registrants do not have any material leases in which they are the lessor.

The Registrants account for leases under, "Leases (Topic 842)". Leases with an initial term of 12 months or less are recognized as lease expense on a straight-line basis over the lease term and not recorded on the balance sheet. Most leases include one or more options to renew, with renewal terms that can extend the lease term from 1 to 40 years, and certain leases include options to terminate. The exercise of lease renewal options is at FirstEnergy’s sole discretion. Renewal options are included within the lease liability if they are reasonably certain based on various factors relative to the contract. Certain leases also include options to purchase the leased property. The depreciable life of leased assets and leasehold improvements are limited by the expected lease term unless there is a transfer of title or purchase option reasonably certain of exercise. The Registrants' lease agreements do not contain any material restrictive covenants. The Registrants have elected a policy to not separate lease components from non-lease components for all asset classes.

For vehicles leased under certain master lease agreements, the lessor is guaranteed a residual value up to a stated percentage of the equipment cost at the end of the lease term. If the actual fair value of the leased equipment is below the guaranteed
residual value at the end of the lease term, the Registrants are committed to pay the difference in the actual fair value and the residual value guarantee. The Registrants do not believe it is probable that it will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly.

Finance leases for assets used in regulated operations are recognized in the Registrants' Statements of Income and Comprehensive Income such that amortization of the right-of-use asset and interest on lease liabilities equals the expense recorded for ratemaking purposes. Finance leases for regulated and non-regulated operations are accounted for as if the assets were owned and financed, with associated expense recognized in Interest expense and Provision for depreciation on the Registrants' Statements of Income and Comprehensive Income, while all operating lease expenses are recognized in Other operating expense.

The following tables represent FirstEnergy's components of lease expense for the years ended December 31, 2025, 2024 and 2023:
For the Year Ended December 31, 2025
(In millions)VehiclesBuildingsOtherTotal
Operating lease costs(1)
$106 $2 $5 $113 
Finance lease costs:
Amortization of right-of-use assets — 1 2 3 
Interest on lease liabilities — 2 — 2 
Total finance lease cost— 3 2 5 
Total lease cost $106 $5 $7 $118 
(1) Includes $45 million of short-term lease costs.

For the Year Ended December 31, 2024
(In millions)VehiclesBuildingsOtherTotal
Operating lease costs(1)
$82 $3 $6 $91 
Finance lease costs:
Amortization of right-of-use assets 1 1 2 4 
Interest on lease liabilities — 2 — 2 
Total finance lease cost1 3 2 6 
Total lease cost $83 $6 $8 $97 
(1) Includes $35 million of short-term lease costs.

For the Year Ended December 31, 2023
(In millions)VehiclesBuildingsOtherTotal
Operating lease costs(1)
$60 $5 $14 $79 
Finance lease costs:
Amortization of right-of-use assets 4 2 2 8 
Interest on lease liabilities — 5 — 5 
Total finance lease cost4 7 2 13 
Total lease cost $64 $12 $16 $92 
(1) Includes $27 million of short-term lease costs.
The following table represents JCP&L's components of lease expense for the years ended December 31, 2025, 2024 and 2023:
For the Year Ended December 31,
(In millions)202520242023
Operating lease costs(1)
$13 $11 $11 
Finance lease costs:
Amortization of right-of-use assets 1 1 1 
Interest on lease liabilities 1 1 1 
Total finance lease cost2 2 2 
Total lease cost $15 $13 $13 
(1) Includes short-term lease costs of $1 million for the year ended December 31, 2025 and $2 million for the years ended December 31, 2024 and 2023.

Supplemental cash flow information related to FirstEnergy's leases was as follows:
For the Years Ended December 31,
(In millions)202520242023
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases$71 $60 $54 
Operating cash flows from finance leases2 23
Finance cash flows from finance leases2 28
Right-of-use assets obtained in exchange for lease obligations:
Operating leases $104 $69 $13 
Finance leases — — — 

Supplemental cash flow information related to JCP&L's leases was as follows:
For the Years Ended December 31,
(In millions)202520242023
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases$13 $12 $11 
Operating cash flows from finance leases1 11
Finance cash flows from finance leases2 11
Right-of-use assets obtained in exchange for lease obligations:
Operating leases $24 $10 $3 
Finance leases — — — 

Lease terms and discount rates for FirstEnergy were as follows:
As of December 31,
202520242023
Weighted-average remaining lease terms (years)
Operating leases 6.405.625.93
Finance leases 12.7912.3812.26
Weighted-average discount rate(1)
Operating leases 5.16 %5.00 %4.51 %
Finance leases 16.24 %15.39 %14.73 %
(1) When an implicit rate is not readily determinable, an incremental borrowing rate is utilized, determining the present value of lease payments. The rate is determined based on expected term and information available at the commencement date.
Lease terms and discount rates for JCP&L were as follows:
As of December 31,
202520242023
Weighted-average remaining lease terms (years)
Operating leases 9.396.006.60
Finance leases 12.159.6010.30
Weighted-average discount rate(1)
Operating leases 5.83 %5.76 %5.68 %
Finance leases 15.94 %16.07 %16.15 %
(1) When an implicit rate is not readily determinable, an incremental borrowing rate is utilized, determining the present value of lease payments. The rate is determined based on expected term and information available at the commencement date.

Supplemental balance sheet information related to FirstEnergy's leases was as follows:
As of December 31,
(In millions)Financial Statement Line Item20252024
Assets
Operating lease(1)
Deferred charges and other assets$276 $228 
Finance lease(2)
Property, plant and equipment31 32 
Total leased assets $307 $260 
Liabilities
Current:
Operating Other current liabilities$60 $51 
Finance Currently payable long-term debt3 3 
Noncurrent:
Operating Other noncurrent liabilities227 192 
Finance Long-term debt and other long-term obligations7 9 
Total leased liabilities $297 $255 
(1) Operating lease assets are recorded net of accumulated amortization of $217 million and $174 million as of December 31, 2025 and 2024, respectively.
(2) Finance lease assets are recorded net of accumulated amortization of $17 million and $14 million as of December 31, 2025 and 2024, respectively.
Supplemental balance sheet information related to JCP&L's leases was as follows:
As of December 31,
(In millions)Financial Statement Line Item20252024
Assets
Operating lease(1)
Deferred charges and other assets$58 $43 
Finance lease(2)
Property, plant and equipment6 6 
Total leased assets $64 $49 
Liabilities
Current:
Operating Other current liabilities$11 $11 
Finance Currently payable long-term debt2 1 
Noncurrent:
Operating Other noncurrent liabilities56 43 
Finance Long-term debt and other long-term obligations2 4 
Total leased liabilities $71 $59 
(1) Operating lease assets are recorded net of accumulated amortization of $36 million and $30 million as of December 31, 2025 and 2024, respectively.
(2) Finance lease assets are recorded net of accumulated amortization of $6 million and $5 million as of December 31, 2025 and 2024, respectively.

Maturities of FirstEnergy's lease liabilities as of December 31, 2025, were as follows:
(In millions)Operating LeasesFinance LeasesTotal
2026$72 $4 $76 
202761 3 64 
202858 4 62 
202943 — 43 
203029 — 29 
Thereafter 85 — 85 
Total lease payments(1)
348 11 359 
Less imputed interest 61 1 62 
Total net present value$287 $10 $297 
(1) Operating lease payments for certain leases are offset by sublease receipts of $6 million over 7 years.

Maturities of JCP&L's lease liabilities as of December 31, 2025, were as follows:
(In millions)Operating LeasesFinance LeasesTotal
2026$13 $2 $15 
202711 2 13 
202813 — 13 
20299 — 9 
20307 — 7 
Thereafter 42 — 42 
Total lease payments(1)
95 4 99 
Less imputed interest 28 — 28 
Total net present value$67 $4 $71 
(1) Operating lease payments for certain leases are offset by sublease receipts of $5 million over 7 years.
As of December 31, 2025, lease agreements for vehicles and fiber lines that have not yet commenced for FirstEnergy are $14 million, which are expected to commence from 2026-2045 with lease terms of 5 to 20 years, and lease agreements for vehicles and fiber lines that have not yet commenced for JCP&L are $2 million, which are expected to commence in the next 18 months with lease terms of 5 to 20 years. In November 2024, JCP&L entered into a 22 year lease agreement for a new office located in Morris Plains, New Jersey. The lease commenced on November 25, 2025, and JCP&L took possession of the space to begin tenant improvements. The lease is classified as an operating lease, and a right-of-use asset of $16 million and a lease liability of $17 million were recognized by the Registrants on the commencement date, which amounts are reflected in the tables above.
LEASES LEASES
The disclosures in this note apply to both Registrants, unless indicated otherwise.

The Registrants primarily lease vehicles as well as building space, office equipment, and other property and equipment under cancellable and non-cancelable leases. The Registrants do not have any material leases in which they are the lessor.

The Registrants account for leases under, "Leases (Topic 842)". Leases with an initial term of 12 months or less are recognized as lease expense on a straight-line basis over the lease term and not recorded on the balance sheet. Most leases include one or more options to renew, with renewal terms that can extend the lease term from 1 to 40 years, and certain leases include options to terminate. The exercise of lease renewal options is at FirstEnergy’s sole discretion. Renewal options are included within the lease liability if they are reasonably certain based on various factors relative to the contract. Certain leases also include options to purchase the leased property. The depreciable life of leased assets and leasehold improvements are limited by the expected lease term unless there is a transfer of title or purchase option reasonably certain of exercise. The Registrants' lease agreements do not contain any material restrictive covenants. The Registrants have elected a policy to not separate lease components from non-lease components for all asset classes.

For vehicles leased under certain master lease agreements, the lessor is guaranteed a residual value up to a stated percentage of the equipment cost at the end of the lease term. If the actual fair value of the leased equipment is below the guaranteed
residual value at the end of the lease term, the Registrants are committed to pay the difference in the actual fair value and the residual value guarantee. The Registrants do not believe it is probable that it will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly.

Finance leases for assets used in regulated operations are recognized in the Registrants' Statements of Income and Comprehensive Income such that amortization of the right-of-use asset and interest on lease liabilities equals the expense recorded for ratemaking purposes. Finance leases for regulated and non-regulated operations are accounted for as if the assets were owned and financed, with associated expense recognized in Interest expense and Provision for depreciation on the Registrants' Statements of Income and Comprehensive Income, while all operating lease expenses are recognized in Other operating expense.

The following tables represent FirstEnergy's components of lease expense for the years ended December 31, 2025, 2024 and 2023:
For the Year Ended December 31, 2025
(In millions)VehiclesBuildingsOtherTotal
Operating lease costs(1)
$106 $2 $5 $113 
Finance lease costs:
Amortization of right-of-use assets — 1 2 3 
Interest on lease liabilities — 2 — 2 
Total finance lease cost— 3 2 5 
Total lease cost $106 $5 $7 $118 
(1) Includes $45 million of short-term lease costs.

For the Year Ended December 31, 2024
(In millions)VehiclesBuildingsOtherTotal
Operating lease costs(1)
$82 $3 $6 $91 
Finance lease costs:
Amortization of right-of-use assets 1 1 2 4 
Interest on lease liabilities — 2 — 2 
Total finance lease cost1 3 2 6 
Total lease cost $83 $6 $8 $97 
(1) Includes $35 million of short-term lease costs.

For the Year Ended December 31, 2023
(In millions)VehiclesBuildingsOtherTotal
Operating lease costs(1)
$60 $5 $14 $79 
Finance lease costs:
Amortization of right-of-use assets 4 2 2 8 
Interest on lease liabilities — 5 — 5 
Total finance lease cost4 7 2 13 
Total lease cost $64 $12 $16 $92 
(1) Includes $27 million of short-term lease costs.
The following table represents JCP&L's components of lease expense for the years ended December 31, 2025, 2024 and 2023:
For the Year Ended December 31,
(In millions)202520242023
Operating lease costs(1)
$13 $11 $11 
Finance lease costs:
Amortization of right-of-use assets 1 1 1 
Interest on lease liabilities 1 1 1 
Total finance lease cost2 2 2 
Total lease cost $15 $13 $13 
(1) Includes short-term lease costs of $1 million for the year ended December 31, 2025 and $2 million for the years ended December 31, 2024 and 2023.

Supplemental cash flow information related to FirstEnergy's leases was as follows:
For the Years Ended December 31,
(In millions)202520242023
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases$71 $60 $54 
Operating cash flows from finance leases2 23
Finance cash flows from finance leases2 28
Right-of-use assets obtained in exchange for lease obligations:
Operating leases $104 $69 $13 
Finance leases — — — 

Supplemental cash flow information related to JCP&L's leases was as follows:
For the Years Ended December 31,
(In millions)202520242023
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases$13 $12 $11 
Operating cash flows from finance leases1 11
Finance cash flows from finance leases2 11
Right-of-use assets obtained in exchange for lease obligations:
Operating leases $24 $10 $3 
Finance leases — — — 

Lease terms and discount rates for FirstEnergy were as follows:
As of December 31,
202520242023
Weighted-average remaining lease terms (years)
Operating leases 6.405.625.93
Finance leases 12.7912.3812.26
Weighted-average discount rate(1)
Operating leases 5.16 %5.00 %4.51 %
Finance leases 16.24 %15.39 %14.73 %
(1) When an implicit rate is not readily determinable, an incremental borrowing rate is utilized, determining the present value of lease payments. The rate is determined based on expected term and information available at the commencement date.
Lease terms and discount rates for JCP&L were as follows:
As of December 31,
202520242023
Weighted-average remaining lease terms (years)
Operating leases 9.396.006.60
Finance leases 12.159.6010.30
Weighted-average discount rate(1)
Operating leases 5.83 %5.76 %5.68 %
Finance leases 15.94 %16.07 %16.15 %
(1) When an implicit rate is not readily determinable, an incremental borrowing rate is utilized, determining the present value of lease payments. The rate is determined based on expected term and information available at the commencement date.

Supplemental balance sheet information related to FirstEnergy's leases was as follows:
As of December 31,
(In millions)Financial Statement Line Item20252024
Assets
Operating lease(1)
Deferred charges and other assets$276 $228 
Finance lease(2)
Property, plant and equipment31 32 
Total leased assets $307 $260 
Liabilities
Current:
Operating Other current liabilities$60 $51 
Finance Currently payable long-term debt3 3 
Noncurrent:
Operating Other noncurrent liabilities227 192 
Finance Long-term debt and other long-term obligations7 9 
Total leased liabilities $297 $255 
(1) Operating lease assets are recorded net of accumulated amortization of $217 million and $174 million as of December 31, 2025 and 2024, respectively.
(2) Finance lease assets are recorded net of accumulated amortization of $17 million and $14 million as of December 31, 2025 and 2024, respectively.
Supplemental balance sheet information related to JCP&L's leases was as follows:
As of December 31,
(In millions)Financial Statement Line Item20252024
Assets
Operating lease(1)
Deferred charges and other assets$58 $43 
Finance lease(2)
Property, plant and equipment6 6 
Total leased assets $64 $49 
Liabilities
Current:
Operating Other current liabilities$11 $11 
Finance Currently payable long-term debt2 1 
Noncurrent:
Operating Other noncurrent liabilities56 43 
Finance Long-term debt and other long-term obligations2 4 
Total leased liabilities $71 $59 
(1) Operating lease assets are recorded net of accumulated amortization of $36 million and $30 million as of December 31, 2025 and 2024, respectively.
(2) Finance lease assets are recorded net of accumulated amortization of $6 million and $5 million as of December 31, 2025 and 2024, respectively.

Maturities of FirstEnergy's lease liabilities as of December 31, 2025, were as follows:
(In millions)Operating LeasesFinance LeasesTotal
2026$72 $4 $76 
202761 3 64 
202858 4 62 
202943 — 43 
203029 — 29 
Thereafter 85 — 85 
Total lease payments(1)
348 11 359 
Less imputed interest 61 1 62 
Total net present value$287 $10 $297 
(1) Operating lease payments for certain leases are offset by sublease receipts of $6 million over 7 years.

Maturities of JCP&L's lease liabilities as of December 31, 2025, were as follows:
(In millions)Operating LeasesFinance LeasesTotal
2026$13 $2 $15 
202711 2 13 
202813 — 13 
20299 — 9 
20307 — 7 
Thereafter 42 — 42 
Total lease payments(1)
95 4 99 
Less imputed interest 28 — 28 
Total net present value$67 $4 $71 
(1) Operating lease payments for certain leases are offset by sublease receipts of $5 million over 7 years.
As of December 31, 2025, lease agreements for vehicles and fiber lines that have not yet commenced for FirstEnergy are $14 million, which are expected to commence from 2026-2045 with lease terms of 5 to 20 years, and lease agreements for vehicles and fiber lines that have not yet commenced for JCP&L are $2 million, which are expected to commence in the next 18 months with lease terms of 5 to 20 years. In November 2024, JCP&L entered into a 22 year lease agreement for a new office located in Morris Plains, New Jersey. The lease commenced on November 25, 2025, and JCP&L took possession of the space to begin tenant improvements. The lease is classified as an operating lease, and a right-of-use asset of $16 million and a lease liability of $17 million were recognized by the Registrants on the commencement date, which amounts are reflected in the tables above.
v3.25.4
VARIABLE INTEREST ENTITIES
 12 Months Ended
Dec. 31, 2025
Business Combination, Asset Acquisition, Transaction between Entities under Common Control, and Joint Venture Formation [Abstract]  
VARIABLE INTEREST ENTITIES VARIABLE INTEREST ENTITIES
The disclosures in this note apply to both Registrants, unless indicated otherwise.

The Registrants perform qualitative analyses to determine whether a variable interest qualifies them as the primary beneficiary (a controlling financial interest) of a VIE. An enterprise has a controlling financial interest if it has both: (i) the power to direct the activities of a VIE that most significantly impact the entity’s economic performance; and (ii) the obligation to absorb losses of the entity that could potentially be significant to the VIE or the right to receive benefits from the entity that could potentially be significant to the VIE. The Registrants consolidate a VIE when it is determined that it is the primary beneficiary. JCP&L does not have any consolidated or unconsolidated VIE's.

In order to evaluate contracts for consolidation treatment and entities for which FirstEnergy has an interest, FirstEnergy aggregates variable interests into categories based on similar risk characteristics and significance.

FirstEnergy - Consolidated VIEs
VIEs in which FirstEnergy is the primary beneficiary consist of the following and are included in FirstEnergy’s consolidated financial statements:
•Securitization Companies

•Ohio Securitization Companies - In June 2013, the SPEs formed by the Ohio Companies issued approximately $445 million of pass-through trust certificates supported by phase-in recovery bonds to securitize the recovery of certain all-electric customer heating discounts, fuel and purchased power regulatory assets. The phase-in recovery bonds are payable only from, and secured by, phase in recovery property owned by the SPEs. The bondholder has no recourse to the general credit of FirstEnergy or any of the Ohio Companies. Each of the Ohio Companies, as servicer of its respective SPE, manages and administers the phase in recovery property including the billing, collection and remittance of usage-based charges payable by retail electric customers. The SPEs are considered VIEs and each one is consolidated into its applicable utility. As of December 31, 2025 and 2024, $159 million and $175 million of the phase-in recovery bonds were outstanding, respectively.

•MP and PE Environmental Funding Companies - The consolidated financial statements of FirstEnergy include environmental control bonds issued by two bankruptcy remote, special purpose limited liability companies that are indirect subsidiaries of MP and PE. Proceeds from the bonds were used to construct environmental control facilities. Principal and interest owed on the environmental control bonds is secured by, and payable solely from, the proceeds of the environmental control charges. Creditors of FirstEnergy, other than the limited liability company SPEs, have no recourse to any assets or revenues of the special purpose limited liability companies. As of December 31, 2025 and 2024, $156 million and $188 million of environmental control bonds were outstanding, respectively.

•FirstEnergy's Consolidated Balance Sheets includes restricted cash of 40 million as of December 31, 2025 and 2024 which is related to cash collected from MP, PE and the Ohio Companies' customers that is specifically used to service debt of their respective funding companies.

•FET

•FET is a holding company that owns equity interests in ATSI, MAIT, TrAIL and PATH. As further discussed above, on February 2, 2023, FE entered into an agreement with Brookfield to sell an incremental 30% equity interest in FET, which closed on March 25, 2024. As of December 31, 2025 FE’s equity ownership in FET is 50.1% and Brookfield’s is 49.9%. FirstEnergy has concluded that FET is a VIE and that FE is the primary beneficiary because FE has exposure to the economics of FET and the power to direct significant activities of FET through the FESC services agreement, which represents a separate variable interest.

•Although Brookfield was granted incremental consent rights upon the closing of the FET Equity Interest Sale, Brookfield will not have unilateral control over any activities that most significantly impact FET’s economic performance. However, FE will continue to retain power over the activities that most significantly impact FET’s economic performance through its incremental decision making rights under the existing FESC services
agreement, through which executive management and workforce services are provided to FET. As a result, FE is the primary beneficiary of FET, which will continue to be consolidated in FirstEnergy’s financial statements.

•The assets of FET can only be used to settle its obligations, and creditors of FET do not have recourse to the general credit of FirstEnergy.

FirstEnergy - Unconsolidated VIEs

FirstEnergy is not the primary beneficiary of PATH-WV, as further discussed above in Note 1., Organization and Basis of Information – Equity Method Investments,” of the Combined Notes to Financial Statements of the Registrants. FirstEnergy was also not the primary beneficiary of its former 33-1/3% equity ownership in Global Holding, which was sold to WMB Marketing Ventures, LLC and Pinesdale LLC in July 2025.

•Valley Link - As of December 31, 2025, Valley Link is considered a VIE. Amounts related to Valley Link are immaterial for the year ended December 31, 2025. See Note 1., "Organization and Basis of Information – Equity Method Investments,” of the Combined Notes to Financial Statements of the Registrants for additional information related to Valley Link.

In 2025, FET, DominionHV and Transource issued an equity support agreement to enable Valley Link to enter into a credit facility with a third party. The equity support agreement expires once all Valley Link credit agreement obligations are satisfied or when FET has fulfilled its support obligations under the equity support agreement. As of December 31, 2025, the fair value of FET’s support obligations relating to the Valley Link credit facility was immaterial.
v3.25.4
ASSET RETIREMENT OBLIGATIONS
 12 Months Ended
Dec. 31, 2025
Asset Retirement Obligation [Abstract]  
ASSET RETIREMENT OBLIGATIONS ASSET RETIREMENT OBLIGATIONS
The disclosures in this note apply to both Registrants, unless indicated otherwise.

The Registrants recognize an ARO for their legal obligation to perform asset retirement activities associated with their long-lived assets. The ARO liability represents an estimate of the fair value of the Registrants’ current obligation such that the ARO is accreted monthly to reflect the time value of money.

A fair value measurement inherently involves uncertainty in the amount and timing of settlement of the liability. An expected cash flow approach is used to measure the fair value of the remediation AROs, taking into account the expected timing of settlement of the ARO based on the expected economic useful life of associated asset and/or regulatory requirements. The fair value of an ARO is recognized in the period in which it is incurred. The associated asset retirement costs are capitalized as part of the carrying value of the long-lived asset and are depreciated over the life of the related asset. For instances where asset retirement costs relate to assets that have no future cash flows, the costs are recorded as an operating expense. In certain circumstances, the Registrants have recovery of asset retirement costs and, as such, certain accretion and depreciation is offset against regulatory assets. Conditional retirement obligations associated with tangible long-lived assets are recognized at fair value in the period in which they are incurred if a reasonable estimate can be made, even though there may be uncertainty about timing or method of settlement. When settlement is conditional on a future event occurring, it is reflected in the measurement of the liability, not the timing of the liability recognition.

FirstEnergy has recognized applicable legal obligations for AROs and their associated costs, including reclamation of sludge disposal ponds, closure of CCR sites, underground and above-ground storage tanks and wastewater treatment lagoons. In addition, the Registrants have recognized conditional retirement obligations, primarily for asbestos remediation.
The following table summarizes the changes to the ARO balances as of December 31, 2025, and 2024.
FirstEnergy JCP&L
(In millions)
Balance, January 1, 2024
$209 $7 
Changes in timing and amount of estimated cash flows131 — 
Liabilities incurred95 — 
Liabilities settled (4)— 
Accretion24 1 
Balance, December 31, 2024
455 8 
Changes in timing and amount of estimated cash flows(51)— 
Liabilities incurred1 — 
Liabilities settled (1)
(154)— 
Accretion26 — 
Balance, December 31, 2025
$277 $8 
(1) FirstEnergy amounts include the transfer of the McElroy’s Run CCR impoundment facility as well as the adjacent dry landfill and related remediation obligations to a subsidiary of IDA Power, LLC, as further discussed below.
During 2024, as a result of the evaluation of closure options for McElroy’s Run CCR impoundment facility and the adjacent landfill, AE Supply reviewed its ARO and future expected costs to remediate, resulting in an increase to the ARO liability of $87 million, included within "Other operating expenses" and Corporate/Other for segment reporting. AE Supply transferred the McElroy’s Run CCR impoundment facility and adjacent dry landfill and related remediation obligations on March 4, 2025, pursuant to the environmental liability transfer agreement dated February 3, 2025, with a subsidiary of IDA Power, LLC. Pursuant to the agreement, AE Supply established a $160 million escrow account that AE Supply will fund over five years and is secured by a surety bond, which is guaranteed by FE. In connection with the transfer, AE Supply recognized a $130 million liability, based on a 4.8% weighted average discount rate over the contract term, associated with its remaining obligation to fund the escrow account over the next five years, and derecognized the ARO, resulting in an immaterial impact to earnings. During the year ended December 31, 2025, AE Supply made $46 million of cash payments to the escrow account.

As further discussed in Note 14., “Commitments, Guarantees, and Contingencies - Regulation of Waste Disposal,” of the Combined Notes to Financial Statements of the Registrants on May 8, 2024, the EPA finalized changes to the CCR rule addressing certain legacy CCR disposal sites that were not included in previous CCR rules. As a result, during 2024, FirstEnergy performed a preliminary assessment of former CCR disposal sites and calculated an initial estimate applying historical experience in remediating comparable sites. As a result, FirstEnergy recorded a $139 million increase to its ARO in 2024, of which $113 million is included in “Other operating expenses” on the Consolidated Statements of Income and was not capitalized as an asset retirement cost since the associated electric generation facilities are closed. Of the $113 million expensed in 2024, $16 million is included with Integrated, $46 million is included within Distribution and $51 million at Corporate/Other for segment reporting. JCP&L did not have any legacy CCR disposal sites that were applicable to the new CCR rule.

The ARO increase related to certain legacy CCR disposal sites represents the discounted cash flows for estimated closure costs based upon the potential closure requirements as evaluated on a site-by-site basis. Actual costs to be incurred will be dependent upon factors that vary from site to site. The most significant factors include the method and time frame of closure at the individual sites, which will be determined based on the groundwater monitoring and, if applicable, EPA approval of closure plans. In determining the estimated closure costs for each site, FirstEnergy has assumed the anticipated applicable closure method, however, alternative closure methods may be required, resulting in greater or lesser cost. As a result, the ARO liability may be adjusted as additional information is gained through the evaluation and closure process, including further inspection of the sites, results of groundwater monitoring and changes in interpretation of the CCR regulations which may change management assumptions, and could result in a material change to the ARO liability balance and FirstEnergy’s results of operations.

During the fourth quarter of 2025, FirstEnergy completed engineering studies and field analysis for certain of its legacy CCR disposal sites and determined that certain of those sites did not meet criteria to be applicable to the CCR rules. As a result, during the fourth quarter of 2025, FirstEnergy recorded a $49 million decrease to its ARO, all of which is included in "Other operating expenses" on the Consolidated Statements of Income and was not capitalized as an asset retirement cost since the associated electric generation facilities are closed. Of this $49 million pre-tax decrease to expense, $17 million is included at Integrated and $32 million at Corporate/Other for FirstEnergy's segment reporting.
v3.25.4
FAIR VALUE MEASUREMENTS
 12 Months Ended
Dec. 31, 2025
Fair Value Disclosures [Abstract]  
FAIR VALUE MEASUREMENTS FAIR VALUE MEASUREMENTS
The disclosures in this note apply to both Registrants, unless indicated otherwise.

RECURRING FAIR VALUE MEASUREMENTS

Authoritative accounting guidance establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. This hierarchy gives the highest priority to Level 1 measurements and the lowest priority to Level 3 measurements. The three levels of the fair value hierarchy and a description of the valuation techniques are as follows:
Level 1-Quoted prices for identical instruments in active market
Level 2-Quoted prices for similar instruments in active market
-Quoted prices for identical or similar instruments in markets that are not active
-Model-derived valuations for which all significant inputs are observable market data
Models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors and current market and contractual prices for the underlying instruments, as well as other relevant economic measures.
Level 3-Valuation inputs are unobservable and significant to the fair value measurement
FirstEnergy produces a long-term power and capacity price forecast annually with periodic updates as market conditions change. When underlying prices are not observable, prices from the long-term price forecast are used to measure fair value.

FTRs are financial instruments that entitle the holder to a stream of revenues (or charges) based on the hourly day-ahead congestion price differences across transmission paths. FTRs are acquired by FirstEnergy in the annual, monthly and long-term PJM auctions and are initially recorded using the auction clearing price less cost. After initial recognition, FTRs' carrying values are periodically adjusted to fair value using a mark-to-model methodology, which approximates market. The primary inputs into the model, which are generally less observable than objective sources, are the most recent PJM auction clearing prices and the FTRs' remaining hours. The model calculates the fair value by multiplying the most recent auction clearing price by the remaining FTR hours less the prorated FTR cost. Significant increases or decreases in inputs in isolation may have resulted in a higher or lower fair value measurement.

The Registrants primarily apply the market approach for recurring fair value measurements using the best information available. Accordingly, the Registrants maximize the use of observable inputs and minimizes the use of unobservable inputs. There were no changes in valuation methodologies used as of December 31, 2025, from those used as of December 31, 2024. The determination of the fair value measures takes into consideration various factors, including but not limited to, nonperformance risk, counterparty credit risk and the impact of credit enhancements (such as cash deposits, LOCs and priority interests). The impact of these forms of risk was not significant to the fair value measurements.

For investments reported at NAV where there is no readily determinable fair value, a practical expedient is available that allows the NAV to approximate fair value. Investments that use NAV as a practical expedient are excluded from the requirement to be categorized within the fair value hierarchy tables. Instead, these investments are reported outside of the fair value hierarchy tables to assist in the reconciliation of investment balances reported in the tables to the balance sheet. The Registrants have elected the NAV practical expedient for investments in private equity funds, insurance-linked securities, hedge funds (absolute return) and real estate funds held within the pension plan. See Note 4., "Pension and Other Postemployment Benefits,” of the Combined Notes to Financial Statements of the Registrants for the pension financial assets accounted for at fair value by level within the fair value hierarchy.
The following tables set forth the recurring assets and liabilities that are accounted for at fair value by level within the fair value hierarchy:
December 31, 2025December 31, 2024
Level 1Level 2Level 3TotalLevel 1Level 2Level 3Total
Assets(In millions)
Derivative assets FTRs(1)
$— $— $21 $21 $— $— $7 $7 
Equity securities2 — — 2 2 — — 2 
U.S. state debt securities(2)
— 280 — 280 — 276 — 276 
Cash, cash equivalents and restricted cash(3)
99 — — 99 154 — — 154 
Other(4)
— 56 — 56 — 45 — 45 
Total assets$101 $336 $21 $458 $156 $321 $7 $484 
Liabilities
Derivative liabilities FTRs(1)
$— $— $(1)$(1)$— $— $— $— 
Total liabilities$— $— $(1)$(1)$— $— $— $— 
Net assets (liabilities)$101 $336 $20 $457 $156 $321 $7 $484 
(1) Contracts are subject to regulatory accounting treatment and changes in market values do not impact earnings.
(2) Related to JCP&L’s investments held in the spent nuclear fuel disposal trusts, see below.
(3) Restricted cash of $42 million and $43 million as of December 31, 2025 and 2024, respectively, primarily relates to cash collected from MP, PE and the Ohio Companies' customers that is specifically used to service debt of their respective funding companies. See Note 11., "Capitalization,” of the Combined Notes to Financial Statements of the Registrants for additional information.
(4) Primarily consists of short-term investments, of which $17 million and $6 million as of December 31, 2025, and December 31, 2024, respectively, are held by JCP&L.

INVESTMENTS

All temporary cash investments purchased with an initial maturity of three months or less are reported as cash equivalents on the Consolidated Balance Sheets at cost, which approximates their fair market value. Investments other than cash and cash equivalents include AFS debt securities and other investments. The Registrants have no debt securities held for trading purposes.

Generally, unrealized gains and losses on equity securities are recognized in income whereas unrealized gains and losses on AFS debt securities are recognized in AOCI. However, the JCP&L spent nuclear fuel disposal trusts are subject to regulatory accounting with all gains and losses on equity and AFS debt securities offset against regulatory assets.

Spent Nuclear Fuel Disposal Trusts

JCP&L holds debt securities within the spent nuclear fuel disposal trust, which are classified as AFS securities, recognized at fair market value. The trust is intended for funding spent nuclear fuel disposal fees to the United States Department of Energy associated with the previously owned Oyster Creek and Three Mile Island Unit 1 nuclear power facilities.

The following table summarizes the amortized cost basis, unrealized gains, unrealized losses and fair values of investments held in nuclear fuel disposal trusts as of December 31, 2025 and 2024:
December 31, 2025(1)
December 31, 2024(2)
Cost BasisUnrealized GainsUnrealized LossesFair ValueCost BasisUnrealized GainsUnrealized LossesFair Value
(In millions)
Debt securities$290 $2 $(12)$280 $299 $— $(23)$276 
(1) Excludes short-term cash investments of $17 million as of December 31, 2025.
(2) Excludes short-term cash investments of $6 million as of December 31, 2024.
Proceeds from the sale of investments in AFS debt securities, realized gains and losses on those sales and interest and dividend income for the years ended December 31, 2025, 2024 and 2023, were as follows for the Registrants:
For the Years Ended December 31,
202520242023
(In millions)
Sale Proceeds$102 $121 $38 
Realized Gains1 — — 
Realized Losses(12)(15)(3)
Interest and Dividend Income13 13 12 


Other Investments

Other investments include employee benefit trusts, which are primarily invested in corporate-owned life insurance policies and equity method investments. Earnings and losses associated with corporate-owned life insurance policies and equity method investments are reflected in the “Miscellaneous Income, net” line of FirstEnergy’s Consolidated Statements of Income. Other investments were $344 million and $370 million as of December 31, 2025 and 2024, respectively, and are excluded from the amounts reported above. See Note 1., "Organization and Basis of Presentation," of the Combined Notes to Financial Statements of the Registrants for additional information on FirstEnergy's equity method investments.

For the years ended December 31, 2025, 2024 and 2023, pre-tax income related to corporate-owned life insurance policies were $19 million, $16 million and $18 million, respectively. Corporate-owned life insurance policies are valued using the cash surrender value and any changes in value during the period are recognized as income or expense.

LONG-TERM DEBT AND OTHER LONG-TERM OBLIGATIONS

All borrowings with initial maturities of less than one year are defined as short-term financial instruments under GAAP and are reported as Short-term borrowings on the Consolidated Balance Sheets at cost. Since these borrowings are short-term in nature, the Registrants believe that their costs approximate their fair market value. The following table provides the approximate fair value and related carrying amounts of long-term debt, which excludes finance lease obligations and net unamortized debt issuance costs, unamortized fair value adjustments, premiums and discounts as of December 31, 2025 and 2024:
As of December 31
FirstEnergy20252024
(In millions)
Carrying Value$26,390 $23,594 
Fair Value$25,756 $22,128 

As of December 31
JCP&L20252024
(In millions)
Carrying Value$3,050 $2,350 
Fair Value$3,059 $2,284 

The fair values of long-term debt and other long-term obligations reflect the present value of the cash outflows relating to those securities based on the current call price, the yield to maturity or the yield to call, as deemed appropriate at the end of each respective period. The yields assumed were based on securities with similar characteristics offered by corporations with credit ratings similar to those of the Registrants. The Registrants classified short-term borrowings, long-term debt and other long-term obligations as Level 2 in the fair value hierarchy as of December 31, 2025 and 2024.

See Note 11., "Capitalization,” of the Combined Notes to Financial Statements of the Registrants for further information on long-term debt issued and redeemed during the twelve months ended December 31, 2025.
v3.25.4
CAPITALIZATION
 12 Months Ended
Dec. 31, 2025
Capitalization, Long-Term Debt and Equity [Abstract]  
CAPITALIZATION CAPITALIZATION
The disclosures in this note apply to both Registrants, unless indicated otherwise.

COMMON STOCK

Dividends

Dividends declared and paid per share of FE common stock during 2025 and 2024 were as follows:
Dividends Declared Dividends Paid
2025202420252024
Q1 $0.445 $0.425 $0.425 $0.410 
Q2— — 0.445 0.425 
Q30.890 0.850 0.445 0.425 
Q40.445 0.425 0.445 0.425 
Total $1.780 $1.700 $1.760 $1.685 

The amount and timing of all dividend declarations are subject to the discretion of the FE Board and its consideration of earnings, cash flows, credit metrics, as well as general economic and business conditions. In addition to declaring dividends from retained earnings, FE can declare dividends from paid-in capital accounts.

When FE makes distributions to shareholders, it is required to subsequently determine and report the tax characterization of those distributions for purposes of shareholders’ income taxes. Whether a distribution is characterized as a dividend or a return of capital (and possible capital gain) depends upon an internal tax calculation to determine earnings and profits for income tax purposes. Earnings and profits should not be confused with earnings or net income under GAAP. Further, after FE reports the expected tax characterization of distributions it has paid, the actual characterization could vary from its expectation with the result that holders of FE's common stock could incur different income tax liabilities than expected.

In general, distributions are characterized as dividends to the extent the amount of such distributions do not exceed FE's calculation of current or accumulated earnings and profits. Distributions in excess of current and accumulated earnings and profits may be treated as a non-taxable return of capital. Generally, a non-taxable return of capital will reduce an investor’s basis in FirstEnergy's stock for federal tax purposes, which will impact the calculation of gain or loss when the stock is sold.

FE realized an approximate $7 billion tax gain in 2024 from closing the FET Equity Interest Sale, which created sufficient earnings and profits to cause distributions made during 2024 and 2025 to be characterized as dividends for federal income tax purposes. Although FirstEnergy anticipates, based on current projections of earnings and profits, that distributions in the next several years also may be characterized as dividends for federal income tax purposes, such estimates can change and upon such characterization, shareholders are urged to consult their own tax advisors regarding the income tax treatment of FE's distributions to them.

In addition to paying dividends from retained earnings, the Ohio Companies and JCP&L have authorization from FERC to pay cash dividends to FE from paid-in capital accounts, as long as their FERC-defined equity-to-total-capitalization ratio remains above 35%. FERC also approved such authorization for TrAIL to pay cash dividends to FET from paid in-capital accounts in December 2025. In addition, AGC has authorization from FERC to pay cash dividends to its parent, MP, from paid-in capital accounts, as long as its FERC-defined equity-to-total-capitalization ratio remains above 45%. The governance documents, indentures, regulatory limitations, and FET P&SA II, and various other agreements, including those relating to the long-term debt of certain FirstEnergy subsidiaries contain provisions that could further restrict the payment of dividends on their common stock. As of December 31, 2025, none of these provisions materially restricted FirstEnergy subsidiaries’ abilities to pay cash dividends to their respective parent company.
Common Stock Issuance

FE issued approximately 1 million shares of common stock in 2025, 3 million shares of common stock in 2024 and 2 million shares of common stock in 2023 to registered shareholders and its directors and the employees of its subsidiaries under its Stock Investment Plan and certain share-based benefit plans.

PREFERRED AND PREFERENCE STOCK

FirstEnergy and certain of its subsidiaries are authorized to issue preferred stock and preference stock as of December 31, 2025, as follows:
Preferred StockPreference Stock
Shares AuthorizedPar ValueShares AuthorizedPar Value
FE5,000,000 $100   
OE6,000,000 $100 8,000,000 no par
OE8,000,000 $25   
CEI4,000,000 no par3,000,000 no par
TE3,000,000 $100 5,000,000 $25 
TE12,000,000 $25 
JCP&L15,600,000 no par
MP940,000 $100 
PE10,000,000 $0.01 

As of December 31, 2025 and 2024, there were no preferred stock or preference stock outstanding.

LONG-TERM DEBT AND OTHER LONG-TERM OBLIGATIONS

The following tables present outstanding long-term debt and finance lease obligations for FirstEnergy and JCP&L as of December 31, 2025 and 2024:

FirstEnergyAs of December 31, 2025As of December 31,
Maturity DateInterest Rate20252024
(In millions)
FMBs and secured notes - fixed rate2026-2059
2.650% - 8.250%
$5,214 $4,963 
Unsecured notes - fixed rate2026-2050
2.250% - 6.875%
21,176 18,631 
Finance lease obligations10 12 
Unamortized debt discounts(20)(14)
Unamortized debt issuance costs(150)(122)
Unamortized fair value adjustments1 3 
Currently payable long-term debt(723)(977)
Total long-term debt and other long-term obligations$25,508 $22,496 

JCP&LAs of December 31, 2025As of December 31,
Maturity DateInterest Rate20252024
(In millions)
Unsecured notes - fixed rate2029-2037
2.750% - 6.400%
$3,050 $2,350 
Finance lease obligations4 5 
Unamortized debt premiums/discounts(7)(4)
Unamortized debt issuance costs(22)(11)
Currently payable long-term debt(2)(1)
Total long-term debt and other long-term obligations$3,023 $2,339 
See Note 7., "Leases,” of the Combined Notes to Financial Statements of the Registrants for additional information related to finance leases.
FirstEnergy had the following redemptions and issuances during the twelve months ended December 31, 2025:

CompanyTypeRedemption/Issuance DateInterest RateMaturityAmount
(In millions)		Description
Redemptions
FESenior Unsecured NotesMarch, 20252.05%2025$300FE redeemed unsecured notes that became due.
TrAILSenior Unsecured NotesMay, 20253.76%2025$75TrAIL redeemed unsecured notes that became due.
TrAILSenior Unsecured NotesJune, 20253.85%2025$550TrAIL redeemed unsecured notes that became due.
FESenior Unsecured Convertible NotesJune, 20254.00%2026$1,206
FE repurchased approximately $1,206 million of the principal amount of its 2026 Convertible Notes for $1,225 million, including a premium of approximately $19 million.
JCP&LSenior Unsecured NotesOctober, 20254.30%2026$650
On October 16, 2025, JCP&L redeemed $650 million of 4.30% senior notes due 2026.
FESenior Unsecured NotesDecember, 20251.60%2026$300
On December 31, 2025, FE redeemed $300 million of 1.60% senior notes due 2026.
Issuances
TrAILSenior Unsecured NotesApril, 20255.00%2031$600Proceeds were used to redeem senior notes that came due in 2025, to refinance existing debt, for working capital, and for other general corporate purposes.
ATSISenior Unsecured NotesMay, 20255.00%2030$225Proceeds were used to refinance existing debt, to finance capital expenditures, for working capital, and for other general corporate purposes.
OESenior Unsecured NotesMay, 20254.95%2029$300Proceeds were used to refinance existing debt, to finance capital expenditures, for working capital, and for other general corporate purposes.
MAITSenior Unsecured NotesJune, 20255.00%2031$200Proceeds were used to refinance existing debt, to finance capital expenditures, for working capital, and for other general corporate purposes.
PEFMBsJune, 20255.00%2030$200Proceeds were used to refinance existing debt, to finance capital expenditures, for working capital, and for other general corporate purposes.
TESenior Secured NotesJune, 20255.18%2030$100Proceeds were used to refinance existing debt, to finance capital expenditures, for working capital, and for other general corporate purposes.
FE Senior Unsecured Convertible NotesJune, 20253.63%2029$1,350Proceeds were used to refinance existing debt, to repurchase a portion of its 2026 Convertible Notes, and for other general corporate purposes.
FE Senior Unsecured Convertible NotesJune, 20253.88%2031$1,150Proceeds were used to refinance existing debt, to repurchase a portion of its 2026 Convertible Notes, and for other general corporate purposes.
FETSenior Unsecured NotesAugust, 20254.75%2033$450Proceeds were used to refinance existing debt, to finance capital expenditures, for working capital, and for other general corporate purposes.
JCP&LSenior Unsecured NotesSeptember, 2025 4.15%2029$350
Proceeds were used to refinance existing debt, including the repayment of the remaining $650 million aggregate principal amount of JCP&L’s 4.30% senior notes due 2026, to finance capital expenditures, and for other general corporate purposes.
JCP&LSenior Unsecured NotesSeptember, 20254.40%2031$500
Proceeds were used to refinance existing debt, including the repayment of the remaining $650 million aggregate principal amount of JCP&L’s 4.30% senior notes due 2026, to finance capital expenditures, and for other general corporate purposes.
JCP&LSenior Unsecured NotesSeptember, 20255.15%2036$500
Proceeds were used to refinance existing debt, including the repayment of the remaining $650 million aggregate principal amount of JCP&L’s 4.30% senior notes due 2026, to finance capital expenditures, and for other general corporate purposes.
(1) Excludes principal payments on securitized bonds.

FE Convertible Notes Issuance

On May 4, 2023, FE issued $1.5 billion aggregate principal amount of 2026 Convertible Notes, with a fixed interest rate of 4.00% per year, payable semiannually in arrears on May 1 and November 1 of each year, beginning on November 1, 2023. The 2026 Convertible Notes are unsecured and unsubordinated obligations of FE, and will mature on May 1, 2026, unless required to be converted or repurchased in accordance with their terms. FE may not elect to redeem the 2026 Convertible Notes prior to the maturity date. The 2026 Convertible Notes are included within “Long-term debt and other long-term obligations” on the FirstEnergy Consolidated Balance Sheets. Proceeds from the issuance were approximately $1.48 billion, net of issuance costs.
Through the close of business on the second scheduled trading day immediately preceding the maturity date, holders of the 2026 Convertible Notes may convert all or any portion of their 2026 Convertible Notes at their option at any time at the conversion rate then in effect. FE will settle conversions of the 2026 Convertible Notes, if any, by paying cash for the aggregate principal amount of the 2026 Convertible Notes being converted and its conversion obligation in excess of such aggregate principal amount.

The amount of consideration that a holder will receive upon conversion will be determined by reference to the volume-weighted average price of FE’s common stock for each trading day in a 40 trading day observation period. For any conversions on or after February 1, 2026, this period would be the 40 consecutive trading days beginning on, and including, the 41st scheduled trading day immediately preceding the maturity date.

On June 12, 2025, FE issued $1.35 billion aggregate principal amount of its 2029 Convertible Notes and $1.15 billion aggregate principal amount of its 2031 Convertible Notes.

The 2029 Convertible Notes and 2031 Convertible Notes bear interest at a rate of 3.625% per year and 3.875% per year, respectively, payable semiannually in arrears on January 15 and July 15 of each year, beginning on January 15, 2026. The 2029 Convertible Notes and 2031 Convertible Notes are unsecured and unsubordinated obligations of FE and will mature on January 15, 2029 and January 15, 2031, respectively, unless earlier converted or repurchased in accordance with their terms.

The notes are included within “Long-term debt and other long-term obligations” on the FirstEnergy Consolidated Balance Sheets. Proceeds from the issuance were approximately $2.47 billion, net of issuance costs.

Holders may convert notes at their option at any time prior to the close of business on the business day immediately preceding: (i) October 15, 2028, with respect to the 2029 Convertible Notes, and (ii) October 15, 2030, with respect to the 2031 Convertible Notes, only under certain conditions:

•During any calendar quarter, if the last reported sale price of FE’s common stock for at least 20 trading days during the period of 30 consecutive trading days ending on, and including, the last trading day of the immediately preceding calendar quarter is greater than or equal to 130% of the conversion price on each applicable trading day;
•During the five consecutive business day period immediately after any 10 consecutive trading day period in which the trading price per $1,000 principal amount of the 2029 Convertible Notes and 2031 Convertible Notes for each trading day of such 10 trading-day period was less than 98% of the product of the last reported sale price of FE’s common stock and the conversion rate on each such trading day; or
•Upon the occurrence of certain corporate events specified in the indenture governing the 2029 Convertible Notes and 2031 Convertible Notes.

On or after October 15, 2028, in the case of the 2029 Convertible Notes, and on or after October 15, 2030, in the case of the 2031 Convertible Notes, until the close of business on the second scheduled trading day immediately preceding the maturity date of the relevant series of notes, holders may convert all or any portion of their notes of such series at any time, regardless of the foregoing conditions. FE will settle conversions of such notes by paying cash up to the aggregate principal amount of the notes to be converted and paying or delivering, as the case may be, cash, shares of its common stock or a combination of cash and shares of its common stock, at its election, in respect of the remainder, if any, of its conversion obligation in excess of the aggregate principal amount of the notes being converted, subject to the applicable terms of the indentures.

The conversion rate for each of the series of notes will initially be 20.9275 shares of FE’s common stock per $1,000 principal amount of such notes (equivalent to an initial conversion price of approximately $47.78 per share of FE’s common stock). The initial conversion price of such notes represents a premium of approximately 20% over the last reported sale price of FE’s common stock on the New York Stock Exchange on June 9, 2025. The conversion rate and the corresponding conversion price will be subject to adjustment in some events but will not be adjusted for any accrued and unpaid interest. In addition, following certain corporate events that occur prior to the maturity date with respect to a series of notes (and, in the case of the 2031 Convertible Notes, if FE delivers a notice of redemption with respect to the 2031 Convertible Notes), FE will, in certain circumstances, increase the conversion rate for a holder who elects to convert its notes of such series in connection with such corporate event or redemption as applicable.

FE may not redeem the 2029 Convertible Notes prior to the maturity date of the 2029 Convertible Notes. On or after January 15, 2029 and prior to the 40th trading day immediately before the maturity date of the 2031 Convertible Notes, FE may redeem for cash all or any of the portion of the 2031 Convertible Notes, subject to certain partial redemption limitations and only under certain conditions.

If FE undergoes a fundamental change (as defined in the relevant indenture), subject to certain conditions, holders of the 2026 Convertible Notes, 2029 Convertible Notes and/or 2031 Convertible Notes may require FE to repurchase for cash all or any portion of their notes at a repurchase price equal to 100% of the principal amount of the convertible notes to be repurchased, plus accrued and unpaid interest to, but excluding, the fundamental change repurchase date (as defined in the relevant indenture). In addition, following certain corporate events that occur prior to the maturity date with respect to a series of convertible notes (and, in the case of the 2031 Convertible Notes, if FE delivers a notice of redemption with respect to the 2031
Convertible Notes), FE will, in certain circumstances, increase the conversion rate for a holder who elects to convert its notes of such series in connection with such corporate event or redemption, as applicable.

Separate from the issuance of the 2029 Convertible Notes and 2031 Convertible Notes, FE repurchased approximately $1.2 billion aggregate principal amount of the 2026 Convertible Notes, using a portion of the proceeds from the offering of the 2029 Convertible Notes and 2031 Convertible Notes described above. FE may, in the future, effect additional repurchases of remaining outstanding 2026 Convertible Notes.

FET Senior Notes and Registration Rights

On August 13, 2025, FET issued $450 million of senior unsecured notes due in 2033, in a private offering that included a registration rights agreement in which FET agreed to conduct an exchange offer of these senior notes for the like principal amounts registered under the Securities Act within 366 days of closing of the offering. On November 4, 2025, FET filed a registration statement on Form S-4 for the exchange offer with the SEC, which was declared effective on December 3, 2025. On January 21, 2026, FET completed the exchange offer of these senior notes for like principal amounts registered under the Securities Act.

JCP&L Senior Notes and Registration Rights

On December 5, 2024, JCP&L issued $700 million of senior unsecured notes due in 2035 in a private offering that included a registration rights agreement in which JCP&L agreed to conduct an exchange offer of these senior notes for like principal amounts registered under the Securities Act. On April 1, 2025, JCP&L filed a registration statement on Form S-4 with the SEC, which became effective on April 11, 2025.

On September 4, 2025, JCP&L issued: (i) $350 million of senior unsecured notes due in 2029; (ii) $500 million of senior unsecured notes due in 2031; and (iii) $500 million of senior unsecured notes due in 2036, in a private offering that included a registration rights agreement in which JCP&L agreed to conduct an exchange offer of these senior notes for the like principal amounts registered under the Securities Act within 366 days of closing of the offering.

Scheduled Debt Repayments

The following table presents scheduled debt repayments or debt that has been noticed for redemption for outstanding long-term debt, excluding finance leases, fair value purchase accounting adjustments and unamortized debt discounts and premiums, for the next five years as of December 31, 2025.

FirstEnergy (In millions)
20262027202820292030
Scheduled debt repayments $720$2,003$2,453$3,064$2,456

JCP&L (In millions)20262027202820292030
Scheduled debt repayments $—$—$—$350$—

Securitized Bonds

Environmental Control Bonds

The consolidated financial statements of FirstEnergy include environmental control bonds issued by two bankruptcy remote, special purpose limited liability companies that are indirect subsidiaries of MP and PE. Proceeds from the bonds were used to construct environmental control facilities. Principal and interest owed on the environmental control bonds is secured by, and payable solely from, the proceeds of the environmental control charges. Creditors of FirstEnergy, other than the limited liability company SPEs, have no recourse to any assets or revenues of the special purpose limited liability companies. As of December 31, 2025 and 2024, $156 million and $188 million of environmental control bonds were outstanding, respectively.

Phase-In Recovery Bonds

In June 2013, the SPEs formed by the Ohio Companies issued approximately $445 million of pass-through trust certificates supported by phase-in recovery bonds to securitize the recovery of certain all-electric customer heating discounts, fuel and purchased power regulatory assets. The phase-in recovery bonds are payable only from, and secured by, phase in recovery property owned by the SPEs. The bondholder has no recourse to the general credit of FirstEnergy or any of the Ohio Companies. Each of the Ohio Companies, as servicer of its respective SPE, manages and administers the phase in recovery property including the billing, collection and remittance of usage-based charges payable by retail electric customers. The SPEs are considered VIEs and each one is consolidated into its applicable utility. As of December 31, 2025 and 2024, $159 million and $175 million of the phase-in recovery bonds were outstanding, respectively.
FMBs

The Ohio Companies, FE PA, MP and PE each have a first mortgage indenture under which they can issue FMBs secured by a direct first mortgage lien on substantially all of their property and franchises, other than specifically excepted property. The outstanding debt under the FMBs of specific FE PA predecessors (WP and Penn) were assumed by FE PA.

Debt Covenant Default Provisions

FirstEnergy has various debt covenants under certain financing arrangements, including its revolving credit facilities and term loans. The most restrictive of the debt covenants relate to the nonpayment of interest and/or principal on such debt and the maintenance of certain financial ratios. The failure by FirstEnergy to comply with the covenants contained in its financing arrangements could result in an event of default, which may have an adverse effect on its financial condition. As of December 31, 2025, FirstEnergy remains in compliance with all debt covenant provisions.

Additionally, there are cross-default provisions in a number of the financing arrangements. These provisions generally trigger a default in the applicable financing arrangement of an entity if it, or any of its significant subsidiaries, default under another financing arrangement in excess of a certain principal amount, typically $100 million. Such defaults by any of the Electric Companies or Transmission Companies would cross-default certain FE financing arrangements containing these provisions, and a certain FET Financing arrangement, with respect to the Transmission Companies only. Such defaults by AE Supply would not cross-default to applicable financing arrangements of FE. Also, defaults by FE would generally not cross-default applicable financing arrangements of any of FE’s subsidiaries. Cross-default provisions are not typically found in any of the senior notes or FMBs of FE or its subsidiaries.
v3.25.4
SHORT-TERM BORROWINGS AND BANK LINES OF CREDIT
 12 Months Ended
Dec. 31, 2025
Debt Disclosure [Abstract]  
SHORT-TERM BORROWINGS AND BANK LINES OF CREDIT SHORT-TERM BORROWINGS AND BANK LINES OF CREDIT
The disclosures in this note apply to both Registrants, unless indicated otherwise.

FirstEnergy had $325 million and $550 million of outstanding short-term borrowings as of December 31, 2025 and 2024, respectively.

JCP&L had $93 million and $22 million of outstanding short-term borrowings as of December 31, 2025 and 2024, respectively.

On October 27, 2025, FE, the Electric Companies, Transmission Companies and FET, each entered into an amended credit facility to, among other things: (i) remove the 10 basis point credit spread adjustment from the interest rate calculation; (ii) permit a one-week interest period for any Term Benchmark Advance (as defined under each of the Amended Credit Facilities) based upon daily simple SOFR; and (iii) extend the maturity date of each credit facility for an additional one-year period (a) from October 20, 2028 to October 20, 2029 for the KATCo credit facility, (b) from October 20, 2029 to October 20, 2030 for the FET credit facility and (c) from October 18, 2028 to October 18, 2029 for the remaining Amended Credit Facilities.

As of December 31, 2025, available liquidity under the Credit Facilities totaled approximately $5.6 billion. JCP&L's available liquidity under its credit facility as of December 31, 2025 was $750 million.

Borrowings under each of the Amended Credit Facilities may be used for working capital and other general corporate purposes. Generally, borrowings under each of the credit facilities are available to each borrower separately and mature on the earlier of 364 days from the date of borrowing or the commitment termination date, as the same may be extended. Each of the Amended Credit Facilities contain financial covenants requiring each borrower, with the exception of FE, to maintain a consolidated debt-to-total-capitalization ratio (as defined under each of the Amended Credit Facilities) of no more than 65%, and 75% for FET, measured at the end of each fiscal quarter. FE is required under its credit facility to maintain a consolidated interest coverage ratio of not less than 2.50 times, measured at the end of each fiscal quarter for the last four fiscal quarters.

Subject to each borrower’s sublimit, certain amounts are available for the issuance of LOCs (subject to borrowings drawn under the Amended Credit Facilities) expiring up to one year from the date of issuance. The stated amount of outstanding LOCs will count against total commitments available under each of the Amended Credit Facilities and against the applicable borrower’s borrowing sublimit. As of December 31, 2025, FirstEnergy had $185 million in outstanding LOCs, $52 million of which are issued under the Amended Credit Facilities.

Each of the Amended Credit Facilities do not contain provisions that restrict the ability to borrow or accelerate payment of outstanding advances in the event of any change in credit ratings of the borrowers. Pricing is defined in “pricing grids,” whereby the cost of funds borrowed under the Amended Credit Facilities are related to the credit ratings of the company borrowing the funds. Additionally, borrowings under each of the credit facilities are subject to the usual and customary provisions for acceleration upon the occurrence of events of default, including a cross-default for other indebtedness in excess of $100 million.

As of December 31, 2025, FE was in compliance with its applicable consolidated interest coverage ratio and the Electric Companies, the Transmission Companies, and FET were each in compliance with their debt-to-total-capitalization ratio covenants under each of their Amended Credit Facilities.
FirstEnergy Money Pools

FirstEnergy’s regulated operating subsidiary companies also have the ability to borrow from each other and FE to meet their short-term working capital requirements. Effective September 23, 2024, AGC and KATCo became participants in the regulated companies’ money pool. Similar but separate arrangements exist among FirstEnergy’s unregulated companies with AE Supply, FE, FET, FEV and certain other unregulated subsidiaries. As of June 1, 2024, FET no longer participates in the unregulated money pool. FESC administers these money pools and tracks surplus funds of FE and the respective regulated and unregulated subsidiaries, as the case may be, as well as proceeds available from bank borrowings. Companies receiving a loan under the money pool agreements must repay the principal amount of the loan, together with accrued interest, within 364 days of borrowing the funds. The rate of interest is the same for each company receiving a loan from their respective pool and is based on the average cost of funds available through the pool.

Average Interest RatesRegulated Companies’ Money PoolUnregulated Companies’ Money Pool
2025202420252024
For the Years Ended December 31, 4.51 %5.74 %4.89 %6.44 %

Weighted Average Interest Rates

FirstEnergy - The annual weighted average interest rates on short-term borrowings through the years ended December 31, 2025 and 2024 were 5.72% and 7.10%, respectively.

JCP&L - The annual weighted average interest rates on short-term borrowings through the years ended December 31, 2025 and 2024 were 7.58% and 6.76%, respectively.
v3.25.4
REGULATORY MATTERS
 12 Months Ended
Dec. 31, 2025
Regulated Operations [Abstract]  
REGULATORY MATTERS REGULATORY MATTERS
The disclosures in this note apply to FirstEnergy, with the disclosures under “State Regulation”, “New Jersey”, “FERC Regulatory Matters”, “FERC Audit”, “Transmission ROE Methodology”, “Transmission Rate Incentives”, “Transmission Planning Supplemental Projects”, and “Local Transmission Planning Complaint” also applicable to JCP&L.

STATE REGULATION

Each of the Electric Companies retail rates, conditions of service, issuance of securities and other matters are subject to regulation in the states in which it operates - in Maryland by the MDPSC, in New Jersey by the NJBPU, in Ohio by the PUCO, in Pennsylvania by the PPUC, in West Virginia by the WVPSC and in New York by the NYPSC. The transmission operations of PE and TrAIL in Virginia, ATSI in Ohio, the Transmission Companies in Pennsylvania, PE and MP in West Virginia, and PE in Maryland are subject to certain regulations of the VSCC, PUCO, PPUC, WVPSC, and MDPSC, respectively. In addition, under Ohio law, municipalities may regulate rates of a public utility, subject to appeal to the PUCO if not acceptable to the utility. Further, if any of the FirstEnergy affiliates were to engage in the construction of significant new transmission facilities, depending on the state, they may be required to obtain state regulatory authorization to site, construct and operate the new transmission facility.
The following table summarizes the key terms of state base rate orders in effect for the Electric Companies as of December 31, 2025:
CompanyRates Effective For CustomersAllowed Debt/Equity Capital StructureAllowed ROE
CEI (1)
May 2009
51%/ 49%
10.5%
FE PA
January 2025
Settled(2)
Settled(2)
MPMarch 2024
Settled(2)
9.8%
JCP&LJune 2024
48.1% / 51.9%
9.6%
OE (1)
January 2009
51% /49%
10.5%
PE (West Virginia)March 2024
Settled(2)
9.8%
PE (Maryland)October 2023
47% / 53%
9.5%
TE (1)
January 2009
51% / 49%
10.5%
(1) On November 19, 2025, the PUCO issued an order in the Ohio Companies’ base rate case that authorized a capital structure of 48.8% debt and 51.2% equity, and an ROE of 9.63%. New rates reflecting this order were not yet in effect as of December 31, 2025.
(2) Commission-approved settlement agreements did not disclose allowed debt/equity and/or ROE rates.

MARYLAND

PE operates under MDPSC-approved distribution base rates that were effective as of October 19, 2023, and that were subsequently modified by an MDPSC order dated January 3, 2024, which became effective as of March 1, 2024. PE also provides SOS pursuant to a combination of settlement agreements, MDPSC orders and regulations, and statutory provisions. SOS supply is competitively procured in the form of rolling contracts of varying lengths through periodic auctions that are overseen by the MDPSC and a third-party monitor. Although settlements with respect to SOS supply for PE customers have expired, service continues in the same manner until changed by order of the MDPSC. PE recovers its costs plus a return for providing SOS.

The EmPOWER Maryland program, following passage of the Climate Solutions Now Act of 2022, required annual incremental energy efficiency targets of 2% per year from 2022 through 2024, 2.25% per year in 2025 and 2026, and 2.5% per year in 2027 and thereafter. On August 1, 2023, PE filed its proposed plan for the 2024-2026 cycle as required by the MDPSC. Additionally, at the direction of the MDPSC, PE together with other Maryland utilities were required to address GHG reductions in addition to energy efficiency. In compliance with the MDPSC directive, PE submitted three scenarios with projected costs over a three-year cycle of $311 million, $354 million, and $510 million, respectively. On December 29, 2023, the MDPSC issued an order approving the $311 million scenario for most programs, with some modifications. On August 15, 2024, PE filed a revised plan for the remainder of the 2024-2026 cycle to comply with refined GHG reduction targets with a total budget of $314 million, which the MDPSC approved on December 27, 2024. PE recovers EmPOWER Maryland program costs with carrying costs on unamortized balances through an annually reconciled surcharge, with certain costs subject to recovery over a five-year amortization period. Lost distribution revenue attributable to energy efficiency or demand reduction is recovered only through base rates. Consistent with an MDPSC order dated December 29, 2022, phasing out the unamortized balances of EmPOWER Maryland investments, PE is required to expense 67% of its EmPOWER Maryland program costs in 2025, and 100% in 2026 and beyond. All previously unamortized costs for prior cycles are to be collected by the end of 2030, consistent with the 2024-2026 order issued on December 29, 2023. Legislation which took effect on July 1, 2024 is expected to reduce the carrying costs on the EmPOWER Maryland unamortized balances for PE by a total of $25 to $30 million over the period of 2024-2030. On July 31, 2024, the MDPSC issued an order implementing revised EmPOWER Maryland surcharge rates for PE in accordance with the new law, denying PE’s request for a hearing that sought to challenge certain portions of the law. On August 30, 2024, PE filed a petition seeking judicial review of its challenge to the law in the Circuit Court for Washington County, Maryland. On August 6, 2025, the Circuit Court for Washington County, Maryland issued an order granting PE’s petition, finding that the legislature may not change terms to apply retroactively to monies already expended. MDPSC and the Maryland Office of People’s Counsel have each appealed the decision. On November 14, 2025, the Appellate Court of Maryland issued an order denying the unopposed motion of the Attorney General of Maryland to Intervene without prejudice to the ability to file an amicus curiae brief, which the Attorney General filed on December 30, 2025. PE's response brief was filed on January 21, 2026.

NEW JERSEY

JCP&L operates under NJBPU approved rates that took effect as of February 15, 2024, and became effective for customers as of June 1, 2024. JCP&L provides BGS for retail customers who do not choose a third-party EGS and for customers of third-party EGSs that fail to provide the contracted service. All New Jersey EDCs participate in this competitive BGS procurement process and recover BGS costs directly from customers as a charge separate from base rates.

The settlement of the distribution rate case in 2020, provided among other things, that JCP&L would be subject to a management audit, which began in May 2021. On April 12, 2023, the NJBPU accepted the final management audit report for filing purposes and ordered that interested stakeholders file comments on the report by May 22, 2023, which deadline was extended until July
31, 2023. JCP&L and one other party filed comments on July 31, 2023. On July 16, 2025, the NJBPU issued its final order, directing 100 of the 105 recommendations be implemented, including certain modifications. JCP&L filed its implementation plan on September 22, 2025, and began quarterly progress reporting in October 2025.

On September 17, 2021, in connection with Mid-Atlantic Offshore Development, LLC, a transmission company jointly owned by Shell New Energies US LLC and EDF Renewables North America, JCP&L submitted a proposal to the NJBPU and PJM to build transmission infrastructure connecting offshore wind-generated electricity to the New Jersey power grid. On October 26, 2022, the JCP&L proposal was accepted, in part, in an order issued by NJBPU. The proposal, as accepted, included approximately $723 million in investments for JCP&L to both build new and upgrade existing transmission infrastructure. JCP&L’s proposal projects an investment ROE of 10.2% and includes the option for JCP&L to acquire up to a 20% equity stake in Mid-Atlantic Offshore Development, LLC. The resulting rates associated with the project are expected to be shared among the ratepayers of all New Jersey electric utilities. On April 17, 2023, JCP&L applied for the FERC “abandonment” transmission rates incentive, which would provide for recovery of 100% of the cancelled prudent project costs that are incurred after the incentive is approved, and 50% of the costs incurred prior to that date, in the event that some or all of the project is cancelled for reasons beyond JCP&L’s control. On August 21, 2023, FERC approved JCP&L’s application, effective August 22, 2023.

On October 31, 2023, offshore wind developer, Orsted, announced plans to cease development of two offshore wind projects in New Jersey—Ocean Wind 1 and 2—having a combined planned capacity of 2,248 MWs. On January 30, 2025, and February 25, 2025, Shell New Energies US LLC and EDF Renewables North America respectively announced that each was exiting its Atlantic Shores partnership to construct wind energy off the shore of New Jersey. On June 4, 2025, Atlantic Shores filed a petition with the NJBPU, requesting consent to terminate its 1.5 GW offshore wind project. These cancellations are not expected to directly affect JCP&L’s awarded projects.

On May 23, 2025, JCP&L filed with the NJBPU a motion seeking declaratory guidance in view of recent offshore wind developments, including a shift in federal energy policy toward more traditional energy resources. JCP&L requested that the NJBPU provide guidance either affirming the current project schedule or, alternatively, authorizing JCP&L to modify the schedule. On June 9, 2025, responses to JCP&L’s motion were filed with the NJBPU, including a cross-motion by the New Jersey Division of Rate Counsel to reopen the offshore wind transmission proceeding, which JCP&L opposed. JCP&L advised that it intended to comply with its contractual obligations to construct the transmission project, and that its motion was limited to seeking guidance on the construction milestones. On July 28, 2025, the New Jersey Division of Rate Counsel asked the NJBPU to take judicial notice of a recent NYPSC order terminating its offshore wind transmission infrastructure process in the interest of protecting ratepayers. On August 13, 2025, the NJBPU issued an order requesting that JCP&L delay expenditures of certain of the transmission investment planned by JCP&L for a 2.5-year period, and directing that JCP&L work with NJBPU staff and PJM to ensure alignment as to the work that is to be continued on the original timeline and the work that is to be delayed consistent with the order.

Consistent with the commitments made in its proposal to the NJBPU, JCP&L formally submitted in November 2023 the first part of its application to the DOE to finance a substantial portion of the project using low-interest rate loans available under the DOE’s Energy Infrastructure Reinvestment Program of the IRA of 2022. JCP&L submitted the second part of its two-part application on March 13, 2024, which was approved on May 17, 2024. The DOE Loan Program Office initiated a due diligence review of the application shortly thereafter. On January 16, 2025, the DOE announced a conditional commitment to JCP&L for a loan guarantee of up to approximately $716 million for the project. On August 20, 2025, the DOE terminated its conditional commitment to JCP&L due to the DOE’s determination that a condition precedent could not be satisfied.

On November 9, 2023, JCP&L filed a petition for approval of its EnergizeNJ with the NJBPU that would, among other things, support grid modernization, system resiliency and substation modernization in technologies designed to provide enhanced customer benefits. JCP&L proposes EnergizeNJ will be implemented over a five-year budget period with estimated costs of approximately $935 million over the deployment period, of which, $906 million is capital investments and $29 million is operating and maintenance expenses. Under the proposal, the capital costs of EnergizeNJ would be recovered through JCP&L’s base rates via annual and semi-annual base rate adjustment filings. The 2023 base rate case stipulation that was filed on February 2, 2024, necessitated amendments to the EnergizeNJ program. On February 14, 2024, the NJBPU approved the stipulated settlement between JCP&L and various parties, resolving JCP&L’s request for a distribution base rate increase. On February 27, 2024, as part of the stipulated settlement, JCP&L amended its pending EnergizeNJ petition following receipt of NJBPU approval of the base rate case settlement, to remove the high-priority circuits that are to be addressed in the first phase of its reliability improvement plan and to include the second phase of its reliability improvement plan that is expected to further address certain high-priority circuits that require additional upgrades. On April 10, 2025, JCP&L, joined by various parties, filed a stipulated settlement with the NJBPU resolving JCP&L’s amended EnergizeNJ petition, which the NJBPU approved on April 23, 2025. The settlement provides for total program costs of $339 million, including capital investments in JCP&L’s electric distribution system of approximately $203 million, $132 million of matching capital investment and approximately $4 million of O&M expense. Pursuant to the settlement, the program began on July 1, 2025, and will continue through December 31, 2028. JCP&L has agreed to file a base rate case no later than January 1, 2030.

In February 2025, the NJBPU certified the results of its annual basic generation service auctions through which New Jersey’s four EDCs – including JCP&L – satisfy their generation supply requirements for BGS customers for the period beginning June 1, 2025 through May 31, 2026. The certified results resulted in significant rate increases for New Jersey EDC customers and, by
order dated April 23, 2025, the NJBPU directed the four EDCs to submit proposals to mitigate the impact of the rate increases that affected residential customers beginning June 1, 2025. On May 7, 2025, JCP&L filed a petition in response to the April 2025 order, modeling four potential mitigation scenarios. On June 18, 2025, the NJBPU approved a stipulation that included JCP&L, NJBPU Staff and New Jersey Division of Rate Counsel, pursuant to which, among other things, JCP&L agreed to apply a temporary rate credit of $30.00 to each residential electric customer’s monthly bill in July and August 2025 that would be deferred in a regulatory asset and recovered with a charge of $10 applied to each residential bill from September 2025 through February 2026 to recover the amounts deferred, without carry charges, subject to a final reconciliation. As of December 31, 2025, JCP&L's regulatory asset associated with this temporary rate credit was approximately $20 million.

On August 13, 2025, the NJBPU issued an Order to Show Cause reviewing JCP&L’s 2024 Annual System Performance Report, which includes information regarding JCP&L’s systems level of electric service reliability performance during the prior calendar year. Failure to attain NJBPU’s minimum reliability levels may subject JCP&L to a penalty. The NJBPU order alleges JCP&L has failed to achieve minimum reliability levels for calendar years 2022, 2023, and 2024, and directed JCP&L to file an answer demonstrating why the NJBPU should not impose certain penalties upon JCP&L for such failure, which JCP&L filed on October 10, 2025. JCP&L is unable to predict the outcome or estimate the impact of this matter.

On January 14, 2026, the NJBPU issued an order authorizing JCP&L to modify its Lost Revenue Adjustment Mechanism rate rider in its tariff. The modification allows JCP&L to recover the revenue impact of sales losses of approximately $16 million (pre-tax) primarily resulting from the implementation of JCP&L’s Energy Efficiency and Conservation Plan during the one-year period from July 1, 2023, through June 30, 2024. The modification was effective February 1, 2026.

OHIO

Until the rates approved in the 2024 base rate case go into effect, the Ohio Companies will continue to operate under PUCO-approved base distribution rates that became effective in 2009. The Ohio Companies operated under ESP IV through May 31, 2024, which provided for the supply of power to non-shopping customers at a market-based price set through an auction process. From June 1, 2024, until January 31, 2025, the Ohio Companies operated under ESP V, as modified by the PUCO, and as further described below. On December 18, 2024, the PUCO approved the Ohio Companies’ notice to withdraw ESP V and approved the Ohio Companies’ proposal for returning to ESP IV, with modifications. ESP IV, as modified, continues the DCR rider, which supports continued investment related to the distribution system for the benefit of customers, with an annual revenue cap of $390 million. In addition, ESP IV, as modified, includes: (1) continuation of a base distribution rate freeze until ESP VI becomes effective or the Ohio Companies’ obtain the PUCO’s staff agreement; (2) a goal across FirstEnergy to reduce CO2 emissions by 90% below 2005 levels by 2045; and (3) contributions, totaling $6.39 million per year to: (a) fund energy conservation, economic development and job retention programs in the Ohio Companies’ service territories; and (b) establish fuel-funds in each of the Ohio Companies’ service territories to assist low-income customers.

On April 5, 2023, the Ohio Companies filed an application with the PUCO for approval of ESP V, for an eight-year term beginning June 1, 2024, and continuing through May 31, 2032. On May 15, 2024, the PUCO issued an order approving ESP V with modifications, which became effective June 1, 2024, and would have continued through May 31, 2029. ESP V, as modified by the PUCO, provided for, among other things, the continuation of existing riders related to purchased power, transmission and uncollectibles, the continuation of the DCR rider with proposed annual revenue cap increases until new base rates are established, the continuation of the AMI rider, and the addition of new riders for recovery of storm and vegetation management expenses. Many of the terms and conditions were to be reconsidered in the base rate case. The ESP V order additionally directed the Ohio Companies to file another base distribution rate case not later than May 31, 2028, contribute $32.5 million during the term of ESP V to fund low-income customer bill assistance programs and bill assistance for income-eligible senior citizens, and to develop an electric vehicle education program to assist customers in transitioning to electric vehicles which was recognized in the second quarter of 2024 within “Other operating expenses” at the Regulated Distribution segment and on FirstEnergy’s Consolidated Statements of Income. Due to the risks and uncertainty resulting from the Ohio Companies’ application for rehearing being denied by operation of law, on October 29, 2024, the Ohio Companies filed a notice of their intent to withdraw ESP V and proposed the terms under which they would resume operating under ESP IV. On December 18, 2024, the PUCO approved the Ohio Companies’ notice of withdrawal. Also on December 18, 2024, the PUCO approved the Ohio Companies’ proposal for returning to ESP IV, with modifications. Consistent with ESP IV, the PUCO authorized the Ohio Companies’ reinstatement of the DCR rider, with an annual revenue cap of $390 million, and denied the Ohio Companies’ request to continue ESP IV’s DCR rider revenue cap increases of $15 million per year. Additionally, the PUCO ordered that storm costs deferred under ESP V since June 1, 2024, remain on the Ohio Companies’ books and subject to review in a future case. The PUCO also denied the Ohio Companies’ request to lift the base rate freeze in ESP IV, permitting the Ohio Companies’ pending base rate case to continue, but prohibiting new rates from going into effect until either the effective date of ESP VI, or the staff agrees that the freeze be lifted and new rates be implemented. On January 22, 2025, the PUCO approved the Ohio Companies’ revised ESP IV tariffs, effective February 1, 2025, at which time the Ohio Companies resumed operating under ESP IV. On April 7, 2025, certain intervenors filed an appeal to the Supreme Court of Ohio challenging the Ohio Companies’ return to ESP IV. On May 22, 2025, the Ohio Supreme Court granted the Ohio Companies motion to intervene in the appeal. On July 7, 2025, OCC and NOAC filed their Appellants’ brief. Appellees, including the PUCO and the Ohio Companies, filed their briefs on August 26, 2025, to which OCC and NOAC replied on September 15, 2025.
On January 31, 2025, the Ohio Companies filed an application with the PUCO for ESP VI, for a term beginning on the date new base distribution rates from the pending base rate case go into effect, in an effort to align with the ongoing base distribution rate case, and continuing through May 31, 2028. ESP VI proposed to continue providing power to non-shopping customers at market-based prices set through an auction process, and proposed to continue riders supporting investment in the Ohio Companies’ distribution system, including Rider DCR with annual reliability performance-based revenue cap increases of $37 million to $43 million, and an AMI rider for recovery of approved grid modernization investments. ESP VI additionally proposed riders to support continued maintenance of the distribution system, including recovery of vegetation management and storm restoration operations and maintenance expenses. In addition, ESP VI proposed energy efficiency programs for low-income customers, and included a commitment to spend $6.5 million annually over the ESP VI term, without recovery from customers, on initiatives to assist low-income customers, as well as education and incentives to help ensure customers have good experiences with electric vehicles. On May 15, 2025, the Ohio Governor signed HB 15, which repealed the statute authorizing ESPs in Ohio, effective August 14, 2025. On December 17, 2025, the PUCO dismissed the Ohio Companies’ application for ESP VI due to the repeal of the ESP statute.

On March 14, 2025, as directed by the PUCO in its December 18, 2024, order approving the Ohio Companies’ revised ESP IV tariffs, the Ohio Companies filed with the PUCO a request to commence their statutorily required quadrennial review of ESP IV and establish a proposed schedule. On July 10, 2025, the Ohio Companies withdrew the request for the PUCO to establish a procedural schedule following the May 15, 2025 signing by the Ohio Governor of HB 15 ending the statutory mandate to conduct the quadrennial review, effective August 14, 2025. The OCC filed its response to the Ohio Companies’ notice of withdrawal on July 25, 2025, to which the Ohio Companies replied on August 1, 2025. The matter remains pending before the PUCO.

On May 31, 2024, the Ohio Companies filed their application for an increase in base distribution rates based on a 2024 calendar year test period. The Ohio Companies requested a net increase in base distribution revenues of approximately $94 million with a return on equity of 10.8% and capital structures of 44% debt and 56% equity for CEI, 46% debt and 54% equity for OE, and 45% debt and 55% equity for TE, which reflects a roll-in of current riders such as DCR and AMI. Key components of the base rate case filing included a proposal to change pension and OPEB recovery to the delayed recognition method and to implement a mechanism to establish a regulatory asset (or liability) to recover (or refund) net differences between the amount of pension and OPEB expense requested in the proceeding and the actual amount each year using this method. Additionally, the Ohio Companies requested recovery of certain incurred costs, including the impact of major storms, a program to convert streetlights to LEDs, and others. On June 14, 2024, the Ohio Companies filed supporting testimony and on July 31, 2024, filed an update with an adjusted net increase of base distribution revenues of approximately $190 million and incorporated matters in the rate case as directed by the PUCO’s ESP V order. On December 18, 2024, the PUCO issued an order approving the Ohio Companies’ withdrawal of ESP V. On January 22, 2025, the PUCO approved the Ohio Companies’ revised ESP IV tariffs, effective February 1, 2025, at which time the Ohio Companies resumed operating under ESP IV. On January 27, 2025, the Ohio Companies notified the PUCO of their intention to update their application for an increase in base distribution rates to remove ESP V related provisions from the base rate case. On November 19, 2025, the PUCO issued an order in the rate case lifting the rate freeze and approving a net increase in base distribution revenues of the Ohio Companies of approximately $34 million, with a return on equity of 9.63% and a hypothetical capital structure of 48.8% debt and 51.2% equity for all three Ohio Companies, which reflects a roll-in of current riders such as DCR and AMI. The PUCO authorized continuance of Rider DCR with a cap increase commensurate with capital investments through January 31, 2025, and approved the Ohio Companies’ proposal to change pension and OPEB recovery to the delayed recognition method. Additionally, the order authorizes recovery of certain deferred costs for storm restoration, operations and maintenance, and energy efficiency programs. As a result of the order, the Ohio Companies recognized a $352 million pre-tax impairment charge related to future recovery disallowances of certain previously capitalized amounts. On November 26, 2025, the Ohio Companies filed proposed compliance tariffs. On December 19, 2025, the Ohio Companies and other parties filed applications for rehearing and on December 29, 2025, the Ohio Companies filed a memorandum against intervenors’ applications for rehearing. On January 7, 2026, the PUCO issued an entry granting rehearing in order to determine whether its November 19, 2025 base rate case opinion and order should be affirmed, abrogated, or modified on rehearing. On January 9, 2026, the Ohio Companies filed an expedited motion for ruling on the proposed compliance tariffs and on February 4, 2026, PUCO staff issued a letter recommending that most of the Ohio Companies’ proposed compliance tariffs be approved. The Ohio Companies cannot predict the outcome of the rehearing, but do not expect material changes to the November 2025 order.

On May 16, 2022, May 15, 2023, and May 15, 2024, the Ohio Companies filed their SEET applications for determination of the existence of significantly excessive earnings under ESP IV for calendar years 2021, 2022, and 2023, respectively. On May 15, 2025, the Ohio Companies filed their SEET application for determination of the existence of significantly excessive earnings under ESPs IV and V for calendar year 2024. Each application demonstrated that each of the individual Ohio Companies did not have significantly excessive earnings. These matters remain pending before the PUCO.

In the fourth quarter of 2020, motions were filed with the PUCO requesting that the PUCO amend the Ohio Companies’ riders for collecting the OVEC-related charges required by HB 6 to provide for refunds in the event such provisions of HB 6 are repealed. Neither the Ohio Companies nor FE benefit from the OVEC-related charges the Ohio Companies collect. Instead, the Ohio Companies were further required by HB 6 to remit all the OVEC-related charges they collect to non-FE Ohio electric distribution utilities until August 14, 2025, at which time HB 15 became effective and the Ohio Companies stopped collecting OVEC-related charges. The Ohio Companies contested the motions, which are pending before the PUCO.
In 2020, the four proceedings below were opened by the PUCO relating to HB 6. The matters, described in full below, were resolved pursuant to the terms of an order issued by the PUCO on January 7, 2026. The order, which adopted without modification the terms of the stipulation and recommendation filed with the PUCO by the Ohio Companies and fourteen intervenors on December 19, 2026, vacated the approximately $250 million in monetary penalties assessed by the PUCO in its order issued on November 19, 2025. Instead, the January 7, 2026 PUCO order directed the Ohio Companies to pay their customers, among other things, restitution and refunds totaling approximately $275 million ($213 million after-tax), of which, $25 million is recorded in "Other current liabilities" and approximately $250 million is recorded within "Regulatory Liabilities" on FirstEnergy's Consolidated Balance Sheets. The refunds will be paid out over three billing cycles beginning in February 2026 and the matters are now resolved:

•On September 8, 2020, the OCC filed motions in the Ohio Companies’ corporate separation audit and DMR audit dockets, requesting the PUCO to open an investigation and management audit, hire an independent auditor, and require FirstEnergy to show it did not improperly use money collected from consumers or violate any utility regulatory laws, rules or orders in its activities regarding HB 6. On December 30, 2020, in response to the OCC's motion, the PUCO reopened the DMR audit docket, and directed PUCO staff to solicit a third-party auditor and conduct a full review of the DMR to ensure funds collected from customers through the DMR were only used for the purposes established in ESP IV. On June 2, 2021, the PUCO selected an auditor, and the auditor filed the final audit report on January 14, 2022, which made certain findings and recommendations. The report found that spending of DMR revenues was not required to be tracked, and that DMR revenues, like all rider revenues, are placed into the regulated money pool as a matter of routine, where the funds lose their identity. Therefore, the report could not suggest that DMR funds were used definitively for direct or indirect support for grid modernization. The report also concluded that there was no documented evidence that ties revenues from the DMR to lobbying for the passage of HB 6, but also could not rule out with certainty uses of DMR funds to support the passage of HB 6. The report further recommended that the regulated companies' money pool be audited more frequently and the Ohio Companies adopt formal dividend policies. Final comments and responses were filed by parties during the second quarter of 2022. The proceeding was stayed in its entirety, including discovery and motions, continuously at the request of the U.S. Attorney for the Southern District of Ohio beginning in August 2022 and was lifted on February 26, 2024. On February 26, 2024, the Attorney Examiner consolidated this proceeding with the expanded DCR rider audit proceeding described below and on November 22, 2024, the administrative law judge ordered that the bifurcated portion of the corporate separation audit, discussed further below, be consolidated with the already-consolidated DMR audit and expanded DCR rider audit proceeding. Evidentiary hearings were held between June 10, 2025, and June 27, 2025. Initial and reply briefs were filed by the parties on July 21, 2025, and August 4, 2025, respectively.

•On September 15, 2020, the PUCO opened a new proceeding to review the political and charitable spending by the Ohio Companies in support of HB 6 and the subsequent referendum effort, and directed the Ohio Companies to show cause, demonstrating that the costs of any political or charitable spending in support of HB 6, or the subsequent referendum effort, were not included, directly or indirectly, in any rates or charges paid by customers. The Ohio Companies initially filed a response stating that the costs of any political or charitable spending in support of HB 6, or the subsequent referendum effort, were not included, directly or indirectly, in any rates or charges paid by customers, but on August 6, 2021, filed a supplemental response explaining that, in light of the facts set forth in the DPA and the findings of the DCR rider audit report further discussed below, political or charitable spending in support of HB 6, or the subsequent referendum effort, affected pole attachment rates paid by approximately $15,000. On October 26, 2021, the OCC filed a motion requesting the PUCO to order an independent external audit to investigate FE’s political and charitable spending related to HB 6, and to appoint an independent review panel to retain and oversee the auditor. In November and December 2021, parties filed comments and reply comments regarding the Ohio Companies’ original and supplemental responses to the PUCO’s September 15, 2020, show cause directive. On May 4, 2022, the PUCO selected a third-party auditor to determine whether the show cause demonstration submitted by the Ohio Companies is sufficient to ensure that the cost of any political or charitable spending in support of HB 6 or the subsequent referendum effort was not included, directly or indirectly, in any rates or charges paid by ratepayers. The proceeding was stayed in its entirety, including discovery and motions, continuously at the request of the U.S. Attorney for the Southern District of Ohio beginning in August 2022 and the stay was lifted on February 26, 2024. On September 30, 2024, the third-party auditor’s report was filed. The audit examined 53 payments totaling approximately $75 million made in support of the passage of HB 6 and subsequent referendum efforts, and concluded that less than $5 million was allocated to the Ohio Companies. The audit report affirmed the Ohio Companies’ conclusion in its August 6, 2021 filing that a rate impact of less than $15,000 was charged to the Ohio Companies’ pole attachment customers associated with political and charitable spending in support of HB 6. On October 22, 2024, parties filed comments on the audit report, and on November 5, 2024, parties filed reply comments. On September 5, 2025, the administrative law judge set a procedural schedule, but stayed it on December 29, 2025.

•In connection with an ongoing audit of the Ohio Companies’ policies and procedures relating to the code of conduct rules between affiliates, on November 4, 2020, the PUCO initiated an additional corporate separation audit as a result of the FirstEnergy leadership transition announcement made on October 29, 2020, as further discussed below. The additional audit is to ensure compliance by the Ohio Companies and their affiliates with corporate
separation laws and the Ohio Companies’ corporate separation plan. The additional audit is for the period from November 2016 through October 2020. The final audit report was filed on September 13, 2021. The audit report makes no findings of major non-compliance with Ohio corporate separation requirements, minor non-compliance with eight requirements, and findings of compliance with 23 requirements. Parties filed comments and reply comments on the audit report. The proceeding was stayed in its entirety, including discovery and motions, continuously at the request of the U.S. Attorney for the Southern District of Ohio beginning in August 2022 and the stay was lifted on February 26, 2024. On September 10, 2024, the Ohio Companies filed testimony describing their compliance with Ohio corporate separation laws and the implementation of the recommendations made in the audit reports. On September 20, 2024, intervenors filed testimony recommending fines for alleged violations of the Ohio corporate separation requirements. Evidentiary hearings were held on October 9 and 10, 2024; the scope of the hearings excluded allegations involving activities related to the passage of HB 6 and the former PUCO chairman, which were later addressed in hearings held between June 10, 2025, and June 27, 2025, as further described below. Initial and reply briefs have been filed by the Ohio Companies, PUCO staff and the intervening parties.

•On September 3, 2024, the Ohio Companies filed an application to amend their corporate separation plan to incorporate certain recommendations from prior audit reports, which include, but are not limited to, improving controls for non-regulated competitive employees’ physical space and access to data, updating and implementing a process to annually review the cost allocation manual, developing state specific codes of conduct practices, and implementing additional training related to the cost allocation manual and the state codes of conduct. On October 23, 2024, the administrative law judge issued an entry suspending automatic approval of the amended corporate separation plan and establishing a procedural schedule.

•In connection with an ongoing annual audit of the Ohio Companies’ DCR rider for 2020, and as a result of disclosures in FirstEnergy’s Form 10-K for the year ended December 31, 2020 (filed on February 18, 2021), the PUCO expanded the scope of the audit on March 10, 2021, to include a review of certain transactions that were either improperly classified, misallocated, or lacked supporting documentation, and to determine whether funds collected from customers were used to pay the vendors, and if so, whether or not the funds associated with those payments should be returned to customers through the DCR rider or through an alternative proceeding. On August 3, 2021, the auditor filed its final report on this phase of the audit, and the parties submitted comments and reply comments on this audit report in October 2021. Additionally, on September 29, 2021, the PUCO expanded the scope of the audit in this proceeding to determine if the costs of the naming rights for FirstEnergy Stadium have been recovered from the Ohio Companies’ customers. On November 19, 2021, the auditor filed its final report, in which the auditor concluded that the FirstEnergy Stadium naming rights expenses were not recovered from Ohio customers. On December 15, 2021, the PUCO further expanded the scope of the audit to include an investigation into an apparent nondisclosure of a side agreement in the Ohio Companies’ ESP IV settlement proceedings, but stayed its expansion of the audit until otherwise ordered by the PUCO. The proceeding was stayed in its entirety, including discovery and motions, continuously at the request of the U.S. Attorney for the Southern District of Ohio beginning in August 2022 and the stay was lifted on February 26, 2024. On February 26, 2024, the Attorney Examiner consolidated this proceeding with the Rider DMR audit proceeding described above, and further lifted the stay of the portion of the investigation relating to an apparent nondisclosure of a side agreement. On November 22, 2024, the administrative law judge ordered that the bifurcated portion of the corporate separation audit be consolidated with the already-consolidated DMR audit and the expanded DCR rider audit proceeding. Evidentiary hearings were held between June 10, 2025, and June 27, 2025. Initial and reply briefs were filed by the parties on July 21, 2025, and August 4, 2025, respectively.

See Note 14., "Commitments, Guarantees and Contingencies,” of the Combined Notes to Financial Statements of the Registrants below for additional details on the government investigations and subsequent litigation surrounding the investigation of HB 6.

PENNSYLVANIA

FE PA has five rate districts in Pennsylvania – four that correspond to the territories previously serviced by ME, PN, Penn, and WP and one rate district that corresponds to WP’s service provided to The Pennsylvania State University. The rate districts created by the PA Consolidation will not reach full rate unity until the earlier of 2033 or the conclusion of three base rate cases filed after January 1, 2025. FE PA operates under rates approved by the PPUC, effective as of January 1, 2025. FE PA operates under a DSP through the May 31, 2027 delivery period, which provides for the competitive procurement of generation supply for customers who do not choose an alternative EGS or for customers of alternative EGSs that fail to provide the contracted service.

Pursuant to Pennsylvania Act 129 of 2008 and PPUC orders, the Pennsylvania Companies implemented energy efficiency and peak demand reduction programs with demand reduction targets, relative to 2007-2008 peak demands, at 2.9% MW for ME, 3.3% MW for PN, 2.0% MW for Penn, and 2.5% MW for WP; and energy consumption reduction targets, as a percentage of the Pennsylvania Companies’ historic 2009 to 2010 reference load at 3.1% MWh for ME, 3.0% MWh for PN, 2.7% MWh for Penn, and 2.4% MWh for WP. The fourth phase of FE PA’s energy efficiency and peak demand reduction program, which runs for the five-year period beginning June 1, 2021 through May 31, 2026, was approved by the PPUC on June 18, 2020, providing cost
recovery of approximately $390 million to be recovered through Energy Efficiency and Conservation Phase IV Riders for each FE PA rate district.

On November 26, 2025, FE PA submitted a petition for approval of its Phase V Energy Efficiency and Conservation Plan, which includes energy efficiency and peak demand reduction programs with demand reduction targets, relative to 2007-2008 peak demands, at 2.01% MW, and energy consumption reduction targets, as a percentage of FE PA’s historic 2009 to 2010 reference load, at 2.00% MWh. The proposed plan includes cost recovery of approximately $390 million to be recovered through its Phase V Energy Efficiency and Conservation Charge Rider and runs for a five-year period beginning June 1, 2026, through May 31, 2031. Hearings were held on January 29, 2026. The parties have reached a full settlement in principle and expect to file with the PPUC a Joint Petition for Complete Settlement on or before February 19, 2026. An order is expected from the PPUC in the first quarter of 2026.

On February 3, 2026, FE PA filed a proposed DSP for provision of generation for the June 1, 2027 through May 31, 2031 delivery period, to be sourced through competitive procurements for customers who do not receive service from an alternative EGS. Under the 2027-2031 DSP, supply would be provided through a mix of 12, 24, and in the case of residential customers, 60-month energy contracts, as well as spot market purchases for industrial customers. A final order is expected from the PPUC by November 2026.

WEST VIRGINIA

MP and PE provide electric service to all customers through traditional cost-based, regulated utility ratemaking and operate under WVPSC-approved rates that became effective March 27, 2024. MP and PE recover net power supply costs, including fuel costs, purchased power costs and related expenses, net of related market sales revenue through the ENEC. MP’s and PE’s ENEC rate is typically updated annually and MP and PE filed their ENEC filing on August 29, 2025, for rates effective January 1, 2026.

On April 21, 2022, the WVPSC issued an order approving, effective May 1, 2022, a tariff to offer solar power on a voluntary basis to West Virginia customers and requiring MP and PE to subscribe at least 85% of the planned 50 MWs of solar generation before seeking approval for surcharge cost recovery. MP and PE must seek separate approval from the WVPSC to recover any solar generation costs in excess of the approved solar power tariff. On April 24, 2023, MP and PE sought approval for surcharge cost recovery from the WVPSC for three of the five solar sites, representing 30 MWs of generation. On August 23, 2023, the WVPSC approved the customer surcharge and granted approval to construct three of the five solar sites. The surcharge went into effect January 1, 2024. Two of the five solar generation sites went into service in 2024, with the third in April 2025. On December 4, 2024, MP and PE submitted for approval a settlement agreement to increase its solar surcharge rate. The WVPSC approved the settlement without modification on December 27, 2024, and new rates went into effect on January 1, 2025. In November 2025, MP and PE submitted a settlement agreement to the WVPSC seeking approval to adjust the solar surcharge rate, which was approved without modification on January 15, 2026. Pursuant to the settlement agreement, a modest decrease in the solar surcharge rate became effective January 15, 2026.

On August 29, 2025, MP and PE filed with the WVPSC their annual ENEC case requesting an increase in ENEC rates by approximately $14 million, proposed to be effective January 1, 2026, which represents a 0.8% increase of total revenues. The proposed increase is driven primarily by an under-recovery balance as of June 30, 2025, and higher costs for fuel and reagents. On December 12, 2025, the parties filed a settlement agreement with the WVPSC, which was approved in full without modification on December 23, 2025.

On August 29, 2025, MP and PE filed with the WVPSC their biennial review of their vegetation management program and surcharge. MP and PE have proposed an approximate $3.2 million decrease in the surcharge rates due to an over-recovery balance as of June 30, 2025, and higher costs for fuel and reagents. The WVPSC held a hearing regarding rate matters on December 15, 2025. An order from the WVPSC is expected by the end of first quarter 2026.

On October 1, 2025, MP and PE filed their integrated resource plan with the WVPSC. To ensure that MP and PE can meet their PJM adequacy requirements, the plan proposes, among other things, near-term market capacity purchases, and the addition of 70 MWs of solar generation by 2028 and 1,200 MWs of natural gas combined cycle generation by 2031. On November 26, 2025, the WVPSC issued a procedural order setting a hearing in May 2026.

On February 13, 2026, MP and PE filed a CPCN to construct and operate a 1,200 MW combined cycle gas turbine plant and 70 MWs of solar generation capacity for an estimated capital investment totaling approximately $2.7 billion as of the date of the filing. The request also includes a surcharge designed to recover financing costs during development and construction of the projects, as well as to transition to recovery in base rates once the projects are placed in-service and approved through a base rate case. An order is expected from the WVPSC in the second half of 2026. See Note 14, "Commitments, Guarantees and Contingencies - Environmental Matters - Clean Water Act,” of the Combined Notes to Financial Statements of the Registrants for additional details on the EPA's ELG.
FERC REGULATORY MATTERS

Under the Federal Power Act, FERC regulates rates for interstate wholesale sales and transmission of electric power, regulatory accounting and reporting under the Uniform System of Accounts, and other matters, including construction and operation of hydroelectric projects. With respect to their wholesale services and rates, the Electric Companies, AE Supply and the Transmission Companies are subject to regulation by FERC. FERC regulations require JCP&L, MP, PE and the Transmission Companies to provide open access transmission service at FERC-approved rates, terms and conditions. Transmission facilities of JCP&L, MP, PE and the Transmission Companies are subject to functional control by PJM and transmission service using their transmission facilities is provided by PJM under the PJM Tariff.

The following table summarizes the key terms of FERC rate orders in effect for transmission customer billings for FirstEnergy's transmission owner entities as of December 31, 2025:
CompanyAllowed Debt/Equity Capital StructureAllowed ROE
ATSIActual (13-month average)
9.88%(1)
JCP&L
Actual (13-month average)10.2%
MP
Lower of Actual (13-month average) or 56% equity
10.45%
PE
Lower of Actual (13-month average) or 56% equity
10.45%
KATCo(2)
49.3% equity(3)
10.45%
MAIT
Lower of Actual (13-month average) or 60% equity
10.3%
TrAILActual (year-end)
12.7%(4) / 11.7%(5)
(1) Reflects a 0.5% reduction to the 10.38% approved ROE due to the January 2025 Sixth Circuit ruling eliminating the 50 basis point adder associated with RTO membership (see Transmission ROE Incentive).
(2) On January 1, 2024, WP transferred certain of its Pennsylvania-based transmission assets to KATCo.
(3) Capital structure will convert to an actual (13-month average) in January 2027.
(4) TrAIL the Line and Black Oak Static Var Compensator.
(5) All other projects.

FERC regulates the sale of power for resale in interstate commerce in part by granting authority to public utilities to sell wholesale power at market-based rates upon showing that the seller cannot exert market power in generation or transmission or erect barriers to entry into markets. The Electric Companies and AE Supply each have the necessary authorization from FERC to sell their wholesale power, if any, in interstate commerce at market-based rates, although in the case of the Electric Companies major wholesale purchases remain subject to review and regulation by the relevant state commissions. The Electric Companies and AE Supply are required to renew their respective authorizations every three years, and on December 16, 2025, the companies filed applications for the next renewal period.

Federally enforceable mandatory reliability standards apply to the bulk electric system and impose certain operating, record-keeping and reporting requirements on the Electric Companies, AE Supply, and the Transmission Companies. NERC is the Electric Reliability Organization designated by FERC to establish and enforce these reliability standards, although NERC has delegated day-to-day implementation and enforcement of these reliability standards to six regional entities, including RFC. All of the facilities that FirstEnergy operates are located within the RFC region. FirstEnergy actively participates in the NERC and RFC stakeholder processes, and otherwise monitors and manages its companies in response to the ongoing development, implementation and enforcement of the reliability standards implemented and enforced by RFC.

FirstEnergy believes that it is in material compliance with all currently-effective and enforceable reliability standards. Nevertheless, in the course of operating its extensive electric utility systems and facilities, FirstEnergy occasionally learns of isolated facts or circumstances that could be interpreted as excursions from the reliability standards. If and when such occurrences are found, FirstEnergy develops information about the occurrence and develops a remedial response to the specific circumstances, including in appropriate cases “self-reporting” an occurrence to RFC. Moreover, it is clear that NERC, RFC and FERC will continue to refine existing reliability standards as well as to develop and adopt new reliability standards. Any inability on FirstEnergy’s part to comply with the reliability standards for its bulk electric system could result in the imposition of financial penalties, or obligations to upgrade or build transmission facilities, that could have a material adverse effect on its financial condition, results of operations, and cash flows.

FERC Audit

FERC’s Division of Audits and Accounting initiated a nonpublic audit of FESC in February 2019. Among other matters, the audit is evaluating FirstEnergy’s compliance with certain accounting and reporting requirements under various FERC regulations. On February 4, 2022, FERC filed the final audit report for the period of January 1, 2015, through September 30, 2021, which included several findings and recommendations that FirstEnergy has accepted. The audit report included a finding and related
recommendation on FirstEnergy’s methodology for allocation of certain corporate support costs to regulatory capital accounts under certain FERC regulations and reporting. Effective in the first quarter of 2022 and in response to the finding, FirstEnergy implemented a new methodology for the allocation of these corporate support costs to regulatory capital accounts for its regulated distribution and transmission companies on a prospective basis. With the assistance of an independent outside firm, FirstEnergy completed an analysis during the third quarter of 2022 of these costs and how it impacted certain FERC-jurisdictional wholesale transmission customer rates for the audit period of 2015 through 2021. As a result of this analysis, FirstEnergy reclassified certain transmission capital assets to operating expenses for the audit period. FirstEnergy fully recovered approximately $105 million ($13 million at JCP&L) of these costs reclassified to operating expenses in its transmission formula rate revenue requirements as of December 31, 2024.

On December 8, 2023, FERC audit staff issued a letter advising that two unresolved audit matters, related to FirstEnergy’s plan to recover the reclassified operating expenses in formula transmission rates and a since terminated fuel consulting contract, were being referred to other offices within FERC for further review. On July 5, 2024, and September 26, 2024, the FERC Office of Enforcement issued additional data requests related to the 2022 reclassification of operating expenses, to which FirstEnergy replied. On September 10, 2024, and January 13, 2025, the FERC Office of Enforcement issued further data requests related to the classification and recovery of a since terminated fuel consulting contract, to which FirstEnergy responded. The FERC Office of Enforcement took no action with respect to the referred matters, and on December 23, 2025, FERC staff notified FirstEnergy that the audit is concluded.

Transmission ROE Incentive

On February 24, 2022, the OCC filed a complaint with FERC against ATSI, AEP’s Ohio affiliate and American Electric Power Service Corporation, and Duke Energy Ohio, Inc. asserting that FERC should reduce the ROE utilized in the utilities’ transmission formula rates by eliminating the 50 basis point adder associated with RTO membership, effective February 24, 2022. The OCC contends that this result is required because Ohio law mandates that transmission owning utilities join an RTO and that the 50 basis point adder is applicable only where RTO membership is voluntary. On December 15, 2022, FERC denied the complaint as to ATSI and Duke Energy Ohio, Inc., but granted it as to AEP’s Ohio affiliate. AEP’s Ohio affiliate and OCC appealed FERC’s orders to the Sixth Circuit. On January 17, 2025, the Sixth Circuit ruled that the 50 basis point adder is available only where RTO membership is voluntary, that Ohio law requires Ohio’s transmission utilities to be members of an RTO, and that it was unlawful for FERC to excise the adder from AEP’s Ohio affiliate rates, but not from the Duke Energy Ohio, Inc. and ATSI rates. During 2024, as a result of the ruling, ATSI recognized a $46 million pre-tax charge, with interest, of which $42 million is reported in “Transmission Revenues” and $4 million is reported in “Miscellaneous income, net” on the FirstEnergy Consolidated Statements of Income at the Stand-Alone Transmission segment, to reflect the expected refund owed to transmission customers back to February 24, 2022. On June 20, 2025 and June 24, 2025, ATSI and AEP’s Ohio affiliate, respectively, applied for the Supreme Court of the U.S. to review the Sixth Circuit’s decision. On November 10, 2025, the Supreme Court of the U.S. denied ATSI’s petition for the court to review the case. On November 13, 2025, the Sixth Circuit issued a mandate sending the case back to FERC for further proceedings.

Transmission ROE Methodology

A proposed rulemaking proceeding concerning transmission rate incentives provisions of Section 219 of the 2005 Energy Policy Act was initiated in March of 2020 and remains pending before FERC. Among other things, the rulemaking explored whether utilities should collect an “RTO membership” ROE incentive adder for more than three years. FirstEnergy is a member of PJM, and its transmission subsidiaries could be affected by the proposed rulemaking. FirstEnergy participated in comments on the supplemental rulemaking that were submitted by a group of PJM transmission owners and by various industry trade groups. If there were to be any changes to FirstEnergy's transmission incentive ROE, such changes will be applied on a prospective basis; provided however, due to the Sixth Circuit’s ruling in the Transmission ROE Incentive matter described above, ATSI is collecting the ROE incentive adder subject to refund.

Transmission Planning Supplemental Projects

On September 27, 2023, the OCC filed a complaint against ATSI, PJM and other transmission utilities in Ohio alleging that the PJM Tariff and operating agreement are unjust, unreasonable, and unduly discriminatory because they include no provisions to ensure PJM’s review and approval for the planning, need, prudence and cost-effectiveness of the PJM Tariff Attachment M-3 “Supplemental Projects.” Supplemental Projects are projects that are planned and constructed to address local needs on the transmission system. The OCC demands that FERC: (i) require PJM to review supplemental projects for need, prudence and cost-effectiveness; (ii) appoint an independent transmission monitor to assist PJM in such review; and (iii) require that Supplemental Projects go into rate base only through a “stated rate” procedure whereby prior FERC approval would be needed for projects with costs that exceed an established threshold. Subsequently, intervenors expanded the scope of this proceeding to all of the transmission utilities in PJM, including JCP&L. ATSI and the other transmission utilities in Ohio and PJM filed comments.

Local Transmission Planning Complaint

On December 19, 2024, the Industrial Energy Consumers of America, a group representing large industrial customers, and state
consumer advocates filed a complaint at FERC that asserts that transmission owners are overbuilding “local transmission facilities” with corresponding unjustified increases in transmission rates. The complaint demands that FERC: (i) prohibit transmission owners from planning “local transmission facilities” that are rated at 100 kV or higher; (ii) appoint “independent transmission monitors” to conduct such planning; and (iii) condition construction of local transmission facilities on the facility having been planned by the “independent transmission monitor.” FirstEnergy is participating in this matter through a consortium of PJM transmission owners and through certain trade groups, including EEI. FirstEnergy, together with the PJM transmission owners, filed a motion to dismiss the complaint on March 20, 2025, which is pending before FERC. FirstEnergy is unable to predict the outcome or estimate the impact that this complaint may have on its Transmission Companies, however, whether this lawsuit moves forward could have a material impact on FirstEnergy and its transmission capital investment strategy.

Ghiorzi v. PJM

In December 2023, PJM assigned certain baseline RTEP projects to NextEra Energy Transmission, which subsequently informed PJM that it would not construct the projects. On April 3, 2025, following the reassignment by PJM of certain baseline RTEP projects in Maryland and Virginia to PE, two individuals filed a complaint at FERC challenging this outcome, which FERC denied on February 2, 2026. The complainants asserted that PJM erred in reassigning the work to PE because such reassignment projects: (i) did not reflect the cost estimates or cost caps included in NextEra Energy Transmission’s bid; and (ii) would be constructed with different routing than as originally proposed. FirstEnergy and PE are unable to predict the outcome or estimate the impact that this complaint may have.

Valley Link Formula Transmission Rate

On March 14, 2025, the Valley Link joint venture filed an application for forward-looking formula transmission rates to provide for cost recovery for the portfolio of selected projects. Among other things, the transmission rate application provides for a capital structure of 40% debt and 60% equity, and a base ROE of 10.9% with associated templates and protocols, as well as transmission rate incentives, including the abandonment rate incentive, the CWIP rate incentive, the RTO participation adder incentive, the hypothetical capital structure incentive, and the precommercial regulatory asset incentive. On May 14, 2025, FERC issued an initial order that, among other things, accepted the requested abandonment rate incentive, CWIP rate incentive, RTO participation adder incentive, and precommercial regulatory asset rate incentive, and allowed the formula rate to go into effect on May 13, 2025, as requested, subject to refund, pending further settlement and hearing proceedings. The most recent settlement conference was held on December 9, 2025, at which the parties agreed to a procedural schedule to govern the next phase of the settlement process. The capital structure incentive and the other open rate design matters are being addressed in the confidential settlement negotiations.

Abandonment Transmission Rate Incentive

On February 26, 2025, PJM completed its 2024 RTEP Open Window 1 process and, among other actions, designated each of ATSI and PE to construct certain transmission projects. On July 11, 2025, ATSI and PE filed a joint application for the abandonment incentive with FERC, which, was approved on September 9, 2025. Effective September 10, 2025, ATSI and PE each became eligible to recover 50% of the project costs incurred prior to September 10, 2025, and 100% of the project costs incurred thereafter for any projects subsequently cancelled for reasons beyond the control of utility management.

PJM Capacity Market Reforms

On January 16, 2026, the Trump administration and the governors of all thirteen PJM states released a Statement of Principles Regarding PJM. This Statement of Principles is designed to, among other things, increase capacity available in the PJM market. PJM is seeking input from its stakeholders on matters related to the Statement of Principles, including: (1) proposals for a backstop capacity auction, price (cap), term, and quantity; (2) on whether to extend the existing capacity auction price collar; and (3) accelerating large load interconnections bringing their own generation. FirstEnergy is participating in the stakeholder processes that are described in the Statement of Principles, including by submitting a letter on January 30, 2026, in response to PJM’s request for input on the question of whether to extend the existing capacity auction price collar. In the letter, FirstEnergy supported extending the price collar but noted that PJM may wish to lower costs to customers by lowering the price collar through administrative or other mechanisms.

Large Load Interconnection Rulemaking

On October 23, 2025, the U.S. Secretary of Energy directed FERC to conduct a rulemaking procedure to develop regulations that would speed interconnection to the transmission system of large loads, including “Artificial Intelligence” data centers and “hybrid” data center/electric generation facilities. The Energy Secretary advanced 14 principles to guide this outcome, including that such large loads should be responsible for paying the costs of any network transmission system upgrades required for interconnection of such large loads, and that these large loads should have the option for building such network transmission upgrades. The Energy Secretary requested that FERC take final action by April 30, 2026. On October 27, 2025, FERC noticed the Energy Secretary’s directive for comment, and subsequently established November 21, 2025 as the deadline for initial comments and December 5, 2025 as the deadline for reply comments. FET and its transmission affiliates, as well as over 150 other parties, filed comments on the established deadlines. FirstEnergy is unable to predict the outcome of this rulemaking
procedure. To the extent the new regulations do not permit transmission utilities to fully recover costs associated with transmission network upgrades required to serve new large loads, our strategy of investing in transmission could be adversely affected.
v3.25.4
COMMITMENTS, GUARANTEES AND CONTINGENCIES
 12 Months Ended
Dec. 31, 2025
Commitments and Contingencies Disclosure [Abstract]  
COMMITMENTS, GUARANTEES AND CONTINGENCIES COMMITMENTS, GUARANTEES AND CONTINGENCIES
The disclosures in this note apply to both Registrants, unless indicated otherwise.

FIRSTENERGY - GUARANTEES AND OTHER ASSURANCES

FirstEnergy has various financial and performance guarantees and indemnifications which are issued in the normal course of business. These contracts include performance guarantees, stand-by LOCs, debt guarantees, surety bonds and indemnifications. FirstEnergy enters into these arrangements to facilitate commercial transactions with third parties by enhancing the value of the transaction to the third party. The maximum potential amount of future payments FirstEnergy and its subsidiaries could be required to make under these guarantees as of December 31, 2025, was approximately $1.1 billion, as summarized below:
Guarantees and Other AssurancesMaximum Exposure
 (In millions)
FE's Guarantees on Behalf of its Consolidated Subsidiaries
Deferred compensation arrangements$395 
Vehicle leases75 
McElroy Run transfer129 
Other15 
 614 
FE's Guarantees on Other Assurances
Surety Bonds161 
Deferred compensation arrangements93 
LOCs185 
 439 
Total Guarantees and Other Assurances$1,053 

In 2025, FET, DominionHV and Transource issued an equity support agreement to enable Valley Link to enter into a credit facility with a third party. The equity support agreement expires once all Valley Link credit agreement obligations are satisfied or when FET has fulfilled its support obligations under the equity support agreement. As of December 31, 2025, the fair value of FET’s support obligations relating to the Valley Link credit facility was immaterial.

JCP&L - GUARANTEES AND OTHER ASSURANCES

JCP&L has various financial and performance guarantees and indemnifications which are issued in the normal course of business. These contracts include stand-by LOCs and surety bonds. JCP&L enters into these arrangements to facilitate commercial transactions with third parties by enhancing the value of the transaction to the third party. The maximum potential amount of future payments JCP&L could be required to make under these guarantees as of December 31, 2025, was $48 million, as summarized below:
Guarantees and Other AssurancesMaximum Exposure
 (In millions)
Guarantees on Other Assurances
Surety Bonds$20 
LOCs28 
Total Guarantees and Other Assurances$48 
FIRSTENERGY - COLLATERAL AND CONTINGENT-RELATED FEATURES

In the normal course of business, FE and its subsidiaries may enter into physical or financially settled contracts for the sale and purchase of electric capacity, energy, fuel and emission allowances. Certain agreements contain provisions that require FE or its subsidiaries to post collateral. This collateral may be posted in the form of cash or credit support with thresholds contingent upon FE's or its subsidiaries' credit rating from each of the major credit rating agencies. The collateral and credit support requirements vary by contract and by counterparty.

As of December 31, 2025, $185 million of collateral, in the form of LOCs, has been posted by FE or its subsidiaries. FE or its subsidiaries are holding $33 million of net cash collateral as of December 31, 2025, from certain generation suppliers, and such amount is included in "Other current liabilities" on FirstEnergy's Consolidated Balance Sheets.

These credit-risk-related contingent features stipulate that if the subsidiary were to be downgraded or lose its investment grade credit rating (based on its senior unsecured debt rating), it would be required to provide additional collateral. The following table discloses the potential additional credit rating contingent contractual collateral obligations as of December 31, 2025:
Potential Collateral ObligationsElectric Companies and Transmission CompaniesFETotal
(In millions)
Contractual Obligations for Additional Collateral
Upon Further Downgrade$99 $1 $100 
Surety Bonds (collateralized amount)(1)
113 153 266 
Total Exposure from Contractual Obligations$212 $154 $366 
(1) Surety Bonds are not tied to a credit rating. Surety Bonds' impact assumes maximum contractual obligations, which is ordinarily 100% of the face amount of the surety bond except with respect to $22 million of surety obligations for which the collateral obligation is capped at 60% of the face amount, and typical obligations require 30 days to cure.

JCP&L - COLLATERAL AND CONTINGENT-RELATED FEATURES

In the normal course of business, JCP&L may enter into physical or financially settled contracts for the sale and purchase of electric capacity, energy, fuel and emission allowances. Certain agreements contain provisions that require JCP&L to post collateral. This collateral may be posted in the form of cash or credit support with thresholds contingent upon JCP&L's credit rating from each of the major credit rating agencies. The collateral and credit support requirements vary by contract and by counterparty.

JCP&L has posted $28 million of collateral in the form of LOCs as of December 31, 2025. JCP&L is holding $2 million of net cash collateral as of December 31, 2025, from certain generation suppliers, and such amount is included in "Other current liabilities" on JCP&L's Balance Sheets.

These credit-risk-related contingent features stipulate that if JCP&L were to be downgraded or lose its investment grade credit rating (based on its senior unsecured debt rating), it would be required to provide additional collateral. The following table discloses the potential additional credit rating contingent contractual collateral obligations as of December 31, 2025:
Potential Collateral ObligationsJCP&L
(In millions)
Contractual Obligations for Additional Collateral
Upon Further Downgrade$67 
Surety Bonds (collateralized amount)(1)
20 
Total Exposure from Contractual Obligations$87 
(1) Surety Bonds are not tied to a credit rating. Surety Bonds' impact assumes maximum contractual obligations, which is ordinarily 100% of the face amount of the surety bond except with respect to $1 million of surety obligations for which the collateral obligation is capped at 60% of the face amount, and typical obligations require 30 days to cure.


ENVIRONMENTAL MATTERS

Various federal, state and local authorities regulate the Registrants with regard to air and water quality, hazardous and solid waste management and disposal, and other environmental matters. While the Registrants’ environmental policies and procedures are designed to achieve compliance with applicable environmental laws and regulations, such laws and regulations are subject to periodic review and potential revision by the implementing agencies. The Registrants cannot predict the timing or ultimate outcome of any of these reviews or how any future actions taken as a result thereof may materially impact their
business, results of operations, cash flows and financial condition. In general, environmental requirements applicable to the electric power sector are becoming increasingly prescriptive and stringent, and the EPA finalized a number of rules in 2024 that could impact the Registrants. However, the Trump administration has issued certain executive orders and stated its intention to rescind, revise or replace some existing environmental regulations and the ultimate impact of recently finalized rules, several of which are in litigation, and any replacement rules are uncertain.

On March 12, 2025, the EPA announced its intent to reevaluate or reconsider numerous environmental regulations, many of which apply to the Registrants. The specific timing or outcome of this initiative remains unknown, but regular required rulemaking processes and procedures still apply, and litigation is also anticipated to occur. The disclosures herein do not attempt to discern potential impacts of these deregulatory actions until and unless formal rulemaking or other regulatory actions are announced and the potential impacts to operations can be discerned.

The disclosures below apply to FirstEnergy and the disclosures under “Regulation of Waste Disposal,” are also applicable to JCP&L.

Clean Air Act

FirstEnergy complies with SO2 and NOx emission reduction requirements under the CAA and SIP by burning lower-sulfur fuel, utilizing combustion controls and post-combustion controls and/or using emission allowances.

CSAPR requires reductions of NOx and SO2 emissions in two phases (2015 and 2017), ultimately capping SO2 emissions in affected states to 2.4 million tons annually and NOx emissions to 1.2 million tons annually. CSAPR allows trading of NOx and SO2 emission allowances between electric generation facilities located in the same state and interstate trading of NOx and SO2 emission allowances with some restrictions. On July 28, 2015, the D.C. Circuit ordered the EPA to reconsider the CSAPR caps on NOx and SO2 emissions from electric generation facilities in 13 states, including West Virginia. This followed the 2014 Supreme Court of the U.S. ruling generally upholding the EPA’s regulatory approach under CSAPR but questioning whether the EPA required upwind states to reduce emissions by more than their contribution to air pollution in downwind states. The EPA issued a CSAPR Update on September 7, 2016, reducing summertime NOx emissions from electric generation facilities in 22 states in the eastern U.S., including West Virginia, beginning in 2017. Various states and other stakeholders appealed the CSAPR Update to the D.C. Circuit in November and December 2016. On September 13, 2019, the D.C. Circuit remanded the CSAPR Update to the EPA citing that the rule did not eliminate upwind states’ significant contributions to downwind states’ air quality attainment requirements within applicable attainment deadlines.

Also in March 2018, the State of New York filed a CAA Section 126 petition with the EPA alleging that NOx emissions from nine states (including West Virginia) significantly contribute to New York’s inability to attain the ozone National Ambient Air Quality Standards. The petition sought suitable emission rate limits for large stationary sources that are allegedly affecting New York’s air quality within the three years allowed by CAA Section 126. On September 20, 2019, the EPA denied New York’s CAA Section 126 petition. On October 29, 2019, the State of New York appealed the denial of its petition to the D.C. Circuit. On July 14, 2020, the D.C. Circuit reversed and remanded the New York petition to the EPA for further consideration. On March 15, 2021, the EPA issued a revised CSAPR Update that addressed, among other things, the remands of the prior CSAPR Update and the New York Section 126 petition. In December 2021, MP purchased NOx emissions allowances to comply with 2021 ozone season requirements. On April 6, 2022, the EPA published proposed rules seeking to impose further significant reductions in EGU NOx emissions in 25 upwind states, including West Virginia, with the stated purpose of allowing downwind states to attain or maintain compliance with the 2015 ozone National Ambient Air Quality Standards. On February 13, 2023, the EPA disapproved 21 SIPs, which was a prerequisite for the EPA to issue a final Good Neighbor Plan or FIP. On June 5, 2023, the EPA issued the final Good Neighbor Plan with an effective date 60 days thereafter. Certain states, including West Virginia, have appealed the disapprovals of their respective SIPs, and some of those states have obtained stays of those disapprovals precluding the Good Neighbor Plan from taking effect in those states. On August 10, 2023, the 4th Circuit granted West Virginia an interim stay of the disapproval of its SIP and on January 10, 2024, after a hearing held on October 27, 2023, granted a full stay which precludes the Good Neighbor Plan from going into effect in West Virginia. In addition to West Virginia, certain other states, and certain trade organizations, including the Midwest Ozone Group of which FE is a member, separately filed petitions for review and motions to stay the Good Neighbor Plan itself at the D.C. Circuit. On September 25, 2023, the D.C. Circuit denied the motions to stay the Good Neighbor Plan. On October 13, 2023, the aggrieved parties filed an Emergency Application for an Immediate Stay of the Good Neighbor Plan with the Supreme Court of the U.S. Oral argument was heard on February 21, 2024. On June 27, 2024, the Supreme Court of the U.S. granted a stay of the Good Neighbor Plan pending disposition of the petition for review in the D.C. Circuit. On February 6, 2025, the EPA filed a motion at the D.C. Circuit to hold the proceedings in abeyance for 60 days to allow the EPA time to familiarize itself with the Good Neighbor Plan and in particular, time to brief the new administration about these consolidated petitions and the underlying Rule to allow them to decide what action, if any, is necessary. On March 10, 2025, the EPA filed a motion for remand with the D.C. Circuit identifying issues with the Good Neighbor Plan that make reconsideration appropriate. The D.C. Circuit granted the motion for remand and cancelled oral argument. Consistent with its March 12, 2025 announcement, the EPA intends to undertake reconsideration of the rule and complete any new rulemaking by the fourth quarter of 2026. On January 27, 2026, the EPA proposed phase 1 of its reconsideration of the rule applicable to eight states outside of FirstEnergy’s service area. FirstEnergy will continue to monitor any further actions by the EPA for any potential impact to its business and results of operations.
Climate Change

In recent years, certain regulators in the U.S. have focused efforts on increasing disclosures by companies related to climate change and mitigation efforts. At the federal level, presidential administrations have held differing views on prioritizing actions to address GHG emissions and, by extension, climate change. Those differing views have led to policy changes, creating uncertainty about environmental requirements and associated impacts.

In December 2009, the EPA released its final “Endangerment and Cause or Contribute Findings for GHGs under the Clean Air Act,” known as the 2009 Endangerment Finding, concluding that concentrations of several key GHGs constitute an “endangerment” and may be regulated as “air pollutants” under the CAA and mandated measurement and reporting of GHG emissions from certain sources, including electric generation facilities. The 2009 Endangerment Finding is the basis of the EPA’s authority to regulate GHG emissions under the CAA.

In January 2025, Executive Order 14514 was issued and, among other deregulatory actions, directed the EPA Administrator to make recommendations on the “legality and continuing applicability” of the EPA’s 2009 Endangerment Finding, which forms the basis for the EPA's GHG regulations. On March 12, 2025, the EPA announced a series of planned deregulatory actions that it would be taking related to such executive order, including reconsideration of the regulations to limit power plant GHG emissions. On July 29, 2025, the EPA announced a proposal to rescind its 2009 Endangerment Finding. On February 12, 2026, the EPA issued a final rule rescinding its 2009 Endangerment Finding, thereby eliminating the basis for much of the EPA’s regulation of GHG emissions. However, depending on the outcome of any appeals and any future EPA actions, compliance with the GHG emissions limits could require additional capital expenditures or changes in operation at the Fort Martin and Harrison power stations.

On May 23, 2023, the EPA published a proposed rule pursuant to CAA Section 111 (b) and (d) in line with the decision in West Virginia v. Environmental Protection Agency intended to reduce power sector GHG emissions (primarily CO2 emissions) from fossil fuel based EGUs. On April 25, 2024, the EPA issued a final rule, which we refer to as the GHG rule, that imposed stringent GHG emissions limitations based on fuel type and unit retirement date. In May 2024, a group of 25 states, including West Virginia, filed a challenge to the rule in the D.C. Circuit. Also in May 2024, other utility groups, including the Midwest Ozone Group and Electric Generators for a Sensible Transition, both of which MP is a member, filed petitions for review of the GHG rule as well as motions to stay the rule in the D.C. Circuit. The D.C. Circuit subsequently granted a motion from the EPA placing the litigation in abeyance until further order of the Court. On June 17, 2025, the EPA published a proposed rule to repeal the GHG rule. The EPA is expected to issue a final rule repealing all or portions of the GHG rule in February 2026.

At the state level, there are several initiatives to reduce GHG emissions. Certain northeastern states are participating in the Regional Greenhouse Gas Initiative and western states, including California, have implemented programs to control emissions of certain GHGs and enhance public disclosures relating to the same. Additional policies reducing GHG emissions, such as demand reduction programs, renewable portfolio standards and renewable subsidies have been implemented across the nation.

FirstEnergy has pledged to achieve carbon neutrality by 2050 with respect to GHGs within FirstEnergy’s direct operational control (known as Scope 1 emissions). FirstEnergy’s ability to achieve its GHG reduction goal is subject to its ability to make operational changes and is conditioned upon numerous risks, many of which are outside of its control. With respect to FirstEnergy’s coal-fired facilities in West Virginia, which serve as the primary source of its Scope 1 emissions, it has identified that the end of the useful life date is 2035 for Fort Martin and 2040 for Harrison. MP filed its 10-year integrated resource plan with the WVPSC on October 1, 2025, which highlighted, among other things, the need for new dispatchable generation in West Virginia. Determination of the useful life of the regulated coal-fired generation could result in changes in depreciation, and/or continued collection of net plant in rates after retirement, securitization, sale, impairment, or regulatory disallowances. If FirstEnergy is unable to recover these costs, it could have a material adverse effect on FirstEnergy’s financial condition, results of operations, and cash flow. FirstEnergy cannot currently estimate the financial impact of climate change policies, although potential legislative or regulatory programs restricting CO2 emissions, or litigation alleging damages from GHG emissions, could require material capital and other expenditures or result in changes to its operations.

FirstEnergy continues to monitor climate change policies at both the federal and state level. Based on the EPA’s final rule rescinding the 2009 Endangerment Filing and other anticipated rulemaking, we may experience a reduction in GHG reporting and other regulatory obligations at the federal level over the near term. Multiple lawsuits opposing the EPA’s rescission were filed after it was finalized and the legal conflict is expected to be extensive. In light of the pending legal challenges, FirstEnergy is unable to predict the impact on its business and operations.

Clean Water Act

Various water quality regulations, the majority of which are the result of the federal Clean Water Act and its amendments, apply to FirstEnergy’s facilities. In addition, the states in which FirstEnergy operates have water quality standards applicable to FirstEnergy’s operations.

On September 30, 2015, the EPA finalized new, more stringent effluent limits for the Steam Electric Power Generating category (40 CFR Part 423) for arsenic, mercury, selenium and nitrogen for wastewater from wet scrubber systems and zero discharge of
pollutants in ash transport water. The treatment obligations were to phase-in as permits were renewed on a five-year cycle from 2018 to 2023. However, on April 13, 2017, the EPA granted a Petition for Reconsideration and on September 18, 2017, the EPA postponed certain compliance deadlines for two years. On August 31, 2020, the EPA issued a final rule revising the effluent limits for discharges from wet scrubber systems, retaining the zero-discharge standard for ash transport water, (with some limited discharge allowances), and extending the deadline for compliance to December 31, 2025, for both. In addition, the EPA allows for less stringent limits for sub-categories of generating units based on capacity utilization, flow volume from the scrubber system, and unit retirement date. On March 29, 2023, the EPA published proposed revised ELGs applicable to coal-fired electric generation facilities that include more stringent effluent limitations for wet scrubber systems and ash transport water, and new limits on landfill leachate. The rule was issued as final by the EPA on April 25, 2024. On May 30, 2024, the Utility Water Act Group, of which FirstEnergy is a member, filed a Petition for Review of the 2024 ELG Rule with the U.S. Court of Appeals for the Fifth and Eighth Circuit Courts, and on June 18, 2024, the Utility Water Group filed a motion to stay the rule pending disposition on the merits. A number of other parties have challenged the final rule in various petitions for review across several circuits. Those petitions and motions for stay have been consolidated in the U.S. Court of Appeals for the Eighth Circuit. On October 10, 2024, the U.S. Court of Appeals for the Eighth Circuit denied the motions for stay. Depending on the outcome of appeals and the EPA’s review, compliance with the 2024 ELG rule could require additional capital expenditures or changes in operation at closed and active landfills, and at the Ft. Martin and Harrison power stations from what was approved by the WVPSC in September 2022 to comply with the 2020 ELG rule. On February 19, 2025, the U.S. Department of Justice filed a motion on behalf of the EPA in the U.S. Court of Appeals for the Eighth Circuit, seeking to hold the litigation in abeyance for a period of 60 days while the new leadership at the EPA evaluates the rule and determines how it wishes to proceed. On February 28, 2025, U.S. Court of Appeals for the Eighth Circuit granted the EPA’s motion. On March 12, 2025, the EPA announced a series of planned deregulatory actions, including reconsideration of the 2024 ELG rule. On December 31, 2025, the EPA published a final ELG Deadline Extensions Rule extending certain compliance deadlines included in the 2024 ELG Rule by five years.

Regulation of Waste Disposal

Federal and state hazardous waste regulations have been promulgated as a result of the Resource Conservation and Recovery Act, as amended, and the Toxic Substances Control Act. Certain CCRs, such as coal ash, were exempted from hazardous waste disposal requirements pending the EPA’s evaluation of the need for future regulation.

In April 2015, the EPA finalized regulations for the disposal of CCRs (non-hazardous), establishing national standards for landfill design, structural integrity design and assessment criteria for surface impoundments, groundwater monitoring and protection procedures and other operational and reporting procedures to assure the safe disposal of CCRs from electric generation facilities. On September 13, 2017, the EPA announced that it would reconsider certain provisions of the final regulations. On July 29, 2020, the EPA published a final rule again revising the date that certain CCR impoundments must cease accepting waste and initiate closure to April 11, 2021. The final rule allowed for an extension of the closure deadline based on meeting identified site-specific criteria. On November 30, 2020, AE Supply submitted a closure deadline extension request to the EPA seeking to extend the cease accepting waste date for the McElroy's Run CCR impoundment facility to October 2024, which request was withdrawn by AE Supply on July 9, 2024, prior to the completion of the technical review by the EPA. As of May 31, 2024, AE Supply ceased accepting waste at the McElroy’s Run CCR impoundment facility from Pleasants Power Station. During 2024, as a result of the evaluation of closure options for McElroy’s Run CCR impoundment facility and the adjacent landfill, AE Supply reviewed its ARO and future expected costs to remediate, resulting in an increase to the ARO liability of $87 million. AE Supply transferred the McElroy’s Run CCR impoundment facility and adjacent dry landfill and related remediation obligations on March 4, 2025, pursuant to the environmental liability transfer agreement dated February 3, 2025 with a subsidiary of IDA Power, LLC. Pursuant to the agreement, AE Supply established a $160 million escrow account that AE Supply will fund over five years and is secured by a surety bond, which is guaranteed by FE. In connection with the transfer, AE Supply recognized a $130 million liability, based on a 4.8% weighted average discount rate over the contract term, associated with its remaining obligation to fund the escrow account over the next five years, and derecognized the ARO, resulting in an immaterial impact to earnings. During the twelve months ended December 31, 2025, AE Supply made $46 million of cash payments to the escrow account.

On May 8, 2024, the EPA issued the legacy CCR rule, which finalized changes to the CCR regulations addressing inactive surface impoundments at inactive electric utilities, known as legacy CCR surface impoundments. The rule extends 2015 CCR Rule requirements for groundwater monitoring and protection, operational and reporting procedures as well as closure requirements to impoundments and landfills that were not originally included for coverage by the 2015 CCR Rule. Furthermore, the EPA’s interpretations of the EPA CCR regulations continue to evolve through enforcement and other regulatory actions. FirstEnergy is currently assessing the potential impacts of the final rule, including a review of additional sites to which the new rule might be applicable. On February 13, 2025, the U.S. Department of Justice filed a motion on behalf of the EPA in the D.C. Circuit, seeking to hold the litigation, which was filed on August 8, 2024, by the Utility Solid Waste Act Group with FE as a member, in abeyance for a period of 120 days while the new leadership at the EPA evaluates the rule and determines how it wishes to proceed, which the D.C. Circuit granted. On March 12, 2025, the EPA announced a series of planned deregulatory actions, including reconsideration of the final legacy CCR rule. FirstEnergy continues to monitor the EPA’s actions related to CCR regulations; however, the ultimate impact is unknown at this time and is subject to the outcome of the litigation and any future state regulatory actions. Depending on the outcome of appeals and the EPA’s rule, compliance with the final legacy CCR rule could require remedial actions, including removal of coal ash. See Note 9., “Asset Retirement Obligations,” of the Combined Notes to Financial Statements of the Registrants above for a description of the $139 million increase to its ARO that FirstEnergy recorded during 2024 as a result of its analysis and reduced in the fourth quarter of 2025 based on the completion of engineering
studies and field analysis of certain sites. JCP&L did not have any potential legacy CCR disposal sites that were applicable to the 2024 legacy CCR rules. During the fourth quarter of 2025, FirstEnergy completed engineering studies and field analysis for certain of its legacy CCR disposal sites and determined that certain of those sites did not meet criteria to be applicable to the CCR rules. As a result, during the fourth quarter of 2025, FirstEnergy recorded a $49 million decrease to its ARO.

Certain of the FirstEnergy companies have been named as potentially responsible parties at waste disposal sites, which may require cleanup under the CERCLA. Allegations of disposal of hazardous substances at historical sites and the liability involved are often unsubstantiated and subject to dispute; however, federal law provides that all potentially responsible parties for a particular site may be liable on a joint and several basis. Environmental liabilities that are considered probable have been recognized on FirstEnergy’s Consolidated Balance Sheets as of December 31, 2025, based on estimates of the total costs of cleanup, FirstEnergy’s proportionate responsibility for such costs and the financial ability of other unaffiliated entities to pay. Total liabilities of approximately $97 million have been accrued through December 31, 2025, of which approximately $70 million are for environmental remediation of former MGP and gas holder facilities in New Jersey, which are being recovered by JCP&L through a non-bypassable societal benefits charge. FE or its subsidiaries could be found potentially responsible for additional amounts or additional sites, but the loss or range of losses cannot be determined or reasonably estimated at this time.

OTHER LEGAL PROCEEDINGS

United States v. Larry Householder, et al.

On July 21, 2020, a complaint and supporting affidavit containing federal criminal allegations were unsealed against the now former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr. Householder. In March 2023, a jury found Mr. Householder and his co-defendant, Matthew Borges, guilty and in June 2023, the two were sentenced to prison for 20 and five years, respectively. Messrs. Householder and Borges have appealed their sentences; the Sixth Circuit recently rejected their appeal upholding their convictions. Also, on July 21, 2020, and in connection with the U.S. Attorney’s Office’s investigation, FirstEnergy received subpoenas for records from the U.S. Attorney’s Office for the Southern District of Ohio. FirstEnergy was not aware of the criminal allegations, affidavit or subpoenas before July 21, 2020. On January 17, 2025, the U.S. Attorney’s Office announced that a federal grand jury charged two former FirstEnergy senior officers with one count of participating in a Racketeer Influenced and Corrupt Organizations Act conspiracy. The allegations in the indictment are largely based on the conduct described in the DPA.

On July 21, 2021, FE entered into a three-year DPA with the U.S. Attorney’s Office that, subject to court proceedings, resolves this matter as to FE. Under the DPA, FE agreed to the filing of a criminal information charging FE with one count of conspiracy to commit honest services wire fraud. The DPA required that FirstEnergy, among other obligations: (i) continue to cooperate with the U.S. Attorney’s Office in all matters relating to the conduct described in the DPA and other conduct under investigation by the U.S. government; (ii) pay a criminal monetary penalty totaling $230 million within sixty days, consisting of (x) $115 million paid by FE to the U.S. Treasury and (y) $115 million paid by FE to the ODSA to fund certain assistance programs, as determined by the ODSA, for the benefit of low-income Ohio electric utility customers; (iii) publish a list of all payments made in 2021 to either 501(c)(4) entities or to entities known by FirstEnergy to be operating for the benefit of a public official, either directly or indirectly, and update the same on a quarterly basis during the term of the DPA; (iv) issue a public statement, as dictated in the DPA, regarding FE’s use of 501(c)(4) entities; and (v) continue to implement and review its compliance and ethics program, internal controls, policies and procedures designed, implemented and enforced to prevent and detect violations of U.S. laws throughout its operations, and to take certain related remedial measures. The $230 million payment will neither be recovered in rates or charged to FirstEnergy customers, nor will FirstEnergy seek any tax deduction related to such payment. The entire amount of the monetary penalty was recognized as an expense in the second quarter of 2021 and paid in the third quarter of 2021. As of July 22, 2024, FirstEnergy had successfully completed the obligations required within the three-year term of the DPA. Under the DPA, FirstEnergy has an obligation to continue: (i) publishing quarterly a list of all payments to 501(c)(4) entities and all payments to entities known by FirstEnergy operating for the benefit of a public official, either directly or indirectly; (ii) not making any statements that contradict the DPA; (iii) notifying the U.S. Attorney’s Office of any changes in FirstEnergy’s corporate form; and (iv) cooperating with the U.S. Attorney’s Office until the conclusion of any related investigation, criminal prosecution, and civil proceeding brought by the U.S. Attorney’s Office, including the aforementioned federal indictment against two former FirstEnergy senior officers. Within 30 days of those matters concluding, and FirstEnergy’s successful completion of its remaining obligations, the U.S. Attorney’s Office will dismiss the criminal information. On February 26, 2025, the U.S. Attorney’s Office filed a status report confirming these commitments.

Legal Proceedings Relating to U.S. v. Larry Householder, et al.

Certain FE stockholders and FirstEnergy customers also filed several lawsuits against FirstEnergy and certain current and former directors, officers and other employees, and the complaints in each of these suits is related to allegations in the complaint and supporting affidavit relating to HB 6 and the now former Ohio House Speaker Larry Householder and other individuals and entities allegedly affiliated with Mr. Householder. The plaintiffs in each of the below cases seek, among other things, to recover an unspecified amount of damages (unless otherwise noted).

•In re FirstEnergy Corp. Securities Litigation (S.D. Ohio); on July 28, 2020, and August 21, 2020, purported stockholders of FE filed putative class action lawsuits alleging violations of the federal securities laws. Those actions have been
consolidated and a lead plaintiff, the Los Angeles County Employees Retirement Association, has been appointed by the court. A consolidated complaint was filed on February 26, 2021. The consolidated complaint alleges, on behalf of a proposed class of persons who purchased FE securities between February 21, 2017 and July 21, 2020, that FE and certain current or former FE officers violated Sections 10(b) and 20(a) of the Exchange Act by issuing alleged misrepresentations or omissions concerning FE’s business and results of operations. The consolidated complaint also alleges that FE, certain current or former FE officers and directors, and a group of underwriters violated Sections 11, 12(a)(2) and 15 of the Securities Act as a result of alleged misrepresentations or omissions in connection with offerings of senior notes by FE in February and June 2020. On March 30, 2023, the court granted plaintiffs’ motion for class certification. On April 14, 2023, FE filed a petition in the Sixth Circuit seeking to appeal that order. On August 13, 2025, the Sixth Circuit vacated the S.D. Ohio’s order granting class certification. On November 6, 2025, the S.D. Ohio held oral argument to further consider class certification in light of the Sixth Circuit’s decision. FE believes that it is probable that it will incur a loss in connection with the resolution of this lawsuit. Given the ongoing nature and complexity of such litigation, FE cannot yet reasonably estimate a loss or range of loss.
•MFS Series Trust I, et al. v. FirstEnergy Corp., et al. and Brighthouse Funds II – MFS Value Portfolio, et al. v. FirstEnergy Corp., et al. (S.D. Ohio); on December 17, 2021 and February 21, 2022, purported stockholders of FE filed complaints against FE, certain current and former officers, and certain then-current and former officers of Energy Harbor Corp. The complaints allege that the defendants violated Sections 10(b) and 20(a) of the Exchange Act by issuing alleged misrepresentations or omissions regarding FE’s business and its results of operations, and seek the same relief as the In re FirstEnergy Corp. Securities Litigation described above. FE believes that it is probable that it will incur losses in connection with the resolution of these lawsuits. Given the ongoing nature and complexity of such litigation, FE cannot yet reasonably estimate a loss or range of loss.

The outcome of any of these lawsuits is uncertain and could have a material adverse effect on FE’s or its subsidiaries’ reputation, business, financial condition, results of operations, liquidity, and cash flows.

Other Legal Matters

There are various lawsuits, claims (including claims for asbestos exposure) and proceedings related to the Registrants’ normal business operations pending against them or their subsidiaries. The loss or range of loss in these matters is not expected to be material to the Registrants. The other potentially material items not otherwise discussed above are described under Note 13., “Regulatory Matters” of the Combined Notes to Financial Statements of the Registrants.

The Registrants accrue legal liabilities only when it concludes that it is probable that it has an obligation for such costs and can reasonably estimate the amount of such costs. In cases where the Registrants determine that it is not probable, but reasonably possible that they have a material obligation, they disclose such obligations and the possible loss or range of loss if such estimate can be made. If it were ultimately determined that the Registrants have legal liability or are otherwise made subject to liability based on any of the matters referenced above, it could have a material adverse effect on the Registrants’ financial condition, results of operations, and cash flows.
v3.25.4
SEGMENT INFORMATION
 12 Months Ended
Dec. 31, 2025
Segment Reporting [Abstract]  
SEGMENT INFORMATION SEGMENT INFORMATION
The disclosures in this note apply to both Registrants, unless indicated otherwise.

FirstEnergy

FE and its subsidiaries are principally involved in the transmission, distribution and generation of electricity through its reportable segments: Distribution, Integrated and Stand-Alone Transmission. The external reportable segments are consistent with the internal financial reports used by FirstEnergy's Chairman, President and Chief Executive Officer, its CODM, to regularly assess the performance of each segment. FirstEnergy’s CODM uses earnings attributable to FE from continuing operations to assess performance, including considering actual versus budget variances to make operating decisions and allocate resources to the segments.

FirstEnergy's Distribution segment, which consists of the Ohio Companies and FE PA, distributes electricity through FirstEnergy’s electric operating companies in Ohio and Pennsylvania. The Distribution segment serves approximately 4.3 million customers in Ohio and Pennsylvania across its distribution footprint and purchases power for its default service or standard service offer requirements. The segment’s results reflect the costs of securing and delivering electric generation to customers, including the deferral and amortization of certain costs.

FirstEnergy's Integrated segment includes the distribution and transmission operations of JCP&L, MP and PE, as well as MP’s regulated generation operations. The Integrated segment distributes electricity to approximately 2 million customers in New Jersey, West Virginia and Maryland across its distribution footprint; provides transmission infrastructure in New Jersey, West Virginia, Maryland and Virginia to transmit electricity and operates 3,610 MWs of regulated generation capacity located primarily in West Virginia and Virginia, which includes three solar generation sites, representing 30 MWs of generation capacity. The segment’s results reflect the costs of securing and delivering electric generation to customers, including the deferral and amortization of certain costs. Additionally, on October 1, 2025, MP and PE filed their integrated resource plan with the WVPSC proposing, among other things, the addition of 70 MWs of solar generation by 2028, and 1,200 MWs of natural gas combined
cycle generation by 2031, which are expected to require an estimated capital investment of approximately $2.5 billion, as detailed in the filing. See Note 13., "Regulatory Matters," of the Combined Notes to Financial Statements of the Registrants for additional details.

FirstEnergy's Stand-Alone Transmission segment, which consists of FE's ownership in FET and KATCo, includes transmission infrastructure owned and operated by the Transmission Companies and used to transmit electricity. The segment’s revenues are primarily derived from forward-looking formula rates, pursuant to which the revenue requirement is updated annually based on a projected rate base and projected costs, which is subject to an annual true-up based on actual rate base and costs. The segment’s results also reflect the net transmission expenses related to the delivery of electricity on FirstEnergy’s transmission facilities.
FirstEnergy's Corporate/Other reflects corporate support and other costs not charged or attributable to the Electric Companies or Transmission Companies, including FE’s retained pension and OPEB assets and liabilities of former subsidiaries, interest expense on FE’s holding company debt and other investments or businesses that do not constitute an operating segment, including FEV’s investment of 33-1/3% equity ownership in Global Holding. On July 16, 2025, FEV sold its entire 33-1/3% equity ownership in Global Holding, the holding company for a joint venture in the Signal Peak mining and coal transportation operations, at book value to WMB Marketing Ventures, LLC and Pinesdale LLC for $47.5 million. Reconciling adjustments for the elimination of inter-segment transactions are shown separately in the following table of Segment Financial Information. Also included in Corporate/Other for segment reporting is 67 MWs of generation capacity, representing AE Supply’s OVEC capacity entitlement. As of December 31, 2025, Corporate/Other had approximately $6.8 billion of external FE holding company debt.
Financial information for FirstEnergy’s business segments and reconciliations to consolidated amounts is presented below:
(In millions)DistributionIntegratedStand-Alone TransmissionTotal Reportable SegmentsCorporate/OtherReconciling AdjustmentsFirstEnergy Consolidated
For the Years Ended
December 31, 2025
External revenues$7,508 $5,678 $1,886 $15,072 $18 $— $15,090 
Internal revenues39 5 19 63 — (63)— 
Total revenues$7,547 $5,683 $1,905 $15,135 $18 $(63)$15,090 
Other operating expenses(1)
2,479 1,416 328 4,223 (90)(11)4,122 
Depreciation(1)
655 562 369 1,586 78 — 1,664 
Amortization (deferral) of regulatory assets, net(103)(12)6 (109)— — (109)
Ohio settlement charges275 — — 275 — — 275 
Equity method investment earnings, net— — — — — — — 
Interest expense(1)
399 284 322 1,005 338 (126)1,217 
Income taxes (benefits)(1)
74 190 99 363 (75)— 288 
Other expense (income) items(2)
3,680 2,655 424 6,759 3 126 6,888 
Earnings (losses) attributable to FE from continuing operations363 588 357 1,308 (288)— 1,020 
Cash Flows from Investing Activities
Capital investments$1,344 $1,842 $1,601 $4,787 $(82)$— $4,705 
December 31, 2024
External revenues$6,824 $4,871 $1,768 $13,463 $9 $— $13,472 
Internal revenues39 5 19 63 — (63)— 
Total revenues$6,863 $4,876 $1,787 $13,526 $9 $(63)$13,472 
Other operating expenses(1)
2,378 1,254 347 3,979 75 (10)4,044 
Depreciation(1)
648 521 336 1,505 76 — 1,581 
Amortization (deferral) of regulatory assets, net(171)(66)6 (231)— — (231)
Equity method investment earnings, net— — — — 58 — 58 
Interest expense(1)
432 262 275 969 360 (185)1,144 
Income taxes (benefits)(1)
135 153 173 461 (84)— 377 
Other expense (income) items(2)
2,817 2,217 356 5,390 62 185 5,637 
Earnings (losses) attributable to FE from continuing operations624 535 294 1,453 (475)— 978 
Cash Flows from Investing Activities
Capital investments$1,130 $1,542 $1,266 $3,938 $92 $— $4,030 
December 31, 2023
External revenues$6,813 $4,315 $1,731 $12,859 $11 $— $12,870 
Internal revenues41 5 17 63 — (63)— 
Total revenues$6,854 $4,320 $1,748 $12,922 $11 $(63)$12,870 
Other operating expenses(1)
2,129 1,156 338 3,623 (34)(10)3,579 
Depreciation(1)
620 462 304 1,386 75 — 1,461 
Amortization (deferral) of regulatory assets, net(259)(10)8 (261)— — (261)
Equity method investment earnings, net— — — — 175 — 175 
Interest expense(1)
390 257 245 892 340 (108)1,124 
Income taxes (benefits)(1)
147 37 146 330 (63)— 267 
Other expense (income) items(2)
3,240 2,118 308 5,666 (22)108 5,752 
Earnings (losses) attributable to FE from continuing operations587 300 399 1,286 (163)— 1,123 
Cash Flows from Investing Activities
Capital investments$936 $1,212 $1,093 $3,241 $115 $— $3,356 
DistributionIntegratedStand-Alone TransmissionTotal Reportable SegmentsCorporate/OtherReconciling AdjustmentsFirstEnergy Consolidated
(In millions)
As of December 31, 2025
Total Assets$20,653 $20,352 $14,903 $55,908 $1,793 $(1,797)$55,904 
Total Goodwill$3,222 $1,953 $443 $5,618 $— $— $5,618 
As of December 31, 2024
Total Assets$19,949 $18,637 $13,528 $52,114 $1,975 $(2,045)$52,044 
Total Goodwill $3,222 $1,953 $443 $5,618 $— $— $5,618 
(1) FirstEnergy considers this line to be a significant expense.
(2) Consists of Fuel, Purchased power, General taxes, Ohio settlement charges, Impairment of assets, Debt redemption costs, Miscellaneous income, net, Capitalized financing costs, Pension and OPEB mark-to-market adjustments, and Income attributable to noncontrolling interest.
JCP&L

JCP&L is principally involved in the transmission and distribution of electricity through its reportable segments: Distribution and Transmission. The external reportable segments are consistent with the internal financial reports used by JCP&L's President, its CODM, to regularly assess the performance of each segment. JCP&L’s CODM uses net income to assess performance, including considering actual versus budget variances to make operating decisions and allocate resources to the segments.

JCP&L’s Distribution segment distributes electricity to approximately 1.2 million customers in New Jersey across its distribution footprint and procures electric supply to serve its BGS customers through a statewide auction process approved by the NJBPU. The segment’s results reflect the costs of securing and delivering electric generation to customers, including the deferral and amortization of certain costs.

JCP&L’s Transmission segment includes transmission infrastructure owned and operated by JCP&L that is used to transmit electricity. The segment’s revenues are primarily derived from forward-looking formula rates, pursuant to which the revenue requirement is updated annually based on a projected rate base and projected costs, which is subject to an annual true-up based on actual rate base and costs. The segment’s results also reflect the net transmission expenses related to the delivery of electricity on JCP&L’s transmission facilities.

Financial information for JCP&L’s reportable segments and reconciliations are presented below:
(In millions)
For the Years Ended
DistributionTransmissionTotal Reportable
Segments		Reconciling AdjustmentsJCP&L
December 31, 2025
External revenues$2,379 $259 $2,638 $— $2,638 
Internal revenues175 — 175 (175)— 
Total revenues$2,554 $259 $2,813 $(175)$2,638 
Other operating expenses(1)
791 64 855 (175)680 
Depreciation(1)
209 54 263 — 263 
Deferral of regulatory assets, net(134)— (134)— (134)
Interest expense - non-affiliates(1)
98 34 132 — 132 
Interest expense - affiliates(1)
6 — 6 — 6 
Income taxes71 36 107 — 107 
Other expense (income) items(2)
1,309 (31)1,278 — 1,278 
Net Income204 102 306 — 306 
Cash Flows from Investing Activities:
Capital investments$454 $651 $1,105 $— 1,105 
(In millions)
For the Years Ended
Distribution (3)
TransmissionTotal Reportable
Segments		Reconciling AdjustmentsJCP&L
December 31, 2024
External revenues$2,073 $242 $2,315 $— $2,315 
Internal revenues152 — 152 (152)— 
Total revenues$2,225 $242 $2,467 $(152)$2,315 
Other operating expenses(1)
745 61 806 (152)654 
Depreciation(1)
203 46 249 — 249 
Deferral of regulatory assets, net(124)— (124)— (124)
Interest expense - non-affiliates(1)
75 22 97 — 97 
Interest expense - affiliates(1)
20 — 20 — 20 
Income taxes52 35 87 — 87 
Other expense (income) items(2)
1,100 (10)1,090 — 1,090 
Net Income154 88 242 — 242 
Cash Flows from Investing Activities:
Capital investments$360 $519 $879 $— 879 
(In millions)
For the Years Ended
Distribution (3)
TransmissionTotal Reportable
Segments		Reconciling AdjustmentsJCP&L
December 31, 2023
External revenues$1,823 $204 $2,027 $— $2,027 
Internal revenues111 — 111 (111)— 
Total revenues$1,934 $204 $2,138 $(111)$2,027 
Other operating expenses(1)
601 65 666 (111)555 
Depreciation(1)
190 41 231 — 231 
Deferral of regulatory assets, net(67)— (67)— (67)
Interest expense - non-affiliates(1)
86 24 110 — 110 
Interest expense - affiliates(1)
14 — 14 — 14 
Income taxes11 22 33 — 33 
Other expense (income) items(2)
1,036 (10)1,026 — 1,026 
Net Income63 62 125 — 125 
Cash Flows from Investing Activities:
Capital investments$232 $401 $633 $— 633 
As of December 31, 2025
Total assets$7,941 $3,168 $11,109 $— $11,109 
Total goodwill$1,213 $598 $1,811 $— $1,811 
As of December 31, 2024
Total assets (3)
$7,198 $2,715 $9,913 $— $9,913 
Total goodwill$1,213 $598 $1,811 $— $1,811 
(1) JCP&L considers this line to be a significant expense.
(2) Consists of Purchased power, General taxes, Miscellaneous income, net, Capitalized financing costs, and Pension and OPEB mark-to-market adjustments.
(3) Previously issued 2024 and 2023 JCP&L amounts have been revised due to the correction of immaterial errors as discussed in Note 1., "Organization and Basis of Presentation," of the Combined Notes to Financial Statements of the Registrants.
v3.25.4
TRANSACTIONS WITH AFFILIATES
 12 Months Ended
Dec. 31, 2025
Related Party Transactions [Abstract]  
TRANSACTIONS WITH AFFILIATES TRANSACTIONS WITH AFFILIATES
The disclosures in this note apply to JCP&L only.
The affiliated company transactions for JCP&L for the years ended December 31, 2025, 2024 and 2023 are as follows:
For the Years Ended December 31,
202520242023
(In millions)
Revenues$1 $1 $1 
Expenses:
FESC support services(1)
180 166 174 
Other affiliate support services(1)
13 26 9 
Interest income 1 — — 
Interest expense6 20 14 
(1) Includes amounts capitalized of $77 million, $74 million and $61 million for 2025, 2024 and 2023, respectively.

FE does not bill directly or allocate any of its costs to any subsidiary company. FESC provides corporate support and other services, including executive administration, accounting and finance, risk management, human resources, corporate affairs, communications, information technology, legal services and other similar services at cost, in accordance with its cost allocation manual, to affiliated FirstEnergy companies under FESC agreements. Allocated costs are for services that are provided on behalf of more than one company, or costs that cannot be precisely identified and are allocated using formulas developed by FESC. Intercompany transactions are generally settled under commercial terms within thirty days. JCP&L can also receive charges from and charge affiliates other than FESC at cost.

JCP&L recognizes an allocation of the net periodic pension and OPEB costs/credits from its affiliates, primarily FESC.

Under the FirstEnergy regulated money pool, JCP&L has the ability to borrow from its regulated affiliates and FE to meet its short-term working capital requirements. Affiliated company notes receivables and payables related to the money pool are reported as Notes receivable from affiliated companies or Short-term borrowings - affiliated companies on the Balance Sheets. Affiliate accounts receivable and accounts payable balances relate to intercompany transactions that have not yet settled through the FirstEnergy money pool.

JCP&L is party to an intercompany income tax allocation agreement with FirstEnergy that provides for the allocation of consolidated tax liabilities.
v3.25.4
REVISION OF PREVIOUSLY ISSUED QUATERLY FINANCIAL STATEMENTS (Unaudited)
 12 Months Ended
Dec. 31, 2025
Accounting Changes and Error Corrections [Abstract]  
REVISION OF PREVIOUSLY ISSUED QUATERLY FINANCIAL STATEMENTS (Unaudited) REVISION OF PREVIOUSLY ISSUED QUARTERLY FINANCIAL STATEMENTS (Unaudited)
The disclosures in this note apply to JCP&L.

As discussed in Note 1.,"Organization and Basis of Presentation," during the fourth quarter of 2025, JCP&L identified an error in the recording of certain expenses for smart meter cost of removal associated with the deployment of its AMI program resulting in an understatement of expense on the Statements of Income and Comprehensive Income and Regulatory assets/liabilities on the Balance Sheets since 2023. JCP&L evaluated the error, and the specific impact on each affected prior period was not material, however, as a result of the cumulative impact, JCP&L determined to revise previously issued financial statements to correct the error and in doing so also corrected certain other previously identified immaterial errors, including the misclassification of certain retired assets.

JCP&L will revise previously reported financial information for this error in its future filings, as applicable. A summary of the corrections to the impacted financial statement line items to JCP&L’s previously issued unaudited quarterly Statements of Income and Comprehensive Income, Balance Sheets, Statements of Cash Flows and the Statements of Common Stockholder’s Equity are as follows:
JCP&L Interim Statements of Income and Comprehensive Income
For the Three Months Ended March 31, 2025For the Three Months Ended March 31, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
Deferral of regulatory assets, net$(22)$2 $(20)$(39)$2 $(37)
Other operating expenses145 — 145 187 (1)186 
Total operating expenses492 2 494 462 1 463 
Operating income74 (2)72 4 (1)3 
Income before income taxes65 (2)63 (12)(1)(13)
Income taxes16 — 16 (4)— (4)
Net income (loss)49 (2)47 (8)(1)(9)
Comprehensive income49 (2)47 (8)(1)(9)

For the Three Months Ended June 30, 2025For the Six Months Ended June 30, 2025
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
Deferral of regulatory assets, net$(14)$2 $(12)$(36)$4 $(32)
Other operating expenses133 4 137 278 4 282 
Total operating expenses493 6 499 985 8 993 
Operating income99 (6)93 173 (8)165 
Income before income taxes88 (6)82 153 (8)145 
Income taxes22 (2)20 38 (2)36 
Net income66 (4)62 115 (6)109 
Comprehensive income66 (4)62 115 (6)109 
For the Three Months Ended June 30, 2024For the Six Months Ended June 30, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
Deferral of regulatory assets, net$(34)$4 $(30)$(73)$5 $(68)
Other operating expenses158 (1)157 345 (2)343 
Total operating expenses458 3 461 920 3 923 
Operating income99 (3)96 103 (3)100 
Income before income taxes78 (3)75 66 (3)63 
Income taxes21 (1)20 17 (1)16 
Net income57 (2)55 49 (2)47 
Comprehensive income57 (2)55 49 (2)47 

For the Three Months Ended
September 30, 2025		For the Nine Months Ended
September 30, 2025
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
Amortization (deferral) of regulatory assets, net$11 $2 $13 $(25)$6 $(19)
Other operating expenses158 — 158 436 4 440 
Total operating expenses692 2 694 1,677 10 1,687 
Operating income172 (2)170 345 (10)335 
Income before income taxes160 (2)158 313 (10)303 
Income taxes41 (1)40 79 (3)76 
Net income119 (1)118 234 (7)227 
Comprehensive income119 (1)118 234 (7)227 
For the Three Months Ended
September 30, 2024		For the Nine Months Ended
September 30, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
Amortization (deferral) of regulatory assets, net$(25)$2 $(23)$(98)$8 $(90)
Other operating expenses179 1 180 524 (1)523 
Total operating expenses605 3 608 1,525 7 1,532 
Operating income160 (3)157 263 (7)256 
Income before income taxes150 (3)147 216 (7)209 
Income taxes41 (1)40 58 (2)56 
Net income109 (2)107 158 (5)153 
Comprehensive income109 (2)107 158 (5)153 

JCP&L Interim Balance Sheets
As of March 31, 2025As of March 31, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
PP&E - In service$8,807 $34 $8,841 $8,340 $12 $8,352 
Accumulated provision for depreciation2,415 30 2,445 2,371 8 2,379 
PP&E Excluding CWIP6,392 4 6,396 5,969 4 5,973 
Total PP&E7,053 4 7,057 6,469 4 6,473 
Regulatory assets/(liabilities)292 (20)272 9 (10)(1)
Total investments and other noncurrent assets2,683 (20)2,663 2,353 (9)2,344 
Total assets10,073 (16)10,057 9,212 (5)9,207 
Accumulated deferred income taxes, net1,223 (4)1,219 986 (1)985 
Total noncurrent liabilities3,981 (4)3,977 3,692 — 3,692 
Total liabilities5,075 (4)5,071 4,946 — 4,946 
Retained earnings1,341 (12)1,329 1,216 (5)1,211 
Total common stockholder's equity4,998 (12)4,986 4,266 (5)4,261 

As of June 30, 2025As of June 30, 2024
(In millions)As ReportedAdjustmentAs RevisedAs ReportedAdjustmentAs Revised
PP&E - In service$8,940 $30 $8,970 $8,458 $16 $8,474 
Accumulated provision for depreciation
2,434 30 2,464 2,388 12 2,400 
PP&E Excluding CWIP6,506 — 6,506 6,070 4 6,074 
Total PP&E7,232 — 7,232 6,581 4 6,585 
Regulatory assets/(liabilities)354 (23)331 95 (13)82 
Total investments and other noncurrent assets2,763 (23)2,740 2,444 (13)2,431 
Total assets10,450 (23)10,427 9,498 (9)9,489 
Accumulated deferred income taxes, net1,257 (7)1,250 1,037 (2)1,035 
Total noncurrent liabilities4,017 (7)4,010 3,742 (2)3,740 
Total liabilities5,385 (7)5,378 4,574 (2)4,572 
Retained earnings1,407 (16)1,391 1,273 (7)1,266 
Total common stockholder's equity5,065 (16)5,049 4,924 (7)4,917 
As of September 30, 2025As of September 30, 2024
(In millions)As ReportedAdjustmentAs RevisedAs ReportedAdjustmentAs Revised
PP&E - In service$9,002 $55 $9,057 $8,521 $15 $8,536 
Accumulated provision for depreciation 2,380 55 2,435 2,402 12 2,414 
PP&E Excluding CWIP6,622 — 6,622 6,119 3 6,122 
Total PP&E7,460 — 7,460 6,707 3 6,710 
Regulatory assets/(liabilities)410 (24)386 153 (15)138 
Total investments and other noncurrent assets2,843 (24)2,819 2,515 (15)2,500 
Total assets11,490 (24)11,466 9,611 (12)9,599 
Accumulated deferred income taxes, net1,292 (7)1,285 1,109 (3)1,106 
Total noncurrent liabilities5,380 (7)5,373 3,831 (3)3,828 
Total liabilities6,394 (7)6,387 4,576 (3)4,573 
Retained earnings1,436 (17)1,419 1,382 (9)1,373 
Total common stockholder's equity5,096 (17)5,079 5,035 (9)5,026 

JCP&L Interim Statements of Common Stockholder's of Equity
As of September 30, 2024
(In millions)As Reported AdjustmentAs Revised
Balance, January 1, 2024$4,132 $(4)$4,128 
Net loss(8)(1)(9)
Balance, March 31, 20244,266 (5)4,261 
Net income57 (2)55 
Balance, June 30, 20244,924 (7)4,917 
Net income109 (2)107 
Balance, September 30, 20245,035 (9)5,026 
As of September 30, 2025
(In millions)As Reported AdjustmentAs Revised
Balance, January 1, 2025$4,977 $(10)$4,967 
Net income49 (2)47 
Balance, March 31, 20254,998 (12)4,986 
Net income66 (4)62 
Balance, June 30, 20255,065 (16)5,049 
Net income119 (1)118 
Balance, September 30, 20255,096 (17)5,079 
JCP&L Interim Statements of Cash Flows
For the Three Months Ended
March 31, 2025		For the Three Months Ended
March 31, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income$49 $(2)$47 $(8)$(1)$(9)
Adjustments to reconcile net income to net cash from operating activities-
Depreciation, amortization and impairments43 2 45 71 2 73 
Deferred income taxes and investment tax credits, net23 — 23 27 — 27 
Net cash provided from operating activities205 — 205 83 1 84 
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital investments$(206)$— $(206)$(194)$(1)$(195)
Net cash used for investing activities(226)— (226)(215)(1)(216)
Net change in cash, cash equivalents, and restricted cash$— $— $— $— $— $— 

For the Six Months Ended
June 30, 2025		For the Six Months Ended
June 30, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income$115 $(6)$109 $49 $(2)$47 
Adjustments to reconcile net income to net cash from operating activities-
Depreciation, amortization and impairments94 4 98 108 5 113 
Deferred income taxes and investment tax credits, net53 (2)51 77 (1)76 
Net cash provided from operating activities326 (4)322 164 2 166 
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital investments$(477)$4 $(473)$(387)$(2)$(389)
Net cash used for investing activities(527)4 (523)(421)(2)(423)
Net change in cash, cash equivalents, and restricted cash$— $— $— $— $— $— 
For the Nine Months Ended
September 30, 2025		For the Nine Months Ended
September 30, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income$234 $(7)$227 $158 $(5)$153 
Adjustments to reconcile net income to net cash from operating activities-
Depreciation, amortization and impairments171 6 177 144 8 152 
Deferred income taxes and investment tax credits, net85 (3)82 148 (2)146 
Net cash provided from operating activities381 (4)377 427 1 428 
CASH FLOWS FROM FINANCING ACTIVITIES:
Capital investments$(782)$4 $(778)$(599)$(1)$(600)
Net cash used for investing activities(877)4 (873)(648)(1)(649)
Net change in cash, cash equivalents, and restricted cash$708 $— $708 $— $— $— 
v3.25.4
Insider Trading Arrangements
 3 Months Ended
Dec. 31, 2025
Trading Arrangements, by Individual  
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
v3.25.4
Insider Trading Policies and Procedures
 12 Months Ended
Dec. 31, 2025
Insider Trading Policies and Procedures [Line Items]  
Insider Trading Policies and Procedures Adopted true
v3.25.4
Cybersecurity Risk Management and Strategy Disclosure
 12 Months Ended
Dec. 31, 2025
Cybersecurity Risk Management, Strategy, and Governance [Line Items]  
Cybersecurity Risk Management Processes for Assessing, Identifying, and Managing Threats [Text Block]
FirstEnergy seeks to protect its customers, employees, facilities and the ongoing reliability of the electric system. FirstEnergy works closely with state and federal agencies and its peers in the electric utility industry to identify physical and cyber security risks, exchange information, and put safeguards in place to comply with strict reliability and security standards. From a security standpoint, the electric utility sector is one of the most regulated industries.
As a wholly owned subsidiary of FE, JCP&L utilizes and falls under the purview of FirstEnergy’s cyber security risk management program.
Risk Management and Strategy

FirstEnergy has established a broad framework to assess, identify and manage material risks from cyber security threats. This program is established at the executive level, with regular reporting to, and oversight by, the FE Board as described below. At the highest level, FirstEnergy’s program includes multi-layered governance by management, the Audit Committee, the Operations and Safety Committee, and the FE Board, as described in greater detail below.
Cybersecurity Risk Management Processes Integrated [Flag] true
Cybersecurity Risk Management Processes Integrated [Text Block] Central management and coordination of the program helps FirstEnergy to comprehensively evaluate and protect against cyber threats. FirstEnergy’s written policies and procedures identify how cyber security measures and controls are developed, implemented, and regularly reviewed and updated. FirstEnergy aims to align its cyber security program with national standards. For example, FirstEnergy has implemented and maintains a set of controls to manage cyber security risk based on, and in alignment with, the National Institute of Standards and Technology Cyber Security Framework, and for Bulk Electric System assets, the NERC Critical Infrastructure Protection standards. FirstEnergy also complies with various state laws and regulations on cyber security.
Cybersecurity Risk Management Third Party Engaged [Flag] true
Cybersecurity Risk Third Party Oversight and Identification Processes [Flag] true
Cybersecurity Risk Materially Affected or Reasonably Likely to Materially Affect Registrant [Flag] false
Cybersecurity Risk Board of Directors Oversight [Text Block]
The FE Board has identified cyber security as a key enterprise risk and prioritizes the mitigation of this risk through FirstEnergy’s enterprise risk management process. Responsibility for oversight of risk management generally lies with the FE Board and the FE Audit Committee has primary responsibility to oversee enterprise risk management. To effectively manage oversight of FirstEnergy’s cyber security risk management practices, since 2022, the FE Board has delegated oversight authority to each of FirstEnergy’s Audit and Operations and Safety Committees, respectively, as detailed in each Committees’ charters. The Audit Committee has primary responsibility to oversee the disclosure of material cyber security incidents, as well as the general obligation to ensure the proper risk oversight structure of cyber security as part of FirstEnergy’s overall enterprise risk management program and the internal controls applicable to cyber security matters. The Operations and Safety Oversight Committee has primary responsibility to oversee the operational aspects of FirstEnergy’s cyber security policies, programs, initiatives and strategies, as well as operational risk considerations related to cyber security matters. FirstEnergy’s Cyber Security Leaders regularly provide reports at the Audit Committee, Operations and Safety Oversight Committee, and to the full FE Board. Each such Committee and the full FE Board work collaboratively to ensure fulsome oversight with the proper focus of each respective Board body. These reports include, among other things, current and emerging cyber security risks to FirstEnergy, incidents that were escalated to management during the prior quarter, including those that did not require immediate escalation to the appropriate Committee and/or full FE Board, internal and external assessments of FirstEnergy’s cyber security program, and a roadmap of projects to manage its cyber security posture.
Cybersecurity Risk Board Committee or Subcommittee Responsible for Oversight [Text Block] Responsibility for oversight of risk management generally lies with the FE Board and the FE Audit Committee has primary responsibility to oversee enterprise risk management. To effectively manage oversight of FirstEnergy’s cyber security risk management practices, since 2022, the FE Board has delegated oversight authority to each of FirstEnergy’s Audit and Operations and Safety Committees, respectively, as detailed in each Committees’ charters. The Audit Committee has primary responsibility to oversee the disclosure of material cyber security incidents, as well as the general obligation to ensure the proper risk oversight structure of cyber security as part of FirstEnergy’s overall enterprise risk management program and the internal controls applicable to cyber security matters.
Cybersecurity Risk Process for Informing Board Committee or Subcommittee Responsible for Oversight [Text Block] The Operations and Safety Oversight Committee has primary responsibility to oversee the operational aspects of FirstEnergy’s cyber security policies, programs, initiatives and strategies, as well as operational risk considerations related to cyber security matters. FirstEnergy’s Cyber Security Leaders regularly provide reports at the Audit Committee, Operations and Safety Oversight Committee, and to the full FE Board. Each such Committee and the full FE Board work collaboratively to ensure fulsome oversight with the proper focus of each respective Board body. These reports include, among other things, current and emerging cyber security risks to FirstEnergy, incidents that were escalated to management during the prior quarter, including those that did not require immediate escalation to the appropriate Committee and/or full FE Board, internal and external assessments of FirstEnergy’s cyber security program, and a roadmap of projects to manage its cyber security posture.
Cybersecurity Risk Role of Management [Text Block]
The FE Board has identified cyber security as a key enterprise risk and prioritizes the mitigation of this risk through FirstEnergy’s enterprise risk management process. Responsibility for oversight of risk management generally lies with the FE Board and the FE Audit Committee has primary responsibility to oversee enterprise risk management. To effectively manage oversight of FirstEnergy’s cyber security risk management practices, since 2022, the FE Board has delegated oversight authority to each of FirstEnergy’s Audit and Operations and Safety Committees, respectively, as detailed in each Committees’ charters. The Audit Committee has primary responsibility to oversee the disclosure of material cyber security incidents, as well as the general obligation to ensure the proper risk oversight structure of cyber security as part of FirstEnergy’s overall enterprise risk management program and the internal controls applicable to cyber security matters. The Operations and Safety Oversight Committee has primary responsibility to oversee the operational aspects of FirstEnergy’s cyber security policies, programs, initiatives and strategies, as well as operational risk considerations related to cyber security matters. FirstEnergy’s Cyber Security Leaders regularly provide reports at the Audit Committee, Operations and Safety Oversight Committee, and to the full FE Board. Each such Committee and the full FE Board work collaboratively to ensure fulsome oversight with the proper focus of each respective Board body. These reports include, among other things, current and emerging cyber security risks to FirstEnergy, incidents that were escalated to management during the prior quarter, including those that did not require immediate escalation to the appropriate Committee and/or full FE Board, internal and external assessments of FirstEnergy’s cyber security program, and a roadmap of projects to manage its cyber security posture.

At the executive and management level, the CISO has primary responsibility for the development, operation, and maintenance of FirstEnergy’s cyber security program. FirstEnergy's CISO has over 30 years of cyber-experience with both large domestic and international companies, and holds an ISC2 Certified Information Systems Security Professional certification. The CISO reports directly to FirstEnergy’s Chief Information Officer, who is responsible for all of FirstEnergy’s digital and technology services and is FirstEnergy’s most senior information technology executive. Under the CISO’s oversight, FirstEnergy’s cyber security team implements and provides governance and functional oversight for cyber security controls and services. Cyber security processes include escalation of certain risks and incidents, including those that originate or occur at third parties, to the Chief Information Officer, Chief Operating Officer, FirstEnergy's legal team, and the executive leaders as appropriate based on the severity of any such risk or incident. In addition, regular updates from the cyber security teams, in conjunction with real-time escalation on an as-needed basis, are also used to update the risk landscape.
Cybersecurity Risk Management Positions or Committees Responsible [Flag] true
Cybersecurity Risk Management Positions or Committees Responsible [Text Block]
At the executive and management level, the CISO has primary responsibility for the development, operation, and maintenance of FirstEnergy’s cyber security program. FirstEnergy's CISO has over 30 years of cyber-experience with both large domestic and international companies, and holds an ISC2 Certified Information Systems Security Professional certification. The CISO reports directly to FirstEnergy’s Chief Information Officer, who is responsible for all of FirstEnergy’s digital and technology services and is FirstEnergy’s most senior information technology executive. Under the CISO’s oversight, FirstEnergy’s cyber security team implements and provides governance and functional oversight for cyber security controls and services. Cyber security processes include escalation of certain risks and incidents, including those that originate or occur at third parties, to the Chief Information Officer, Chief Operating Officer, FirstEnergy's legal team, and the executive leaders as appropriate based on the severity of any such risk or incident. In addition, regular updates from the cyber security teams, in conjunction with real-time escalation on an as-needed basis, are also used to update the risk landscape.
Cybersecurity Risk Management Expertise of Management Responsible [Text Block] FirstEnergy's CISO has over 30 years of cyber-experience with both large domestic and international companies, and holds an ISC2 Certified Information Systems Security Professional certification.
Cybersecurity Risk Process for Informing Management or Committees Responsible [Text Block] In the event of any significant cyber security incident, FirstEnergy’s Cyber Security Incident Response Plan provides for a severity determination by the cyber security incident response team based on factors such as the number of assets affected, the likelihood of inappropriate data exposure, operational impact, reliability impact, and regulatory impact. Dependent upon the severity of an incident, it is FirstEnergy’s practice to escalate the incident to the Chief Information Officer, the Chief Risk Officer, FirstEnergy's legal team, and the FE senior leadership team, including the Chief Legal Officer, Chief Financial Officer, and Chief Executive Officer.
Cybersecurity Risk Management Positions or Committees Responsible Report to Board [Flag] true
v3.25.4
ORGANIZATION AND BASIS OF PRESENTATION (Policies)
 12 Months Ended
Dec. 31, 2025
Organization, Consolidation and Presentation of Financial Statements [Abstract]  
Basis of Presentation
Basis of Presentation

The Registrants follow GAAP and comply with the related regulations, orders, policies and practices prescribed by the SEC, FERC, and, as applicable, the PUCO, the PPUC, the MDPSC, the NYPSC, the WVPSC, the VSCC and the NJBPU. The preparation of financial statements in conformity with GAAP requires management to make periodic estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and disclosure of contingent assets and liabilities. Actual results could differ from these estimates. The reported results of operations are not necessarily indicative of results of operations for any future period. The Registrants have evaluated events and transactions for potential recognition or disclosure through the date the financial statements were issued.
CONSOLIDATION The Registrants consolidate all majority-owned subsidiaries over which they exercise control and, when applicable, entities for which they have a controlling financial interest. Intercompany transactions and balances are eliminated in consolidation as appropriate and permitted pursuant to GAAP. The Registrants consolidate a variable interest entity when it is determined that it is the primary beneficiary. Investments in affiliates over which the Registrants have the ability to exercise significant influence, but do not have a controlling financial interest, follow the equity method of accounting. Under the equity method, the interest in the entity is reported as an investment on the Balance Sheets and the percentage of ownership share of the entity’s earnings is reported in the Statements of Income.
ACCOUNTING FOR THE EFFECTS OF REGULATION
ACCOUNTING FOR THE EFFECTS OF REGULATION

The Registrants are subject to regulation that sets the prices (rates) they are permitted to charge customers based on costs that the regulatory agencies determine are permitted to be recovered. At times, regulatory agencies permit the future recovery of costs that would be currently charged to expense by an unregulated company. The ratemaking process results in the recording of regulatory assets and liabilities based on anticipated future cash inflows and outflows.
The Registrants review the probability of recovery of regulatory assets, and settlement of regulatory liabilities, at each balance sheet date and whenever new events occur. Factors that may affect probability include changes in the regulatory environment, issuance of a regulatory commission order, or passage of new legislation. Upon material changes to these factors, where applicable, the Registrants will record new regulatory assets or liabilities and will assess whether it is probable that currently recorded regulatory assets and liabilities will be recovered or settled in future rates. If recovery of a regulatory asset is no longer probable, the Registrants will write off that regulatory asset as a charge against earnings. The Registrants consider the entire regulatory asset balance as the unit of account for the purposes of balance sheet classification rather than the next years recovery and, as such, net regulatory assets and liabilities are presented in the noncurrent section on the Registrants' Balance Sheets.
DERIVATIVES
DERIVATIVES

FirstEnergy may use various market risk sensitive instruments, including derivative contracts, primarily to manage the risk of price and interest rate fluctuations. FirstEnergy’s Enterprise Risk Management Committee, comprised of members of senior management, provides general oversight for risk management activities throughout FirstEnergy, including market risk.
The Registrants account for derivative instruments on the Balance Sheets at fair value unless they meet the normal purchases and normal sales criteria. Derivative instruments meeting the normal purchases and normal sales criteria are accounted for under the accrual method of accounting with their effects included in earnings at the time of contract performance.
EQUITY METHOD INVESTMENTS
EQUITY METHOD INVESTMENTS
Investments over which the Registrants have the ability to exercise significant influence, but do not have a controlling financial interest, follow the equity method of accounting. Under the equity method, the interest in the entity is reported in “Investments” on the Registrants Balance Sheets. The percentage of ownership share of the entity’s earnings is reported in the Registrants Statement of Income and reflected in “Other income (expense)”. Equity method investments are assessed for impairment annually or whenever events and changes in circumstances indicate that the carrying amount of the investment may not be recoverable. If the decline in value is considered to be other than temporary, the investment is written down to its estimated fair value, which establishes a new cost basis in the investment.
GOODWILL
GOODWILL

In a business combination, the excess of the purchase price over the estimated fair value of the assets acquired and liabilities assumed is recognized as goodwill. The Registrants evaluates goodwill for impairment annually on July 31 and more frequently if indicators of impairment arise. In evaluating goodwill for impairment, the Registrants assess qualitative factors to determine whether it is more likely than not (that is, likelihood of more than 50%) that the fair value of a reporting unit is less than its carrying value (including goodwill). If the Registrants conclude that it is not more likely than not that the fair value of a reporting unit is less than its carrying value, then no further testing is required. However, if the Registrants conclude that it is more likely than not that the fair value of a reporting unit is less than its carrying value or bypasses the qualitative assessment, then the quantitative goodwill impairment test is performed to identify a potential goodwill impairment and measure the amount of impairment to be recognized, if any.
As of July 31, 2025, the Registrants performed a qualitative assessment of its reporting units' goodwill, assessing economic, industry and market considerations in addition to the reporting units' overall financial performance. Key factors used in the assessment included: growth rates, interest rates, expected investments, utility sector market performance, regulatory and legal developments, and other market considerations. It was determined that the fair values of these reporting units were, more likely than not, greater than their carrying values and a quantitative analysis was not necessary.
INVENTORY
INVENTORY

Materials and supplies inventory primarily includes fuel inventory, the distribution, transmission and electric generation facility materials, net of reserve for excess and obsolete inventory as well as emission allowances. Materials charged to inventory are at weighted average cost when purchased and expensed or capitalized, as appropriate, when used or installed. Fuel inventory consists primarily of coal and reagents that are consumed at MP's electric generation facilities, and is accounted for at weighted average cost when purchased and recorded to fuel expense when consumed.

Emission allowances are accounted for as inventory at cost when purchased. FirstEnergy’s emission allowance compliance obligation, principally associated with MP's electric generation facility operations, is accrued to fuel expense at a weighted average cost based on each month’s emissions. When emission allowances are submitted to the EPA, inventory and the compliance obligation are reduced. Due to the ENEC, fuel, emission allowances and other fuel-related expenses have no material impact on current period earnings.
NONCONTROLLING INTEREST
NONCONTROLLING INTEREST

FirstEnergy - FirstEnergy maintains a controlling financial interest in certain less than wholly owned subsidiaries. As a result, FirstEnergy presents the third-party investors’ ownership portion of FirstEnergy's net income, net assets and comprehensive income as noncontrolling interest. Noncontrolling interest is included as a component of equity on the Consolidated Balance Sheets.

On May 31, 2022, Brookfield acquired 19.9% of the issued and outstanding membership interests of FET. On February 2, 2023, FE, along with FET, entered into the FET P&SA II with Brookfield and the Brookfield Guarantors, pursuant to which FE agreed to sell to Brookfield at the closing, and Brookfield agreed to purchase from FE, an incremental 30% equity interest in FET for a purchase price of $3.5 billion. The FET Equity Interest Sale closed on March 25, 2024 and FET continues to be consolidated in FirstEnergy’s financial statements. The difference between the purchase price, net of transaction costs and taxes of approximately $32 million and $803 million, respectively, and the carrying value of the NCI of $731 million, was recorded as an increase to OPIC by $1.9 billion during 2024. As of December 31, 2025, FE’s equity ownership in FET is 50.1% and Brookfield’s is 49.9%.
The purchase price of the FET Equity Interest Sale was paid in part by the issuance of two promissory notes at closing having an aggregate principal amount of $1.2 billion with: (i) one promissory note having an aggregate principal amount of $750 million, at an interest rate of 5.75% per annum, with a maturity date of September 25, 2025 and (ii) one promissory note having an aggregate principal amount of $450 million, at an interest rate of 7.75% per annum, with a maturity date of December 31, 2024. The remaining $2.3 billion of the purchase price was paid in cash at closing. On July 17, 2024, Brookfield paid FE approximately $1.2 billion in full satisfaction of the promissory notes. Interest income associated with the promissory notes was $24 million for the year ended December 31, 2024 and is reported within “Miscellaneous income, net” on FirstEnergy’s Consolidated Statements of Income.
Pursuant to the terms of the FET P&SA II, in connection with the closing, Brookfield, FET and FE entered into the A&R FET LLC Agreement, which amended and restated in its entirety the Third Amended and Restated Limited Liability Company Agreement of FET. The A&R FET LLC Agreement, among other things, provides for the governance, exit, capital and distribution, and other arrangements for FET from and following the closing. Under the A&R FET LLC Agreement, as of the closing, the FET Board of Directors consists of five directors, two of whom are appointed by Brookfield and three of whom are appointed by FE.
PROPERTY, PLANT AND EQUIPMENT
PROPERTY, PLANT AND EQUIPMENT
PP&E reflects original cost (net of any impairments recognized), including payroll and related costs such as taxes, employee benefits, administrative and general costs, and financing costs incurred to place the assets in service. The costs of normal maintenance, repairs and minor replacements are expensed as incurred. The Registrants' recognize liabilities for planned major maintenance projects as they are incurred.
NEW ACCOUNTING PRONOUNCEMENTS
NEW ACCOUNTING PRONOUNCEMENTS

Recently Adopted Pronouncements - ASU 2023-09, "Income taxes (Topic 280): Improvements to Income Tax Disclosures" (Issued in December 2023): ASU 2023-09 enhances disclosures primarily related to existing rate reconciliation and income taxes paid information to help investors better assess how a company’s operations and related tax risks and tax planning and operational opportunities affect the tax rate and prospects for future cash flows. Disclosure requirements include a tabular reconciliation using both percentages and amounts, separated out into specific categories with certain reconciling items at or above 5% of the statutory tax as well as by nature and/or jurisdiction. In addition, entities will be required to disclose income taxes paid (net of refunds received), broken out between federal, state/local and foreign, and amounts paid to an individual jurisdiction when 5% or more of the total income taxes are paid to such jurisdiction. ASU 2023-09 was effective for the Registrants beginning with this Annual Report on Form 10-K for the year ended December 31, 2025, see Note 6., “Taxes,” of the Combined Notes to Financial Statements of the Registrants for the applicable disclosures, which are provided for all periods presented.

Recently Issued Pronouncements - The following new authoritative accounting guidance issued by the FASB has not yet been adopted. Unless otherwise indicated, the Registrants’ management is currently assessing the impact such guidance may have on their financial statements and disclosures, as well as the potential to early adopt where applicable. Management has assessed other FASB issuances of new standards not described below based upon the current expectation that such new standards will not significantly impact the Registrants’ financial statements.

ASU 2024-03, "Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures (Subtopic 220-40)" (Issued in November 2024 and subsequently updated within ASU 2025-01): ASU 2024-03 requires disaggregated disclosure of income statement expenses for public business entities. The ASU does not change the expense captions an entity presents on the face of the income statement; rather, it requires disaggregation of certain expense captions into specified
categories in disclosures within the footnotes to the financial statements. ASU 2024-03 is effective for the Registrants beginning with the Annual Report on Form 10-K for the year ended December 31, 2027, with early adoption permitted. The guidance is permitted to be applied prospectively, and comparative disclosures are not required for reporting periods beginning before the effective date. Entities can elect to apply the new standard retrospectively to any or all prior periods presented in the financial statements.

ASU 2025-06, “Intangibles—Goodwill and Other—Internal-Use Software (Subtopic 350-40): Targeted Improvements to the Accounting for Internal-Use Software" (Issued in September 2025): ASU 2025-06 amends the existing standard that refers to various stages of a software development project to align better with current software development methods, such as agile programming. Under the new standard, entities will start capitalizing eligible costs when (1) management has authorized and committed to funding the software project, and (2) it is probable that the project will be completed and the software will be used to perform the function intended. In evaluating whether it is probable the project will be completed; an entity is required to consider whether there is significant uncertainty associated with the development activities of the software. ASU 2025-06 is effective for the Registrants beginning with the financials for the first quarter of 2028. The guidance is permitted to be applied using a prospective, retrospective or modified transition approach. Early adoption is permitted.

ASU 2025-10, Government Grants (Topic 832): Accounting for Government Grants Received by Business Entities (Issued in December 2025): ASU 2025-10 establishes authoritative guidance for the recognition, measurement, presentation, and disclosure of government grants received by business entities. ASU 2025-10 requires that a government grant be recognized when it is probable that the entity will comply with the conditions of the grant and that the grant will be received and permits two approaches for asset related grants: (1) the cost reduction method (reduce the carrying amount of the asset) and (2) deferred income method (recognize income over the useful life of the asset). Income-related grants are recognized systematically in income as the related costs are incurred. ASU 2025-10 is effective for the Registrants beginning with financials for the first quarter of 2029, with early adoption permitted. The guidance is permitted to be applied using a modified prospective, modified retrospective or full retrospective approach.
RECEIVABLES
RECEIVABLES
Receivables from contracts with customers include retail electric sales and distribution deliveries to residential, commercial and industrial customers of the Electric Companies.
The allowance for uncollectible customer receivables is based on historical loss information comprised of a rolling 36-month average net write-off percentage of revenues, in conjunction with a qualitative assessment of elements that impact the collectability of receivables to determine if allowances for uncollectible customer receivables should be further adjusted in accordance with the accounting guidance for credit losses.

The Registrants review allowance for uncollectible customer receivables utilizing a quantitative and qualitative assessment. Management contemplates available current information such as changes in economic factors, regulatory matters, industry trends, customer credit factors, amount of receivable balances that are past-due, payment options and programs available to customers, and the methods that the Electric Companies are able to utilize to ensure payment. The Registrants’ uncollectible risk on PJM receivables, resulting from transmission and wholesale sales, is minimal due to the nature of PJM’s settlement process
and as a result there is no current allowance for doubtful accounts.
EARNINGS PER SHARE OF COMMON STOCK
Basic EPS is computed using the weighted average number of common shares outstanding during the relevant period as the denominator. The denominator for diluted EPS of common stock reflects the weighted average of common shares outstanding plus the potential additional common shares that could result if dilutive securities and other agreements to issue common stock were exercised.
Diluted EPS reflects the dilutive effect of potential common shares from share-based awards and convertible securities. The dilutive effect of outstanding share-based awards was computed using the treasury stock method, which assumes any proceeds that could be obtained upon the exercise of the award would be used to purchase common stock at the average market price for the period. The dilutive effect of the 2026 Convertible Notes, 2029 Convertible Notes and the 2031 Convertible Notes, as further discussed in Note 11., "Capitalization" under Long-term debt and other long-term obligations, is computed using the if-converted method.
PENSION AND OTHER POSTEMPLOYMENT BENEFITS
The pension plans provide defined benefits based on years of service and compensation levels. Under the cash-balance portion of the pension plan (for employees hired on or after January 1, 2014), FirstEnergy credits amounts to eligible employee notional cash-balance accounts based on a pay credit and an interest credit.
In addition, FirstEnergy provides a minimum amount of noncontributory life insurance to retired employees in addition to optional contributory insurance to a closed group of retired employees. Health care benefits, which include certain employee contributions, deductibles and co-payments, are also available upon retirement to certain employees, their dependents and, under certain circumstances, their survivors. The expected cost of providing pension and OPEB to employees and their beneficiaries and covered dependents is recognized from the time employees are hired until they become eligible to receive those benefits. FirstEnergy also has obligations to former or inactive employees after employment, but before retirement, for disability-related benefits.

FirstEnergy’s pension funding policy is based on actuarial computations using the projected unit credit method. FirstEnergy does not currently expect to have a required contribution to the pension plan until 2027, which based on various assumptions, including an expected rate of return on assets of 8.0% for 2026, is expected to be approximately $250 million. However, FirstEnergy may elect to contribute to the pension plan voluntarily. JCP&L is not expected to make a contribution.
Pension and OPEB costs are affected by employee demographics (including age, compensation levels and employment periods), the level of contributions made to the plans and earnings on plan assets. Pension and OPEB costs may also be affected by changes in key assumptions, including anticipated rates of return on plan assets, the discount rates and health care trend rates used in determining the projected benefit obligations for pension and OPEB costs. FirstEnergy uses a December 31 measurement date for its pension and OPEB plans or whenever a plan is determined to qualify for a remeasurement. The fair value of the plan assets represents the actual market value as of the measurement date.
In January 2025, FirstEnergy executed a lift-out transaction with MetLife, that transferred approximately $640 million of plan assets and $652 million of plan obligations, associated with approximately 2,000 former competitive generation employees, who will assume future and full responsibility to fund and administer their benefit payments. Similar to the lift-out in 2023, there was no change to the pension benefits for any participant as a result of the transfer and the transaction was funded by pension plan assets. FirstEnergy believes that this lift-out transaction, in addition to the lift-out in 2023, further de-risked potential volatility with the pension plan assets and liabilities. FirstEnergy will continue to evaluate other lift-outs in the future based on market and other conditions.
STOCK-BASED COMPENSATION PLANS Shares granted under the ICP 2020 are issued from authorized but unissued common stock. Vesting periods for stock-based awards range from less than a year, primarily due to the issuance of prorated awards to newly hired executives, to four years, with the majority of awards having a vesting period of three years. FirstEnergy also issues stock through its 401(k) savings plan and DCPD.
FirstEnergy records the compensation costs for stock-based compensation awards that will be paid in stock over the vesting period based on the fair value on the grant date. FirstEnergy accounts for forfeitures as they occur.
FirstEnergy adjusts the compensation costs for stock-based compensation awards that will be paid in cash based on changes in the fair value of the award as of each reporting date. FirstEnergy records the actual tax benefit realized from tax deductions when awards are exercised or settled.
TAXES
The Registrants record income taxes in accordance with the liability method of accounting. Deferred income taxes reflect the net tax effect of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts recognized for tax purposes. Investment tax credits, which were deferred when utilized, are being amortized over the recovery period of the related property. Deferred income tax liabilities related to temporary tax and accounting basis differences and tax credit carryforward items are recognized at the statutory income tax rates in effect when the liabilities are expected to be paid. Deferred tax assets are recognized based on income tax rates expected to be in effect when they are settled.
VARIABLE INTEREST ENTITIES
The disclosures in this note apply to both Registrants, unless indicated otherwise.

The Registrants perform qualitative analyses to determine whether a variable interest qualifies them as the primary beneficiary (a controlling financial interest) of a VIE. An enterprise has a controlling financial interest if it has both: (i) the power to direct the activities of a VIE that most significantly impact the entity’s economic performance; and (ii) the obligation to absorb losses of the entity that could potentially be significant to the VIE or the right to receive benefits from the entity that could potentially be significant to the VIE. The Registrants consolidate a VIE when it is determined that it is the primary beneficiary. JCP&L does not have any consolidated or unconsolidated VIE's.

In order to evaluate contracts for consolidation treatment and entities for which FirstEnergy has an interest, FirstEnergy aggregates variable interests into categories based on similar risk characteristics and significance.

FirstEnergy - Consolidated VIEs
VIEs in which FirstEnergy is the primary beneficiary consist of the following and are included in FirstEnergy’s consolidated financial statements:
•Securitization Companies

•Ohio Securitization Companies - In June 2013, the SPEs formed by the Ohio Companies issued approximately $445 million of pass-through trust certificates supported by phase-in recovery bonds to securitize the recovery of certain all-electric customer heating discounts, fuel and purchased power regulatory assets. The phase-in recovery bonds are payable only from, and secured by, phase in recovery property owned by the SPEs. The bondholder has no recourse to the general credit of FirstEnergy or any of the Ohio Companies. Each of the Ohio Companies, as servicer of its respective SPE, manages and administers the phase in recovery property including the billing, collection and remittance of usage-based charges payable by retail electric customers. The SPEs are considered VIEs and each one is consolidated into its applicable utility. As of December 31, 2025 and 2024, $159 million and $175 million of the phase-in recovery bonds were outstanding, respectively.

•MP and PE Environmental Funding Companies - The consolidated financial statements of FirstEnergy include environmental control bonds issued by two bankruptcy remote, special purpose limited liability companies that are indirect subsidiaries of MP and PE. Proceeds from the bonds were used to construct environmental control facilities. Principal and interest owed on the environmental control bonds is secured by, and payable solely from, the proceeds of the environmental control charges. Creditors of FirstEnergy, other than the limited liability company SPEs, have no recourse to any assets or revenues of the special purpose limited liability companies. As of December 31, 2025 and 2024, $156 million and $188 million of environmental control bonds were outstanding, respectively.
•FirstEnergy's Consolidated Balance Sheets includes restricted cash of 40 million as of December 31, 2025 and 2024 which is related to cash collected from MP, PE and the Ohio Companies' customers that is specifically used to service debt of their respective funding companies.
FAIR VALUE MEASUREMENTS
Authoritative accounting guidance establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. This hierarchy gives the highest priority to Level 1 measurements and the lowest priority to Level 3 measurements. The three levels of the fair value hierarchy and a description of the valuation techniques are as follows:
Level 1-Quoted prices for identical instruments in active market
Level 2-Quoted prices for similar instruments in active market
-Quoted prices for identical or similar instruments in markets that are not active
-Model-derived valuations for which all significant inputs are observable market data
Models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors and current market and contractual prices for the underlying instruments, as well as other relevant economic measures.
Level 3-Valuation inputs are unobservable and significant to the fair value measurement
FirstEnergy produces a long-term power and capacity price forecast annually with periodic updates as market conditions change. When underlying prices are not observable, prices from the long-term price forecast are used to measure fair value.

FTRs are financial instruments that entitle the holder to a stream of revenues (or charges) based on the hourly day-ahead congestion price differences across transmission paths. FTRs are acquired by FirstEnergy in the annual, monthly and long-term PJM auctions and are initially recorded using the auction clearing price less cost. After initial recognition, FTRs' carrying values are periodically adjusted to fair value using a mark-to-model methodology, which approximates market. The primary inputs into the model, which are generally less observable than objective sources, are the most recent PJM auction clearing prices and the FTRs' remaining hours. The model calculates the fair value by multiplying the most recent auction clearing price by the remaining FTR hours less the prorated FTR cost. Significant increases or decreases in inputs in isolation may have resulted in a higher or lower fair value measurement.
INVESTMENTS
INVESTMENTS

All temporary cash investments purchased with an initial maturity of three months or less are reported as cash equivalents on the Consolidated Balance Sheets at cost, which approximates their fair market value. Investments other than cash and cash equivalents include AFS debt securities and other investments. The Registrants have no debt securities held for trading purposes.
Generally, unrealized gains and losses on equity securities are recognized in income whereas unrealized gains and losses on AFS debt securities are recognized in AOCI. However, the JCP&L spent nuclear fuel disposal trusts are subject to regulatory accounting with all gains and losses on equity and AFS debt securities offset against regulatory assets.
LONG-TERM DEBT AND OTHER LONG-TERM OBLIGATIONS
LONG-TERM DEBT AND OTHER LONG-TERM OBLIGATIONS
All borrowings with initial maturities of less than one year are defined as short-term financial instruments under GAAP and are reported as Short-term borrowings on the Consolidated Balance Sheets at cost. Since these borrowings are short-term in nature, the Registrants believe that their costs approximate their fair market value.
v3.25.4
ORGANIZATION AND BASIS OF PRESENTATION (Tables)
 12 Months Ended
Dec. 31, 2025
Organization, Consolidation and Presentation of Financial Statements [Abstract]  
Schedule of Error Corrections and Prior Period Adjustments
JCP&L Annual Statements of Income and Comprehensive Income

For the Year Ended December 31, 2024For the Year Ended December 31, 2023
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
Deferral of regulatory assets, net$(135)$11 $(124)$(74)$7 $(67)
Other operating expenses656 (2)654 555 — 555 
Total operating expenses 1,946 9 1,955 1,770 7 1,777 
Operating income369 (9)360 257 (7)250 
Income before income taxes338 (9)329 165 (7)158 
Income taxes90 (3)87 35 (2)33 
Net income248 (6)242 130 (5)125 
Comprehensive income 249 (6)243 130 (5)125 

JCP&L Annual Balance Sheets
As of December 31, 2024As of December 31, 2023
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
PP&E - In service$8,697 $34 $8,731 $8,278 $10 $8,288 
Accumulated provision for depreciation 2,409 30 2,439 2,365 8 2,373 
PP&E Excluding CWIP6,288 4 6,292 5,913 2 5,915 
Total PP&E6,908 4 6,912 6,388 2 6,390 
Regulatory assets/(liabilities)265 (18)247 (48)(8)(56)
Total investments and other noncurrent assets2,640 (18)2,622 2,330 — 2,330 
Total assets 9,927 (14)9,913 9,100 2 9,102 
Accumulated deferred income taxes, net1,196 (4)1,192 957 (2)955 
Total noncurrent liabilities4,605 (4)4,601 3,717 6 3,723 
Total liabilities4,950 (4)4,946 4,968 6 4,974 
Retained earnings 1,322 (10)1,312 1,224 (4)1,220 
Total common stockholder's equity4,977 (10)4,967 4,132 (4)4,128 

JCP&L Annual Statements of Common Stockholder's Equity
For the Years Ended December 31, 2024 and 2023
(In millions)As Reported AdjustmentAs Revised
Balance, January 1, 2023$3,967 $1 $3,968 
Net income130 (5)125 
Balance, December 31, 20234,132 (4)4,128 
Net income248 (6)242 
Balance, December 31, 20244,977 (10)4,967 
JCP&L Annual Statements of Cash Flows
For the Year Ended
December 31, 2024		For the Year Ended
December 31, 2023
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income$248 $(6)$242 $130 $(5)$125 
Adjustments to reconcile net income to net cash from operating activities-
Depreciation, amortization and impairments161 11 172 145 7 152 
Deferred income taxes and investment tax credits, net233 (3)230 50 (2)48 
Net cash provided from operating activities607 2 609 264 — 264 
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital investments$(877)$(2)$(879)$(633)$— $(633)
Net cash used for investing activities(947)(2)(949)(690)— (690)
Net change in cash, cash equivalents, and restricted cash$— $— $— $— $— $— 
A summary of the corrections to the impacted financial statement line items to JCP&L’s previously issued unaudited quarterly Statements of Income and Comprehensive Income, Balance Sheets, Statements of Cash Flows and the Statements of Common Stockholder’s Equity are as follows:
JCP&L Interim Statements of Income and Comprehensive Income
For the Three Months Ended March 31, 2025For the Three Months Ended March 31, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
Deferral of regulatory assets, net$(22)$2 $(20)$(39)$2 $(37)
Other operating expenses145 — 145 187 (1)186 
Total operating expenses492 2 494 462 1 463 
Operating income74 (2)72 4 (1)3 
Income before income taxes65 (2)63 (12)(1)(13)
Income taxes16 — 16 (4)— (4)
Net income (loss)49 (2)47 (8)(1)(9)
Comprehensive income49 (2)47 (8)(1)(9)

For the Three Months Ended June 30, 2025For the Six Months Ended June 30, 2025
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
Deferral of regulatory assets, net$(14)$2 $(12)$(36)$4 $(32)
Other operating expenses133 4 137 278 4 282 
Total operating expenses493 6 499 985 8 993 
Operating income99 (6)93 173 (8)165 
Income before income taxes88 (6)82 153 (8)145 
Income taxes22 (2)20 38 (2)36 
Net income66 (4)62 115 (6)109 
Comprehensive income66 (4)62 115 (6)109 
For the Three Months Ended June 30, 2024For the Six Months Ended June 30, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
Deferral of regulatory assets, net$(34)$4 $(30)$(73)$5 $(68)
Other operating expenses158 (1)157 345 (2)343 
Total operating expenses458 3 461 920 3 923 
Operating income99 (3)96 103 (3)100 
Income before income taxes78 (3)75 66 (3)63 
Income taxes21 (1)20 17 (1)16 
Net income57 (2)55 49 (2)47 
Comprehensive income57 (2)55 49 (2)47 

For the Three Months Ended
September 30, 2025		For the Nine Months Ended
September 30, 2025
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
Amortization (deferral) of regulatory assets, net$11 $2 $13 $(25)$6 $(19)
Other operating expenses158 — 158 436 4 440 
Total operating expenses692 2 694 1,677 10 1,687 
Operating income172 (2)170 345 (10)335 
Income before income taxes160 (2)158 313 (10)303 
Income taxes41 (1)40 79 (3)76 
Net income119 (1)118 234 (7)227 
Comprehensive income119 (1)118 234 (7)227 
For the Three Months Ended
September 30, 2024		For the Nine Months Ended
September 30, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
Amortization (deferral) of regulatory assets, net$(25)$2 $(23)$(98)$8 $(90)
Other operating expenses179 1 180 524 (1)523 
Total operating expenses605 3 608 1,525 7 1,532 
Operating income160 (3)157 263 (7)256 
Income before income taxes150 (3)147 216 (7)209 
Income taxes41 (1)40 58 (2)56 
Net income109 (2)107 158 (5)153 
Comprehensive income109 (2)107 158 (5)153 

JCP&L Interim Balance Sheets
As of March 31, 2025As of March 31, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
PP&E - In service$8,807 $34 $8,841 $8,340 $12 $8,352 
Accumulated provision for depreciation2,415 30 2,445 2,371 8 2,379 
PP&E Excluding CWIP6,392 4 6,396 5,969 4 5,973 
Total PP&E7,053 4 7,057 6,469 4 6,473 
Regulatory assets/(liabilities)292 (20)272 9 (10)(1)
Total investments and other noncurrent assets2,683 (20)2,663 2,353 (9)2,344 
Total assets10,073 (16)10,057 9,212 (5)9,207 
Accumulated deferred income taxes, net1,223 (4)1,219 986 (1)985 
Total noncurrent liabilities3,981 (4)3,977 3,692 — 3,692 
Total liabilities5,075 (4)5,071 4,946 — 4,946 
Retained earnings1,341 (12)1,329 1,216 (5)1,211 
Total common stockholder's equity4,998 (12)4,986 4,266 (5)4,261 

As of June 30, 2025As of June 30, 2024
(In millions)As ReportedAdjustmentAs RevisedAs ReportedAdjustmentAs Revised
PP&E - In service$8,940 $30 $8,970 $8,458 $16 $8,474 
Accumulated provision for depreciation
2,434 30 2,464 2,388 12 2,400 
PP&E Excluding CWIP6,506 — 6,506 6,070 4 6,074 
Total PP&E7,232 — 7,232 6,581 4 6,585 
Regulatory assets/(liabilities)354 (23)331 95 (13)82 
Total investments and other noncurrent assets2,763 (23)2,740 2,444 (13)2,431 
Total assets10,450 (23)10,427 9,498 (9)9,489 
Accumulated deferred income taxes, net1,257 (7)1,250 1,037 (2)1,035 
Total noncurrent liabilities4,017 (7)4,010 3,742 (2)3,740 
Total liabilities5,385 (7)5,378 4,574 (2)4,572 
Retained earnings1,407 (16)1,391 1,273 (7)1,266 
Total common stockholder's equity5,065 (16)5,049 4,924 (7)4,917 
As of September 30, 2025As of September 30, 2024
(In millions)As ReportedAdjustmentAs RevisedAs ReportedAdjustmentAs Revised
PP&E - In service$9,002 $55 $9,057 $8,521 $15 $8,536 
Accumulated provision for depreciation 2,380 55 2,435 2,402 12 2,414 
PP&E Excluding CWIP6,622 — 6,622 6,119 3 6,122 
Total PP&E7,460 — 7,460 6,707 3 6,710 
Regulatory assets/(liabilities)410 (24)386 153 (15)138 
Total investments and other noncurrent assets2,843 (24)2,819 2,515 (15)2,500 
Total assets11,490 (24)11,466 9,611 (12)9,599 
Accumulated deferred income taxes, net1,292 (7)1,285 1,109 (3)1,106 
Total noncurrent liabilities5,380 (7)5,373 3,831 (3)3,828 
Total liabilities6,394 (7)6,387 4,576 (3)4,573 
Retained earnings1,436 (17)1,419 1,382 (9)1,373 
Total common stockholder's equity5,096 (17)5,079 5,035 (9)5,026 

JCP&L Interim Statements of Common Stockholder's of Equity
As of September 30, 2024
(In millions)As Reported AdjustmentAs Revised
Balance, January 1, 2024$4,132 $(4)$4,128 
Net loss(8)(1)(9)
Balance, March 31, 20244,266 (5)4,261 
Net income57 (2)55 
Balance, June 30, 20244,924 (7)4,917 
Net income109 (2)107 
Balance, September 30, 20245,035 (9)5,026 
As of September 30, 2025
(In millions)As Reported AdjustmentAs Revised
Balance, January 1, 2025$4,977 $(10)$4,967 
Net income49 (2)47 
Balance, March 31, 20254,998 (12)4,986 
Net income66 (4)62 
Balance, June 30, 20255,065 (16)5,049 
Net income119 (1)118 
Balance, September 30, 20255,096 (17)5,079 
JCP&L Interim Statements of Cash Flows
For the Three Months Ended
March 31, 2025		For the Three Months Ended
March 31, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income$49 $(2)$47 $(8)$(1)$(9)
Adjustments to reconcile net income to net cash from operating activities-
Depreciation, amortization and impairments43 2 45 71 2 73 
Deferred income taxes and investment tax credits, net23 — 23 27 — 27 
Net cash provided from operating activities205 — 205 83 1 84 
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital investments$(206)$— $(206)$(194)$(1)$(195)
Net cash used for investing activities(226)— (226)(215)(1)(216)
Net change in cash, cash equivalents, and restricted cash$— $— $— $— $— $— 

For the Six Months Ended
June 30, 2025		For the Six Months Ended
June 30, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income$115 $(6)$109 $49 $(2)$47 
Adjustments to reconcile net income to net cash from operating activities-
Depreciation, amortization and impairments94 4 98 108 5 113 
Deferred income taxes and investment tax credits, net53 (2)51 77 (1)76 
Net cash provided from operating activities326 (4)322 164 2 166 
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital investments$(477)$4 $(473)$(387)$(2)$(389)
Net cash used for investing activities(527)4 (523)(421)(2)(423)
Net change in cash, cash equivalents, and restricted cash$— $— $— $— $— $— 
For the Nine Months Ended
September 30, 2025		For the Nine Months Ended
September 30, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income$234 $(7)$227 $158 $(5)$153 
Adjustments to reconcile net income to net cash from operating activities-
Depreciation, amortization and impairments171 6 177 144 8 152 
Deferred income taxes and investment tax credits, net85 (3)82 148 (2)146 
Net cash provided from operating activities381 (4)377 427 1 428 
CASH FLOWS FROM FINANCING ACTIVITIES:
Capital investments$(782)$4 $(778)$(599)$(1)$(600)
Net cash used for investing activities(877)4 (873)(648)(1)(649)
Net change in cash, cash equivalents, and restricted cash$708 $— $708 $— $— $— 
Schedule of Regulatory Assets on the Balance Sheets
As of December 31,
Net Regulatory Assets (Liabilities) by Source - FirstEnergy20252024Change
 (In millions)
Customer payables for future income taxes$(2,041)$(2,234)$193 
Spent nuclear fuel disposal costs(76)(72)(4)
Asset removal costs(675)(681)6 
Deferred transmission costs(43)190 (233)
Deferred generation costs405 481 (76)
Deferred distribution costs466 287 179 
Storm-related costs1,122 1,015 107 
Energy efficiency program costs462 349 113 
New Jersey societal benefit costs80 87 (7)
Vegetation management153 125 28 
Ohio settlement charges(250)— (250)
Other41 75 (34)
Net Regulatory Liabilities included on FirstEnergy's Consolidated Balance Sheets$(356)$(378)$22 

The following table provides information about the composition of JCP&L's net regulatory assets and liabilities as of December 31, 2025 and 2024, and the changes during the year 2025:
As of December 31,
Net Regulatory Assets (Liabilities) by Source - JCP&L20252024Change
(In millions)
Customer payables for future income taxes$(393)$(410)$17 
Spent nuclear fuel disposal costs(76)(72)(4)
Asset removal costs (1)
(87)(101)14 
Deferred transmission costs(25)(3)(22)
Deferred distribution costs318 206 112 
Storm-related costs367 310 57 
Energy efficiency program costs316 208 108 
New Jersey societal benefit costs80 87 (7)
Other15 22 (7)
Net Regulatory Assets included on JCP&L's Balance Sheets$515 $247 $268 
(1) Previously issued 2024 JCP&L amounts have been revised due to the correction of immaterial errors as discussed in Note 1., "Organization and Basis of Presentation," of the Combined Notes to Financial Statements of the Registrants.
The following table provides information about the composition of FirstEnergy's net regulatory assets that do not earn a current return as of December 31, 2025 and 2024, of which approximately $802 million and $698 million, respectively, are currently being recovered through rates over varying periods, through 2068, depending on the nature of the deferral and the jurisdiction:
Regulatory Assets by Source Not Earning aAs of December 31,
Current Return - FirstEnergy20252024Change
(In millions)
Deferred generation costs$280 $314 $(34)
Deferred distribution costs199 153 46 
Storm-related costs844 694 150 
Other102 82 20 
FirstEnergy Regulatory Assets Not Earning a Current Return$1,425 $1,243 $182 

The following table provides information about the composition of JCP&L's net regulatory assets that do not earn a current return as of December 31, 2025 and 2024, of which approximately $76 million and $45 million, respectively, are currently being recovered through rates over varying periods, through 2068, depending on the nature of the deferral:
Regulatory Assets by Source Not Earning aAs of December 31,
Current Return - JCP&L20252024Change
(In millions)
Deferred distribution costs$147 $101 $46 
Storm-related costs367 310 57 
Other24 28 (4)
JCP&L Regulatory Assets Not Earning a Current Return$538 $439 $99 
Schedule of Goodwill The following table presents goodwill by reporting unit as of December 31, 2025 and 2024:
(In millions)Distribution SegmentIntegrated SegmentStand-Alone Transmission SegmentFirstEnergy Consolidated
Goodwill$3,222 $1,953 $443 $5,618 

JCP&L's reporting units are consistent with its reportable segments and consist of Distribution and Transmission. The following table presents goodwill by reporting unit as of December 31, 2025 and 2024:
(In millions)Distribution Segment Transmission SegmentJCP&L
Goodwill$1,213 $598 $1,811 
Schedule of Property, Plant and Equipment Balances
PP&E balances by segment as of December 31, 2025 and 2024, were as follows:
December 31, 2025
Segment
In Service(1)
Accumulated. Depreciation(2)
Net PlantCWIPTotalUseful Service Life
(In millions)
(years)
Distribution $21,944 $(7,511)$14,433 $682 $15,115 
5 - 80
Integrated 18,380 (4,154)14,226 1,314 15,540 
5 - 80
Stand-Alone Transmission 14,759 (2,878)11,881 1,333 13,214 
5 - 85
Corporate/Other1,130 (646)484 60 544 
3 - 63
Total PP&E$56,213 $(15,189)$41,024 $3,389 $44,413 
December 31, 2024
Segment
In Service(1)
Accumulated. Depreciation(2)
Net PlantCWIPTotal
Useful Service Life
(In millions)(years)
Distribution$21,245 $(7,338)$13,907 $618 $14,525 
5 - 80
Integrated17,080 (3,943)13,137 1,076 14,213 
5 - 100
Stand-Alone Transmission13,509 (2,660)10,849 986 11,835 
5 - 85
Corporate/Other1,062 (607)455 74 529 
3 - 63
Total PP&E$52,896 $(14,548)$38,348 $2,754 $41,102 
(1) Includes finance leases of $48 million and $46 million as of December 31, 2025 and 2024, respectively.
(2) Includes finance lease accumulated amortization of $17 million and $14 million as of December 31, 2025 and 2024, respectively.
PP&E by segment as of December 31, 2025 and 2024, were as follows:
December 31, 2025
Segment
In Service(1)
Accumulated. Depreciation(2)
Net PlantCWIPTotal Useful Service Life
(In millions)
(years)
Distribution$6,679 $(1,925)$4,754 $270 $5,024 
5 - 75
Transmission2,588 (514)2,074 610 2,684 
5 - 80
Total PP&E$9,267 $(2,439)$6,828 $880 $7,708 
December 31, 2024
Segment
In Service(1)
Accumulated. Depreciation(2)
Net PlantCWIPTotal Useful Service Life
(In millions)
(years)
Distribution$6,438 $(1,938)$4,500 $187 $4,687 
10 - 75
Transmission2,293 (501)1,792 433 2,225 
55 - 80
Total PP&E (3)
$8,731 $(2,439)$6,292 $620 $6,912 
(1) Includes finance leases of $12 million and $11 million as of December 31, 2025 and 2024, respectively.
(2) Includes finance lease accumulated amortization of $6 million and $5 million as of December 31, 2025 and 2024, respectively.
(3) Previously issued 2024 JCP&L amounts have been revised due to the correction of immaterial errors as discussed in Note 1., "Organization and Basis of Presentation," of the Combined Notes to Financial Statements of the Registrants.
v3.25.4
REVENUE (Tables)
 12 Months Ended
Dec. 31, 2025
Revenue from Contract with Customer [Abstract]  
Schedule of Disaggregation of Revenue
The following represents a disaggregation of FirstEnergy's revenue from contracts with customers for the years ended December 31, 2025, 2024 and 2023:

FirstEnergyFor the Years Ended December 31,
(In millions)202520242023
 Distribution
Retail generation and distribution services
Residential $4,948 $4,514 $4,344 
Commercial 1,699 1,522 1,528 
Industrial 651 588 726 
Other 73 73 72 
Wholesale 16 6 20 
Other revenue from contracts with customers (1)
78 80 89 
Total revenues from contracts with customers7,465 6,783 6,779 
Other revenue unrelated to contracts with customers (2)
82 80 75 
Total Distribution$7,547 $6,863 $6,854 
Integrated
Retail generation and distribution services
Residential$2,877 $2,528 $2,137 
Commercial1,294 1,142 1,023 
Industrial615 577 545 
Other32 32 30 
Wholesale377 146 208 
Transmission 425 380 318 
Other revenue from contracts with customers(1)
6 19 24 
Total revenues from contracts with customers5,626 4,824 4,285 
ARP (3)
— 10 — 
Other revenue unrelated to contracts with customers(2)
57 42 35 
Total Integrated $5,683 $4,876 $4,320 
Stand-Alone Transmission
ATSI $1,058 $980 $967 
TrAIL 260 269 279 
MAIT 483 436 394 
KATCo85 85 89 
Other — (2)2 
Total revenues from contracts with customers1,886 1,768 1,731 
Other revenue unrelated to contracts with customers19 19 17 
Total Stand-Alone Transmission $1,905 $1,787 $1,748 
Corporate/Other, Eliminations and Reconciling Adjustments (4)
Wholesale$18 $9 $11 
Eliminations and reconciling adjustments (63)(63)(63)
Total Corporate/Other, Eliminations and Reconciling Adjustments$(45)$(54)$(52)
FirstEnergy Total Revenues $15,090 $13,472 $12,870 
(1) Primarily includes amounts collected from customers to administer and repay securitization bonds and pole attachment revenue.
(2) Primarily includes late payment charges and revenue from FTRs.
(3) Related to lost distribution revenues associated with energy efficiency in New Jersey.
(4) Includes eliminations and reconciling adjustments of inter-segment revenues.
The following table represents a disaggregation of JCP&L's revenue from contracts with customers for the years ended December 31, 2025, 2024 and 2023:
For the Years Ended December 31,
(In millions)202520242023
 Distribution
Retail generation and distribution services
Residential $1,705 $1,470 $1,240 
Commercial 728 627 579 
Industrial 76 70 68 
Street lighting
21 20 21 
Wholesale 6 6 5
Other revenue from contracts with customers (1)
14 18 18
Total revenues from contracts with customers2,550 2,211 1,931 
ARP(2)
— 10 — 
Other revenue unrelated to contracts with customers4 4 3
Total Distribution Segment Revenue $2,554 $2,225 $1,934 
Transmission
Total Transmission Segment Revenue $259 $242 $204 
 Reconciling Adjustments(3)
Retail generation and distribution services$(175)$(152)$(111)
JCP&L Total Revenues $2,638 $2,315 $2,027 
(1) Primarily includes pole attachment revenue.
(2) Related to lost distribution revenues associated with energy efficiency in New Jersey.
(3) Includes eliminations and reconciling adjustments of inter-segment revenues.
Schedule of Receivables from Customers Billed and unbilled customer receivables as of December 31, 2025 and 2024, are included below.
Customer ReceivablesFirstEnergy JCP&L
As of December 31, 2025202420252024
 (In millions)
Billed(1)
$939 $867 $178 $166 
Unbilled844 718 152 118 
1,783 1,585 330 284 
Less: Uncollectible Reserve 57 55 6 6 
Total Customer Receivables $1,726 $1,530 $324 $278 
(1) Includes approximately $323 million and $284 million for FirstEnergy as of December 31, 2025 and 2024, respectively, that are past due by greater than 30 days.
Schedule of Activity in the Allowance for Uncollectible Accounts on Customer Receivables and Other Receivables
Activity in the allowance for uncollectible accounts on customer receivables for the years ended December 31, 2025, 2024 and 2023 are as follows:
Customer Receivables FirstEnergy JCP&L
(In millions)
Balance, January 1, 2023$137 $21 
Provision for expected credit losses(1)(2)
8 (1)
Charged to other accounts(3)
34 3 
Write-offs(115)(14)
Balance, December 31, 2023649
Provision for expected credit losses(1)(2)
73 5 
Charged to other accounts(3)
39 4 
Write-offs(121)(12)
Balance, December 31, 202455 6 
Provision for expected credit losses(1)(2)
94 8 
Charged to other accounts(3)
37 3 
Write-offs(129)(11)
Balance, December 31, 2025$57 $6 
(1) Customer receivable amounts charged (credited) to income for FirstEnergy for the years ended December 31, 2025, 2024 and 2023, include approximately $31 million, $17 million, and $(15) million, respectively, deferred for future recovery (refund).
(2) Customer receivable amounts charged (credited) to income for JCP&L include approximately $8 million, $5 million and $(1) million deferred for future recovery (refund) for the years ended December 31, 2025, 2024 and 2023 respectively.
(3) Represents recoveries and reinstatements of accounts written off for uncollectible accounts.
Activity in the allowance for uncollectible accounts on other receivables for the years ended December 31, 2025, 2024 and 2023 are as follows:
Other Receivables FirstEnergy JCP&L
(In millions)
Balance, January 1, 2024$11 $6 
Provision for expected credit losses7 — 
Charged to other accounts(1)
(1)— 
Write-offs(2)— 
Balance, December 31, 202315 6 
Provision for expected credit losses1 — 
Charged to other accounts(1)
(5)(6)
Write-offs(5)— 
Balance, December 31, 20246 — 
Provision for expected credit losses9 1 
Charged to other accounts(1)
— — 
Write-offs(4)(1)
Balance, December 31, 2025$11 $— 
(1) Represents recoveries and reinstatements of accounts written off for uncollectible accounts.
v3.25.4
EARNINGS PER SHARE OF COMMON STOCK (Tables)
 12 Months Ended
Dec. 31, 2025
Earnings Per Share [Abstract]  
Schedule of Reconciliation of Basic and Diluted EPS Attributable to FE
The following table reconciles basic and diluted EPS attributable to FE:

For the Years Ended December 31,
Reconciliation of Basic and Diluted EPS of Common Stock202520242023
(In millions, except per share amounts)
Earnings Attributable to FE - continuing operations$1,020 $978 $1,123 
Earnings Attributable to FE - discontinued operations, net of tax— — (21)
Earnings Attributable to FE$1,020 $978 $1,102 
Share Count information:
Weighted average number of basic shares outstanding577 575 573 
Assumed exercise of dilutive share-based awards1 2 1 
Weighted average number of diluted shares outstanding578 577 574 
EPS Attributable to FE:
Income from continuing operations, basic$1.77 $1.70 $1.96 
Discontinued operations, basic — — (0.04)
Basic EPS$1.77 $1.70 $1.92 
Income from continuing operations, diluted$1.76 $1.70 $1.96 
Discontinued operations, diluted— — (0.04)
Diluted EPS$1.76 $1.70 $1.92 
v3.25.4
PENSION AND OTHER POSTEMPLOYMENT BENEFITS (Tables)
 12 Months Ended
Dec. 31, 2025
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Schedule of Assumptions Used to Determine Net Periodic Benefit Cost
Actuarial Assumptions PensionOPEB
20252024
2023 (2)
20252024
2023 (2)
Assumptions Related to Benefit Obligations:
Discount rate5.59 %5.72 %5.05 %5.37 %5.60 %4.97 %
Rate of compensation increase4.30 %4.30 %4.30 %N/AN/AN/A
Cash balance weighted average interest crediting rate4.64 %4.37 %4.94 %N/AN/AN/A
Assumptions Related to Benefit Costs:(1)
Effective rate for interest on benefit obligations 5.41 %4.92 %
5.10% / 4.80%
5.28 %4.88 %5.06 %
Effective rate for service costs 5.89 %5.17 %
5.34% / 5.11%
5.98 %5.23 %5.41 %
Effective rate for interest on service costs 5.66 %5.05 %
5.22% /4.94%
5.88 %5.16 %5.33 %
Expected return on plan assets8.50 %8.00 %8.00 %7.00 %7.00 %7.00 %
Rate of compensation increase4.30 %4.30 %4.30 %N/AN/AN/A
Assumed Health Care Cost Trend Rates:
Health care cost trend rate assumed (pre/post-Medicare)N/AN/AN/A
6.50% - 5.80%
7.00%-
6.00%
7.00%-
6.50%
Rate to which the cost trend rate is assumed to decline (ultimate trend rate)N/AN/AN/A4.50 %4.50 %4.50 %
Year that the rate reaches the ultimate trend rateN/AN/AN/A203620352033
(1) Excludes impact of pension and OPEB mark-to-market adjustments.
(2) As a result of the interim plan remeasurement during 2023, different rates were in effect from January 1, 2023, through April 30, 2023 compared to May 1, 2023 through December 31, 2023.
Schedule of Fair Value of Plan Assets Explanatory
FirstEnergy Pension and OPEB Returns202520242023
 Actual gains or (losses) on plan assets - $ millions$880 $3 $751 
Actual gains or (losses) on plan assets - %15.4 %0.7 %11.2 %
Expected return on plan assets - $ millions$499 $565 $601 
Expected return on plan assets - %
8.50% for pension

7.00% for OPEB
8.00% for pension

7.00% for OPEB
8.00% for pension

7.00% for OPEB
Schedule of Components of Net Periodic Benefit Costs
FirstEnergy Components of Net Periodic Benefit Costs (Credits) for the Years Ended December 31,PensionOPEB
202520242023202520242023
 (In millions)
Service cost(1)
$131 $140 $139 $2 $3 $2 
Interest cost 374 398 428 20 20 21 
Expected return on plan assets (461)(530)(570)(38)(35)(31)
Amortization of prior service costs (credits)1 2 2 (1)(1)(8)
Special termination benefits(2)
— — 21 — — 8 
Pension & OPEB mark-to-market adjustments(231)66 108 (22)(44)(30)
Net periodic benefit costs (credits)$(186)$76 $128 $(39)$(57)$(38)
(1) Includes amounts capitalized.
(2) Related to benefits provided in connection with the PEER.
JCP&L’s net periodic benefit costs (credits) for pension and OPEB were as follows:

PensionOPEB
For the Years Ended December 31,202520242023202520242023
(In millions)
JCP&L's share of net periodic benefit credits (1)(2)
$(37)$(12)$10 $(28)$(27)$(29)
Allocated net periodic benefit costs from affiliates (1)(3)
$(1)$6 $40 $1 $— $1 
(1) Includes amounts capitalized.
(2) Includes JCP&L’s pension and OPEB mark-to-market adjustment gain (loss) of $45 million, $22 million and $2 million for the years ended December 31, 2025, 2024 and 2023, respectively.
(3) Included in these net periodic benefit costs/(credits) from its affiliates are $10 million, $2 million and $(31) million of mark-to-market adjustment gain (loss), for the years ended December 31, 2025, 2024 and 2023, respectively.

Summary of Plan Status PensionOPEB
As of December 31, (in millions)
2025202420252024
JCP&L's share of FirstEnergy funded status(2)
$(29)$(67)$243 $215 
(1) OPEB amounts include a $7 million contribution from JCP&L in 2024.
(2) Excludes $492 million and $502 million as of December 31, 2025 and 2024, respectively, of affiliated noncurrent liabilities included within "Other" noncurrent liabilities on JCP&L's Balance Sheets related to pension and OPEB mark-to-market costs allocated to JCP&L and amounts associated with a reallocation of OPEB assets among certain FirstEnergy companies in 2022.
Schedule of Obligations and Funded Status
FirstEnergy PensionOPEB
Obligations/Funded Status - Qualified and Non-Qualified Plans2025202420252024
(In millions)
Change in benefit obligation:
Benefit obligation as of January 1$7,824 $8,363$407 $441
Service cost131 1402 3
Interest cost374 39820 20
Plan participants’ contributions— —3 4
Medicare retiree drug subsidy— —— 1
Lift-out transaction (652)—— —
Actuarial loss (gain)129 (526)11 (14)
Benefits paid(526)(551)(45)(48)
Benefit obligation as of December 31$7,280 $7,824$398 $407
Change in fair value of plan assets:
Fair value of plan assets as of January 1$6,296 $6,879$567 $516
Actual return on plan assets809 (62)71 65
Lift-out transaction (640)—— —
Company contributions28 3021 30
Plan participants’ contributions— —3 4
Benefits paid(526)(551)(45)(48)
Fair value of plan assets as of December 31$5,967 $6,296$617 $567
Funded Status:
Qualified plan$(952)$(1,165)$— $—
Non-qualified plans(361)(363)— —
Funded Status - Net asset (liability) as of December 31 (1)
$(1,313)$(1,528)$219$160
Accumulated benefit obligation$7,047 $7,572 $— $— 
Amounts Recognized in AOCI:
Prior service cost (credit)$1 $2 $1 $1 
(1) The pension net liability is included in “Retirement benefits,” on the Consolidated Balance Sheets. The OPEB net asset is included in “Other” noncurrent assets on the Consolidated Balance Sheets.
Schedule of Target asset allocations for pension and OPEB portfolio
FirstEnergy’s target asset allocations for its pension and OPEB trust portfolios as of December 31, 2025 were as follows:
Target Asset Allocations
Pension OPEB
Equities30 %50 %
Fixed income28.5 %50 %
Alternative investments 5 %— %
Real estate10 %— %
Private - equity and debt funds20 %— %
Cash and derivatives 6.5 %— %
100 %100 %
Schedule of Estimated Future Benefit Payments
Taking into account estimated employee future service, FirstEnergy expects to make the following benefit payments from plan assets and other payments, net of participant contribution.
OPEB
Pension Benefit Payments
Benefit Payments (1)
Subsidy Receipts
(In millions)
2026$517 $40 $1 
2027522 39 1 
2028526 38 — 
2029530 37 — 
2030532 35 — 
Years 2031-20352,660 155 2 
(1) Net of participant contributions.
Pension  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Schedule of Pension investments measured at fair value
The following tables set forth FirstEnergy's pension financial assets that are accounted for at fair value by level within the fair value hierarchy. See Note 10., "Fair Value Measurements," of the Combined Notes to Financial Statements of the Registrants for a description of each level of the fair value hierarchy. There were no significant transfers between levels during 2025 and 2024.
December 31, 2025Asset Allocation
FirstEnergyLevel 1Level 2Level 3Total
(In millions)
Cash and short-term securities$— $402 $— $402 7 %
Public equity1,976 6 — 1,982 33 %
Fixed income— 1,507 — 1,507 25 %
Derivatives(21)18 — (3)— %
Total(1)
$1,955 $1,933 $— $3,888 65 %
Private - equity and debt funds(2)
1,278 22 %
Insurance-linked securities(2)
7 — %
Hedge funds(2)
270 5 %
Real estate funds(2)
498 8 %
Total Investments$5,941 100 %
(1) Excludes $26 million as of December 31, 2025, of receivables, payables, taxes, cash collateral for derivatives and accrued income associated with financial instruments reflected within the fair value table.
(2) NAV used as a practical expedient to approximate fair value.

December 31, 2024Asset Allocation
FirstEnergyLevel 1Level 2Level 3Total
(In millions)
Cash and short-term securities$— $1,173 $— $1,173 19 %
Public equity1,585 5 — 1,590 25 %
Fixed income— 1,425 — 1,425 23 %
Derivatives(95)37 — (58)(1)%
Total(1)
$1,490 $2,640 $— $4,130 66 %
Private - equity and debt funds(2)
1,273 20 %
Insurance-linked securities(2)
39 1 %
Hedge funds(2)
253 4 %
Real estate funds(2)
554 9 %
Total Investments$6,249 100 %
(1) Excludes $47 million as of December 31, 2024, of receivables, payables, taxes and accrued income associated with financial instruments reflected within the fair value table.
(2) NAV used as a practical expedient to approximate fair value.
OPEB  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Schedule of Pension investments measured at fair value
As of December 31, 2025, and 2024, the FirstEnergy OPEB trust investments measured at fair value were as follows:
December 31, 2025Asset Allocation
FirstEnergyLevel 1Level 2Level 3Total
(In millions)
Cash and short-term securities$— $128 $— $128 20 %
Public equity361 — — 361 57 %
Fixed income— 141 — 141 23 %
Total(1)
$361 $269 $— $630 100 %
(1) Excludes $(13) million as of December 31, 2025, of receivables, payables, taxes and accrued income associated with financial instruments reflected within the fair value table.

December 31, 2024Asset Allocation
FirstEnergyLevel 1Level 2Level 3Total
(In millions)
Cash and short-term securities$— $112 $— $112 20 %
Public equity314 — — 314 55 %
Fixed income:— 146 — 146 25 %
Total(1)
$314 $258 $— $572 100 %
(1) Excludes $(5) million as of December 31, 2024, of receivables, payables, taxes and accrued income associated with financial instruments reflected within the fair value table.
v3.25.4
STOCK-BASED COMPENSATION PLANS (Tables)
 12 Months Ended
Dec. 31, 2025
Share-Based Payment Arrangement [Abstract]  
Schedule of Stock-based Compensation Expense
The following table reflects the pre-tax portion of stock-based compensation costs that were charged to expense, including amounts capitalized, and net of amounts capitalized, for the years ended December 31, 2025, 2024 and 2023:
For the Years Ended December 31,
Components of Stock-based Compensation Plan Costs 202520242023
(In millions)
Restricted stock units $35 $32 $39 
Restricted stock4 7 5 
401(k) savings plan39 41 38 
EDCP & DCPD7 6 1 
   Total stock based compensation costs $85 $86 $83 
Stock-based compensation costs, net of amounts capitalized$39 $43 $44 
Schedule of Nonvested Restricted Stock Units Activity
Restricted stock unit activity for the year ended December 31, 2025, was as follows:
Restricted Stock Unit Activity
Shares
(in millions)
Weighted-Average Grant Date Fair Value (per share)
Nonvested as of January 1, 20252.8 $37.32 
Granted in 20251.1 39.94 
Forfeited in 2024(0.4)39.48 
Vested in 2025(1)
(0.6)38.38 
Nonvested as of December 31, 20252.9 $36.38 
(1) Excludes dividend equivalents of approximately 67 thousand shares earned during vesting periodRestricted stock activity for the year ended 2025, was as follows:
Restricted Stock Activity
Shares
(in millions)
Weighted-Average Grant Date Fair Value (per share)
Nonvested as of January 1, 20250.27 $38.29 
Granted in 20250.06 41.98 
Forfeited in 2025(0.01)38.16 
Vested in 2025(0.08)39.71 
Nonvested as of December 31, 20250.24 $38.70 
v3.25.4
TAXES (Tables)
 12 Months Ended
Dec. 31, 2025
Income Tax Disclosure [Abstract]  
Schedule of Provision for Income Taxes (Benefits)
The following table provides the composite of income taxes on income from continuing operations of FirstEnergy for the years ended 2025, 2024 and 2023:

INCOME TAXES ON INCOME FROM CONTINUING OPERATIONS - FIRSTENERGYFor the Years Ended December 31,
202520242023
(In millions)
Currently payable -
Federal$58 $32 $14 
State11 291
69 61 15 
Deferred, net -   
Federal(1)
135 190 279 
State88 130 (24)
223 320 255 
Investment tax credit amortization(4)(4)(3)
Total income taxes on income from continuing operations$288 $377 $267 
(1) Excludes $21 million of federal tax expense associated with discontinued operations for the year ended December 31, 2023.
The following table provides the composite of income taxes of JCP&L for the years ended 2025, 2024 and 2023:

JCP&L (1)
For the Years Ended December 31,
INCOME TAXES:202520242023
(In millions)
Currently receivable -
Federal$(36)$(143)$(7)
State— — (8)
(36)(143)(15)
Deferred, net -
Federal108 200 34 
State35 30 14 
143 230 48 
Total income taxes$107 $87 $33 
(1) Previously issued 2024 and 2023 JCP&L amounts have been revised due to the correction of immaterial errors as discussed in Note 1., "Organization and Basis of Presentation," of the Combined Notes to Financial Statements of the Registrants.
Schedule of Reconciliation of Federal Income Tax Expense at the Federal Statutory Rate to the Total Provision for Income Taxes The following tables present a reconciliation of income tax expense at the U.S. federal statutory tax rate to the actual tax expense from continuing operations for the years ended December 31, 2025, 2024 and 2023:
For the Year Ended December 31, 2025
(In millions) FirstEnergy JCP&L
Amount %Amount%
Income before income taxes$1,559 $413 
Federal statutory income tax$327 21.0 %$87 21.0 %
Federal
Tax credits(5)(0.3)%— — %
Nontaxable and Nondeductible
AFUDC equity income(23)(1.5)%(6)(1.4)%
AFUDC equity depreciation4 0.3 %— — %
Tax related to FE's equity investment in FET13 0.8 %— — %
Changes in valuation allowances3 0.2 %— — %
Other
Excess deferred tax amortization(42)(2.7)%(1)(0.2)%
Remeasurement of excess deferred income taxes(70)(4.5)%— — %
Federal and state related flow-through(37)(2.4)%(2)(0.5)%
Deferred taxes associated with FET equity interest sale6 0.4 %— — %
Other 2 0.1 %— — %
Changes in unrecognized tax benefits1 0.1 %— — %
State and municipal income taxes, net of federal effect (1) (2)
109 7.0 %29 7.0 %
Total income taxes (3)
$288 18.5 %$107 25.9 %
(1) Valuation allowances have been established for certain state NOL carryforwards that reduce deferred tax assets to an amount that will be realized on a more-likely-than-not basis. The net change in the total valuation allowance is included in state income tax, net of federal income tax effect, in the above tables.
(2) Jurisdictions that make up the majority of the Registrants' respective domestic state income taxes, net of federal effect, are Pennsylvania for FirstEnergy and New Jersey for JCP&L.
(3) There were no amounts for the year ended December 31, 2025 at FirstEnergy or JCP&L related to cross-border tax laws, changes in laws or rates, or foreign tax effects.
For the Year Ended December 31, 2024
(In millions) FirstEnergy
JCP&L (4)
Amount%Amount%
Income before income taxes $1,504 $329 
Federal statutory income tax$316 21.0 %$69 21.0 %
Federal
Tax credits(6)(0.4)%— — %
Nontaxable and Nondeductible— %
AFUDC equity income(13)(0.9)%(1)(0.3)%
AFUDC equity depreciation1 0.1 %— — %
Nondeductible SEC and OAG Settlements27 1.8 %— — %
Tax related to FE's equity investment in FET16 1.1 %— — %
Changes in valuation allowances1 0.1 %— — %
Other
Excess deferred tax amortization(52)(3.5)%(4)(1.3)%
Remeasurement of excess deferred income taxes(43)(2.9)%— — %
Federal and state related flow-through(18)(1.2)%— — %
Deductions associated with certain equity investments(19)(1.3)%— — %
Deferred taxes associated with FET equity interest sale6 0.4 %— — %
Other 6 0.4 %— — %
State and municipal income taxes, net of federal effect (1) (2)
155 10.3 %23 7.0 %
Total income taxes (3)
$377 25.1 %$87 26.4 %
(1) Valuation allowances have been established for certain state NOL carryforwards that reduce deferred tax assets to an amount that will be realized on a more-likely-than-not basis. The net change in the total valuation allowance is included in state income tax, net of federal income tax effect, in the above tables.
(2) Jurisdictions that make up the majority of the Registrants' respective domestic state income taxes, net of federal effect, are Pennsylvania and West Virginia for FirstEnergy; and New Jersey for JCP&L.
(3) There were no amounts for the year ended December 31, 2024 at FirstEnergy or JCP&L related to cross-border tax laws, changes in laws or rates, foreign tax effects, or changes in unrecognized tax benefits.
(4) Previously issued 2024 JCP&L amounts have been revised due to the correction of immaterial errors as discussed in Note 1., "Organization and Basis of Presentation," of the Combined Notes to Financial Statements of the Registrants.
For the Year Ended December 31, 2023
(In millions )FirstEnergy
JCP&L (4)
Amount %Amount%
Income from continuing operations, before income taxes$1,464 $158 
Federal statutory income tax$307 21.0 %$33 21.0 %
Federal
Tax credits(6)(0.4)%— — %
Nontaxable and Nondeductible
AFUDC equity income(9)(0.6)%(1)(0.6)%
AFUDC equity depreciation6 0.4 %— — %
Changes in valuation allowances(33)(2.3)%— — %
Other
Excess deferred tax amortization(46)(3.1)%(4)(2.6)%
Federal and state related flow-through(27)(1.8)%— — %
Deferred taxes associated with FET equity interest sale58 4.0 %— — %
Other 9 0.6 %(1)(0.6)%
Changes in unrecognized tax benefits41 2.8 %(28)(17.8)%
State and municipal income taxes, net of federal effect (1) (2)
(33)(2.3)%34 21.5 %
Total income taxes on income from continuing operations$267 18.2 %$33 20.9 %
(1) Valuation allowances have been established for certain state NOL carryforwards at FirstEnergy that reduce deferred tax assets to an amount that will be realized on a more-likely-than-not basis. The net change in the total valuation allowance is included in state income tax, net of federal income tax effect, in the above tables.
(2) Jurisdictions that make up the majority of the Registrants' respective domestic state income taxes, net of federal effect, are Pennsylvania and West Virginia for FirstEnergy; and New Jersey for JCP&L.
(3) There were no amounts for the year ended December 31, 2023 at FirstEnergy or JCP&L related to cross-border tax laws, changes in laws or rates, or foreign tax effects
(4) Previously issued 2023 JCP&L amounts have been revised due to the correction of immaterial errors as discussed in Note 1., "Organization and Basis of Presentation," of the Combined Notes to Financial Statements of the Registrants.
Schedule of Accumulated Deferred Income Taxes
Net accumulated deferred income tax liabilities (assets) as of December 31, 2025 and 2024, are as follows:
FirstEnergyAs of December 31,
(In millions)20252024
Property basis differences$6,579 $6,079 
Pension and OPEB(249)(322)
Regulatory asset/liability732 744 
Loss carryforwards and tax credits(920)(762)
Valuation allowances245 240 
Other(355)(366)
Net accumulated deferred income tax liability$6,032 $5,613 
JCP&L (1)
As of December 31,
(In millions)20252024
Property basis differences$1,330 $1,167 
Pension and OPEB(78)(99)
Regulatory asset/liability366 296 
Loss and credit carryforwards(199)(116)
Nuclear fuel disposal costs(66)(59)
Other(5)3 
Net accumulated deferred income tax liability$1,348 $1,192 
(1) Previously issued 2024 JCP&L amounts have been revised due to the correction of immaterial errors as discussed in Note 1., "Organization and Basis of Presentation," of the Combined Notes to Financial Statements of the Registrants.
Schedule of Pre-tax Net Operating Loss Expiration Period
Expiration Period (FirstEnergy)StateLocal
(In millions)
2026-2030$1,658 $6,161 
2031-20351,168 — 
2036-20401,026 — 
2041-20451,216 — 
Indefinite2,451 — 
$7,519 $6,161 
Schedule of Valuation Allowance Roll Forward
The following table summarizes the changes in valuation allowances on federal, state, and local deferred tax assets related to business interest expense carryforwards and employee compensation deduction limitations under section 162(m), in addition to state and local NOLs discussed above for the years ended December 31, 2025, 2024 and 2023:

FirstEnergy (In millions)202520242023
Beginning of year balance$240 $226 $440 
Charged to income5 14 (214)
Charged to other accounts— — — 
Write-offs— — — 
End of year balance$245 $240 $226 
Schedule of Unrecognized Tax Benefits Roll Forward
The following table summarizes the changes (gross) in uncertain tax positions for the years ended December 31, 2025, 2024 and 2023:
(In millions)FirstEnergyJCP&L
Balance, January 1, 2023$42 $25 
Prior year increases88 — 
Effectively settled with taxing authorities(24)(24)
        Decrease for lapse in statute(1)— 
Balance, December 31, 2023$105 $1 
Prior year increases— — 
Effectively settled with taxing authorities— — 
        Decrease for lapse in statute— — 
Balance, December 31, 2024$105 $1 
Prior years increases— — 
Effectively settled with taxing authorities— — 
        Decrease for lapse in statute— — 
Balance, December 31, 2025$105 $1 
Schedule of Income Taxes Net of Refunds
Income taxes paid, net of refunds, for the years ended December 31, 2025, 2024 and 2023, are as follows:

For the Years Ended December 31,
FirstEnergyJCP&L
(In millions)202520242023202520242023
Federal payments (receipts)
Internal Revenue Service$48 $146 $49 $(15)$(93)$(11)
Total Federal48 146 49 (15)(93)(11)
State & Municipal payments (receipts)
New Jersey— (8)— — (8)— 
Pennsylvania21 21 8 — — — 
Other4 2 1 — — — 
Total State & Municipal25 15 9 — (8)— 
Total Income Taxes Paid (net of Refunds)$73 $161 $58 $(15)$(101)$(11)
Schedule of Details of General Taxes
General tax expense for the years ended December 31, 2025, 2024 and 2023, recognized in continuing operations is summarized as follows:
FirstEnergy (In millions)For the Years Ended December 31,
202520242023
kWh excise$189 $186 $185 
State gross receipts278 247 235 
Real and personal property735 642 615 
Social security and unemployment126 113 113 
Other17 24 16 
Total general taxes$1,345 $1,212 $1,164 

JCP&L (In millions)For the Years Ended December 31,
202520242023
Real and personal property$7 $6 $7 
Social security and unemployment16 15 14 
Total general taxes$23 $21 $21 
v3.25.4
LEASES (Tables)
 12 Months Ended
Dec. 31, 2025
Leases [Abstract]  
Schedule of Components of Lease Expense
The following tables represent FirstEnergy's components of lease expense for the years ended December 31, 2025, 2024 and 2023:
For the Year Ended December 31, 2025
(In millions)VehiclesBuildingsOtherTotal
Operating lease costs(1)
$106 $2 $5 $113 
Finance lease costs:
Amortization of right-of-use assets — 1 2 3 
Interest on lease liabilities — 2 — 2 
Total finance lease cost— 3 2 5 
Total lease cost $106 $5 $7 $118 
(1) Includes $45 million of short-term lease costs.

For the Year Ended December 31, 2024
(In millions)VehiclesBuildingsOtherTotal
Operating lease costs(1)
$82 $3 $6 $91 
Finance lease costs:
Amortization of right-of-use assets 1 1 2 4 
Interest on lease liabilities — 2 — 2 
Total finance lease cost1 3 2 6 
Total lease cost $83 $6 $8 $97 
(1) Includes $35 million of short-term lease costs.

For the Year Ended December 31, 2023
(In millions)VehiclesBuildingsOtherTotal
Operating lease costs(1)
$60 $5 $14 $79 
Finance lease costs:
Amortization of right-of-use assets 4 2 2 8 
Interest on lease liabilities — 5 — 5 
Total finance lease cost4 7 2 13 
Total lease cost $64 $12 $16 $92 
(1) Includes $27 million of short-term lease costs.
The following table represents JCP&L's components of lease expense for the years ended December 31, 2025, 2024 and 2023:
For the Year Ended December 31,
(In millions)202520242023
Operating lease costs(1)
$13 $11 $11 
Finance lease costs:
Amortization of right-of-use assets 1 1 1 
Interest on lease liabilities 1 1 1 
Total finance lease cost2 2 2 
Total lease cost $15 $13 $13 
(1) Includes short-term lease costs of $1 million for the year ended December 31, 2025 and $2 million for the years ended December 31, 2024 and 2023.

Supplemental cash flow information related to FirstEnergy's leases was as follows:
For the Years Ended December 31,
(In millions)202520242023
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases$71 $60 $54 
Operating cash flows from finance leases2 23
Finance cash flows from finance leases2 28
Right-of-use assets obtained in exchange for lease obligations:
Operating leases $104 $69 $13 
Finance leases — — — 

Supplemental cash flow information related to JCP&L's leases was as follows:
For the Years Ended December 31,
(In millions)202520242023
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases$13 $12 $11 
Operating cash flows from finance leases1 11
Finance cash flows from finance leases2 11
Right-of-use assets obtained in exchange for lease obligations:
Operating leases $24 $10 $3 
Finance leases — — — 
Maturities of FirstEnergy's lease liabilities as of December 31, 2025, were as follows:
(In millions)Operating LeasesFinance LeasesTotal
2026$72 $4 $76 
202761 3 64 
202858 4 62 
202943 — 43 
203029 — 29 
Thereafter 85 — 85 
Total lease payments(1)
348 11 359 
Less imputed interest 61 1 62 
Total net present value$287 $10 $297 
(1) Operating lease payments for certain leases are offset by sublease receipts of $6 million over 7 years.

Maturities of JCP&L's lease liabilities as of December 31, 2025, were as follows:
(In millions)Operating LeasesFinance LeasesTotal
2026$13 $2 $15 
202711 2 13 
202813 — 13 
20299 — 9 
20307 — 7 
Thereafter 42 — 42 
Total lease payments(1)
95 4 99 
Less imputed interest 28 — 28 
Total net present value$67 $4 $71 
(1) Operating lease payments for certain leases are offset by sublease receipts of $5 million over 7 years.
Schedule of Assets and Liabilities, Lessee
Lease terms and discount rates for FirstEnergy were as follows:
As of December 31,
202520242023
Weighted-average remaining lease terms (years)
Operating leases 6.405.625.93
Finance leases 12.7912.3812.26
Weighted-average discount rate(1)
Operating leases 5.16 %5.00 %4.51 %
Finance leases 16.24 %15.39 %14.73 %
(1) When an implicit rate is not readily determinable, an incremental borrowing rate is utilized, determining the present value of lease payments. The rate is determined based on expected term and information available at the commencement date.
Lease terms and discount rates for JCP&L were as follows:
As of December 31,
202520242023
Weighted-average remaining lease terms (years)
Operating leases 9.396.006.60
Finance leases 12.159.6010.30
Weighted-average discount rate(1)
Operating leases 5.83 %5.76 %5.68 %
Finance leases 15.94 %16.07 %16.15 %
(1) When an implicit rate is not readily determinable, an incremental borrowing rate is utilized, determining the present value of lease payments. The rate is determined based on expected term and information available at the commencement date.

Supplemental balance sheet information related to FirstEnergy's leases was as follows:
As of December 31,
(In millions)Financial Statement Line Item20252024
Assets
Operating lease(1)
Deferred charges and other assets$276 $228 
Finance lease(2)
Property, plant and equipment31 32 
Total leased assets $307 $260 
Liabilities
Current:
Operating Other current liabilities$60 $51 
Finance Currently payable long-term debt3 3 
Noncurrent:
Operating Other noncurrent liabilities227 192 
Finance Long-term debt and other long-term obligations7 9 
Total leased liabilities $297 $255 
(1) Operating lease assets are recorded net of accumulated amortization of $217 million and $174 million as of December 31, 2025 and 2024, respectively.
(2) Finance lease assets are recorded net of accumulated amortization of $17 million and $14 million as of December 31, 2025 and 2024, respectively.
Supplemental balance sheet information related to JCP&L's leases was as follows:
As of December 31,
(In millions)Financial Statement Line Item20252024
Assets
Operating lease(1)
Deferred charges and other assets$58 $43 
Finance lease(2)
Property, plant and equipment6 6 
Total leased assets $64 $49 
Liabilities
Current:
Operating Other current liabilities$11 $11 
Finance Currently payable long-term debt2 1 
Noncurrent:
Operating Other noncurrent liabilities56 43 
Finance Long-term debt and other long-term obligations2 4 
Total leased liabilities $71 $59 
(1) Operating lease assets are recorded net of accumulated amortization of $36 million and $30 million as of December 31, 2025 and 2024, respectively.
(2) Finance lease assets are recorded net of accumulated amortization of $6 million and $5 million as of December 31, 2025 and 2024, respectively.
Schedule of Maturity of Operating Lease Liabilities
Maturities of FirstEnergy's lease liabilities as of December 31, 2025, were as follows:
(In millions)Operating LeasesFinance LeasesTotal
2026$72 $4 $76 
202761 3 64 
202858 4 62 
202943 — 43 
203029 — 29 
Thereafter 85 — 85 
Total lease payments(1)
348 11 359 
Less imputed interest 61 1 62 
Total net present value$287 $10 $297 
(1) Operating lease payments for certain leases are offset by sublease receipts of $6 million over 7 years.

Maturities of JCP&L's lease liabilities as of December 31, 2025, were as follows:
(In millions)Operating LeasesFinance LeasesTotal
2026$13 $2 $15 
202711 2 13 
202813 — 13 
20299 — 9 
20307 — 7 
Thereafter 42 — 42 
Total lease payments(1)
95 4 99 
Less imputed interest 28 — 28 
Total net present value$67 $4 $71 
(1) Operating lease payments for certain leases are offset by sublease receipts of $5 million over 7 years.
Schedule of Maturity of Finance Lease Liabilities
Maturities of FirstEnergy's lease liabilities as of December 31, 2025, were as follows:
(In millions)Operating LeasesFinance LeasesTotal
2026$72 $4 $76 
202761 3 64 
202858 4 62 
202943 — 43 
203029 — 29 
Thereafter 85 — 85 
Total lease payments(1)
348 11 359 
Less imputed interest 61 1 62 
Total net present value$287 $10 $297 
(1) Operating lease payments for certain leases are offset by sublease receipts of $6 million over 7 years.

Maturities of JCP&L's lease liabilities as of December 31, 2025, were as follows:
(In millions)Operating LeasesFinance LeasesTotal
2026$13 $2 $15 
202711 2 13 
202813 — 13 
20299 — 9 
20307 — 7 
Thereafter 42 — 42 
Total lease payments(1)
95 4 99 
Less imputed interest 28 — 28 
Total net present value$67 $4 $71 
(1) Operating lease payments for certain leases are offset by sublease receipts of $5 million over 7 years.
v3.25.4
ASSET RETIREMENT OBLIGATIONS (Tables)
 12 Months Ended
Dec. 31, 2025
Asset Retirement Obligation [Abstract]  
Schedule of Change in Asset Retirement Obligation
The following table summarizes the changes to the ARO balances as of December 31, 2025, and 2024.
FirstEnergy JCP&L
(In millions)
Balance, January 1, 2024
$209 $7 
Changes in timing and amount of estimated cash flows131 — 
Liabilities incurred95 — 
Liabilities settled (4)— 
Accretion24 1 
Balance, December 31, 2024
455 8 
Changes in timing and amount of estimated cash flows(51)— 
Liabilities incurred1 — 
Liabilities settled (1)
(154)— 
Accretion26 — 
Balance, December 31, 2025
$277 $8 
(1) FirstEnergy amounts include the transfer of the McElroy’s Run CCR impoundment facility as well as the adjacent dry landfill and related remediation obligations to a subsidiary of IDA Power, LLC, as further discussed below.
v3.25.4
FAIR VALUE MEASUREMENTS (Tables)
 12 Months Ended
Dec. 31, 2025
Fair Value Disclosures [Abstract]  
Schedule of Assets and Liabilities Measured on Recurring Basis
The following tables set forth the recurring assets and liabilities that are accounted for at fair value by level within the fair value hierarchy:
December 31, 2025December 31, 2024
Level 1Level 2Level 3TotalLevel 1Level 2Level 3Total
Assets(In millions)
Derivative assets FTRs(1)
$— $— $21 $21 $— $— $7 $7 
Equity securities2 — — 2 2 — — 2 
U.S. state debt securities(2)
— 280 — 280 — 276 — 276 
Cash, cash equivalents and restricted cash(3)
99 — — 99 154 — — 154 
Other(4)
— 56 — 56 — 45 — 45 
Total assets$101 $336 $21 $458 $156 $321 $7 $484 
Liabilities
Derivative liabilities FTRs(1)
$— $— $(1)$(1)$— $— $— $— 
Total liabilities$— $— $(1)$(1)$— $— $— $— 
Net assets (liabilities)$101 $336 $20 $457 $156 $321 $7 $484 
(1) Contracts are subject to regulatory accounting treatment and changes in market values do not impact earnings.
(2) Related to JCP&L’s investments held in the spent nuclear fuel disposal trusts, see below.
(3) Restricted cash of $42 million and $43 million as of December 31, 2025 and 2024, respectively, primarily relates to cash collected from MP, PE and the Ohio Companies' customers that is specifically used to service debt of their respective funding companies. See Note 11., "Capitalization,” of the Combined Notes to Financial Statements of the Registrants for additional information.
(4) Primarily consists of short-term investments, of which $17 million and $6 million as of December 31, 2025, and December 31, 2024, respectively, are held by JCP&L.
Schedule of Amortized Cost Basis, Unrealized Gains and Losses and Fair Values of Investments in Available-for-sale Securities
The following table summarizes the amortized cost basis, unrealized gains, unrealized losses and fair values of investments held in nuclear fuel disposal trusts as of December 31, 2025 and 2024:
December 31, 2025(1)
December 31, 2024(2)
Cost BasisUnrealized GainsUnrealized LossesFair ValueCost BasisUnrealized GainsUnrealized LossesFair Value
(In millions)
Debt securities$290 $2 $(12)$280 $299 $— $(23)$276 
(1) Excludes short-term cash investments of $17 million as of December 31, 2025.
(2) Excludes short-term cash investments of $6 million as of December 31, 2024.
Schedule of Proceeds from the Sale of Investments in Available-for-sale Debt Securities
Proceeds from the sale of investments in AFS debt securities, realized gains and losses on those sales and interest and dividend income for the years ended December 31, 2025, 2024 and 2023, were as follows for the Registrants:
For the Years Ended December 31,
202520242023
(In millions)
Sale Proceeds$102 $121 $38 
Realized Gains1 — — 
Realized Losses(12)(15)(3)
Interest and Dividend Income13 13 12 
Schedule of Fair Value and Related Carrying Amounts of Long-term Debt The following table provides the approximate fair value and related carrying amounts of long-term debt, which excludes finance lease obligations and net unamortized debt issuance costs, unamortized fair value adjustments, premiums and discounts as of December 31, 2025 and 2024:
As of December 31
FirstEnergy20252024
(In millions)
Carrying Value$26,390 $23,594 
Fair Value$25,756 $22,128 

As of December 31
JCP&L20252024
(In millions)
Carrying Value$3,050 $2,350 
Fair Value$3,059 $2,284 
v3.25.4
CAPITALIZATION (Tables)
 12 Months Ended
Dec. 31, 2025
Capitalization, Long-Term Debt and Equity [Abstract]  
Schedule of Dividends Declared and Paid Dividends declared and paid per share of FE common stock during 2025 and 2024 were as follows:
Dividends Declared Dividends Paid
2025202420252024
Q1 $0.445 $0.425 $0.425 $0.410 
Q2— — 0.445 0.425 
Q30.890 0.850 0.445 0.425 
Q40.445 0.425 0.445 0.425 
Total $1.780 $1.700 $1.760 $1.685 
Schedule of Preferred and Preference Stock Authorizations
FirstEnergy and certain of its subsidiaries are authorized to issue preferred stock and preference stock as of December 31, 2025, as follows:
Preferred StockPreference Stock
Shares AuthorizedPar ValueShares AuthorizedPar Value
FE5,000,000 $100   
OE6,000,000 $100 8,000,000 no par
OE8,000,000 $25   
CEI4,000,000 no par3,000,000 no par
TE3,000,000 $100 5,000,000 $25 
TE12,000,000 $25 
JCP&L15,600,000 no par
MP940,000 $100 
PE10,000,000 $0.01 
Schedule of Long-term Debt and Other Long-term Obligations
The following tables present outstanding long-term debt and finance lease obligations for FirstEnergy and JCP&L as of December 31, 2025 and 2024:

FirstEnergyAs of December 31, 2025As of December 31,
Maturity DateInterest Rate20252024
(In millions)
FMBs and secured notes - fixed rate2026-2059
2.650% - 8.250%
$5,214 $4,963 
Unsecured notes - fixed rate2026-2050
2.250% - 6.875%
21,176 18,631 
Finance lease obligations10 12 
Unamortized debt discounts(20)(14)
Unamortized debt issuance costs(150)(122)
Unamortized fair value adjustments1 3 
Currently payable long-term debt(723)(977)
Total long-term debt and other long-term obligations$25,508 $22,496 

JCP&LAs of December 31, 2025As of December 31,
Maturity DateInterest Rate20252024
(In millions)
Unsecured notes - fixed rate2029-2037
2.750% - 6.400%
$3,050 $2,350 
Finance lease obligations4 5 
Unamortized debt premiums/discounts(7)(4)
Unamortized debt issuance costs(22)(11)
Currently payable long-term debt(2)(1)
Total long-term debt and other long-term obligations$3,023 $2,339 
FirstEnergy had the following redemptions and issuances during the twelve months ended December 31, 2025:

CompanyTypeRedemption/Issuance DateInterest RateMaturityAmount
(In millions)		Description
Redemptions
FESenior Unsecured NotesMarch, 20252.05%2025$300FE redeemed unsecured notes that became due.
TrAILSenior Unsecured NotesMay, 20253.76%2025$75TrAIL redeemed unsecured notes that became due.
TrAILSenior Unsecured NotesJune, 20253.85%2025$550TrAIL redeemed unsecured notes that became due.
FESenior Unsecured Convertible NotesJune, 20254.00%2026$1,206
FE repurchased approximately $1,206 million of the principal amount of its 2026 Convertible Notes for $1,225 million, including a premium of approximately $19 million.
JCP&LSenior Unsecured NotesOctober, 20254.30%2026$650
On October 16, 2025, JCP&L redeemed $650 million of 4.30% senior notes due 2026.
FESenior Unsecured NotesDecember, 20251.60%2026$300
On December 31, 2025, FE redeemed $300 million of 1.60% senior notes due 2026.
Issuances
TrAILSenior Unsecured NotesApril, 20255.00%2031$600Proceeds were used to redeem senior notes that came due in 2025, to refinance existing debt, for working capital, and for other general corporate purposes.
ATSISenior Unsecured NotesMay, 20255.00%2030$225Proceeds were used to refinance existing debt, to finance capital expenditures, for working capital, and for other general corporate purposes.
OESenior Unsecured NotesMay, 20254.95%2029$300Proceeds were used to refinance existing debt, to finance capital expenditures, for working capital, and for other general corporate purposes.
MAITSenior Unsecured NotesJune, 20255.00%2031$200Proceeds were used to refinance existing debt, to finance capital expenditures, for working capital, and for other general corporate purposes.
PEFMBsJune, 20255.00%2030$200Proceeds were used to refinance existing debt, to finance capital expenditures, for working capital, and for other general corporate purposes.
TESenior Secured NotesJune, 20255.18%2030$100Proceeds were used to refinance existing debt, to finance capital expenditures, for working capital, and for other general corporate purposes.
FE Senior Unsecured Convertible NotesJune, 20253.63%2029$1,350Proceeds were used to refinance existing debt, to repurchase a portion of its 2026 Convertible Notes, and for other general corporate purposes.
FE Senior Unsecured Convertible NotesJune, 20253.88%2031$1,150Proceeds were used to refinance existing debt, to repurchase a portion of its 2026 Convertible Notes, and for other general corporate purposes.
FETSenior Unsecured NotesAugust, 20254.75%2033$450Proceeds were used to refinance existing debt, to finance capital expenditures, for working capital, and for other general corporate purposes.
JCP&LSenior Unsecured NotesSeptember, 2025 4.15%2029$350
Proceeds were used to refinance existing debt, including the repayment of the remaining $650 million aggregate principal amount of JCP&L’s 4.30% senior notes due 2026, to finance capital expenditures, and for other general corporate purposes.
JCP&LSenior Unsecured NotesSeptember, 20254.40%2031$500
Proceeds were used to refinance existing debt, including the repayment of the remaining $650 million aggregate principal amount of JCP&L’s 4.30% senior notes due 2026, to finance capital expenditures, and for other general corporate purposes.
JCP&LSenior Unsecured NotesSeptember, 20255.15%2036$500
Proceeds were used to refinance existing debt, including the repayment of the remaining $650 million aggregate principal amount of JCP&L’s 4.30% senior notes due 2026, to finance capital expenditures, and for other general corporate purposes.
(1) Excludes principal payments on securitized bonds.
Schedule of Maturities of Long-term Debt
The following table presents scheduled debt repayments or debt that has been noticed for redemption for outstanding long-term debt, excluding finance leases, fair value purchase accounting adjustments and unamortized debt discounts and premiums, for the next five years as of December 31, 2025.

FirstEnergy (In millions)
20262027202820292030
Scheduled debt repayments $720$2,003$2,453$3,064$2,456

JCP&L (In millions)20262027202820292030
Scheduled debt repayments $—$—$—$350$—
v3.25.4
SHORT-TERM BORROWINGS AND BANK LINES OF CREDIT (Tables)
 12 Months Ended
Dec. 31, 2025
Debt Disclosure [Abstract]  
Schedule of Interest Rate
Average Interest RatesRegulated Companies’ Money PoolUnregulated Companies’ Money Pool
2025202420252024
For the Years Ended December 31, 4.51 %5.74 %4.89 %6.44 %
v3.25.4
REGULATORY MATTERS (Tables)
 12 Months Ended
Dec. 31, 2025
Regulated Operations [Abstract]  
Schedule of Distribution Rate Orders
The following table summarizes the key terms of state base rate orders in effect for the Electric Companies as of December 31, 2025:
CompanyRates Effective For CustomersAllowed Debt/Equity Capital StructureAllowed ROE
CEI (1)
May 2009
51%/ 49%
10.5%
FE PA
January 2025
Settled(2)
Settled(2)
MPMarch 2024
Settled(2)
9.8%
JCP&LJune 2024
48.1% / 51.9%
9.6%
OE (1)
January 2009
51% /49%
10.5%
PE (West Virginia)March 2024
Settled(2)
9.8%
PE (Maryland)October 2023
47% / 53%
9.5%
TE (1)
January 2009
51% / 49%
10.5%
(1) On November 19, 2025, the PUCO issued an order in the Ohio Companies’ base rate case that authorized a capital structure of 48.8% debt and 51.2% equity, and an ROE of 9.63%. New rates reflecting this order were not yet in effect as of December 31, 2025.
(2) Commission-approved settlement agreements did not disclose allowed debt/equity and/or ROE rates.
The following table summarizes the key terms of FERC rate orders in effect for transmission customer billings for FirstEnergy's transmission owner entities as of December 31, 2025:
CompanyAllowed Debt/Equity Capital StructureAllowed ROE
ATSIActual (13-month average)
9.88%(1)
JCP&L
Actual (13-month average)10.2%
MP
Lower of Actual (13-month average) or 56% equity
10.45%
PE
Lower of Actual (13-month average) or 56% equity
10.45%
KATCo(2)
49.3% equity(3)
10.45%
MAIT
Lower of Actual (13-month average) or 60% equity
10.3%
TrAILActual (year-end)
12.7%(4) / 11.7%(5)
(1) Reflects a 0.5% reduction to the 10.38% approved ROE due to the January 2025 Sixth Circuit ruling eliminating the 50 basis point adder associated with RTO membership (see Transmission ROE Incentive).
(2) On January 1, 2024, WP transferred certain of its Pennsylvania-based transmission assets to KATCo.
(3) Capital structure will convert to an actual (13-month average) in January 2027.
(4) TrAIL the Line and Black Oak Static Var Compensator.
(5) All other projects.
v3.25.4
COMMITMENTS, GUARANTEES AND CONTINGENCIES (Tables)
 12 Months Ended
Dec. 31, 2025
Commitments and Contingencies Disclosure [Abstract]  
Schedule of Potential Collateral Obligations The maximum potential amount of future payments FirstEnergy and its subsidiaries could be required to make under these guarantees as of December 31, 2025, was approximately $1.1 billion, as summarized below:
Guarantees and Other AssurancesMaximum Exposure
 (In millions)
FE's Guarantees on Behalf of its Consolidated Subsidiaries
Deferred compensation arrangements$395 
Vehicle leases75 
McElroy Run transfer129 
Other15 
 614 
FE's Guarantees on Other Assurances
Surety Bonds161 
Deferred compensation arrangements93 
LOCs185 
 439 
Total Guarantees and Other Assurances$1,053 
The maximum potential amount of future payments JCP&L could be required to make under these guarantees as of December 31, 2025, was $48 million, as summarized below:
Guarantees and Other AssurancesMaximum Exposure
 (In millions)
Guarantees on Other Assurances
Surety Bonds$20 
LOCs28 
Total Guarantees and Other Assurances$48 
The following table discloses the potential additional credit rating contingent contractual collateral obligations as of December 31, 2025:
Potential Collateral ObligationsElectric Companies and Transmission CompaniesFETotal
(In millions)
Contractual Obligations for Additional Collateral
Upon Further Downgrade$99 $1 $100 
Surety Bonds (collateralized amount)(1)
113 153 266 
Total Exposure from Contractual Obligations$212 $154 $366 
(1) Surety Bonds are not tied to a credit rating. Surety Bonds' impact assumes maximum contractual obligations, which is ordinarily 100% of the face amount of the surety bond except with respect to $22 million of surety obligations for which the collateral obligation is capped at 60% of the face amount, and typical obligations require 30 days to cure.
The following table discloses the potential additional credit rating contingent contractual collateral obligations as of December 31, 2025:
Potential Collateral ObligationsJCP&L
(In millions)
Contractual Obligations for Additional Collateral
Upon Further Downgrade$67 
Surety Bonds (collateralized amount)(1)
20 
Total Exposure from Contractual Obligations$87 
(1) Surety Bonds are not tied to a credit rating. Surety Bonds' impact assumes maximum contractual obligations, which is ordinarily 100% of the face amount of the surety bond except with respect to $1 million of surety obligations for which the collateral obligation is capped at 60% of the face amount, and typical obligations require 30 days to cure.
v3.25.4
SEGMENT INFORMATION (Tables)
 12 Months Ended
Dec. 31, 2025
Segment Reporting [Abstract]  
Schedule of Segment Financial Information
Financial information for FirstEnergy’s business segments and reconciliations to consolidated amounts is presented below:
(In millions)DistributionIntegratedStand-Alone TransmissionTotal Reportable SegmentsCorporate/OtherReconciling AdjustmentsFirstEnergy Consolidated
For the Years Ended
December 31, 2025
External revenues$7,508 $5,678 $1,886 $15,072 $18 $— $15,090 
Internal revenues39 5 19 63 — (63)— 
Total revenues$7,547 $5,683 $1,905 $15,135 $18 $(63)$15,090 
Other operating expenses(1)
2,479 1,416 328 4,223 (90)(11)4,122 
Depreciation(1)
655 562 369 1,586 78 — 1,664 
Amortization (deferral) of regulatory assets, net(103)(12)6 (109)— — (109)
Ohio settlement charges275 — — 275 — — 275 
Equity method investment earnings, net— — — — — — — 
Interest expense(1)
399 284 322 1,005 338 (126)1,217 
Income taxes (benefits)(1)
74 190 99 363 (75)— 288 
Other expense (income) items(2)
3,680 2,655 424 6,759 3 126 6,888 
Earnings (losses) attributable to FE from continuing operations363 588 357 1,308 (288)— 1,020 
Cash Flows from Investing Activities
Capital investments$1,344 $1,842 $1,601 $4,787 $(82)$— $4,705 
December 31, 2024
External revenues$6,824 $4,871 $1,768 $13,463 $9 $— $13,472 
Internal revenues39 5 19 63 — (63)— 
Total revenues$6,863 $4,876 $1,787 $13,526 $9 $(63)$13,472 
Other operating expenses(1)
2,378 1,254 347 3,979 75 (10)4,044 
Depreciation(1)
648 521 336 1,505 76 — 1,581 
Amortization (deferral) of regulatory assets, net(171)(66)6 (231)— — (231)
Equity method investment earnings, net— — — — 58 — 58 
Interest expense(1)
432 262 275 969 360 (185)1,144 
Income taxes (benefits)(1)
135 153 173 461 (84)— 377 
Other expense (income) items(2)
2,817 2,217 356 5,390 62 185 5,637 
Earnings (losses) attributable to FE from continuing operations624 535 294 1,453 (475)— 978 
Cash Flows from Investing Activities
Capital investments$1,130 $1,542 $1,266 $3,938 $92 $— $4,030 
December 31, 2023
External revenues$6,813 $4,315 $1,731 $12,859 $11 $— $12,870 
Internal revenues41 5 17 63 — (63)— 
Total revenues$6,854 $4,320 $1,748 $12,922 $11 $(63)$12,870 
Other operating expenses(1)
2,129 1,156 338 3,623 (34)(10)3,579 
Depreciation(1)
620 462 304 1,386 75 — 1,461 
Amortization (deferral) of regulatory assets, net(259)(10)8 (261)— — (261)
Equity method investment earnings, net— — — — 175 — 175 
Interest expense(1)
390 257 245 892 340 (108)1,124 
Income taxes (benefits)(1)
147 37 146 330 (63)— 267 
Other expense (income) items(2)
3,240 2,118 308 5,666 (22)108 5,752 
Earnings (losses) attributable to FE from continuing operations587 300 399 1,286 (163)— 1,123 
Cash Flows from Investing Activities
Capital investments$936 $1,212 $1,093 $3,241 $115 $— $3,356 
DistributionIntegratedStand-Alone TransmissionTotal Reportable SegmentsCorporate/OtherReconciling AdjustmentsFirstEnergy Consolidated
(In millions)
As of December 31, 2025
Total Assets$20,653 $20,352 $14,903 $55,908 $1,793 $(1,797)$55,904 
Total Goodwill$3,222 $1,953 $443 $5,618 $— $— $5,618 
As of December 31, 2024
Total Assets$19,949 $18,637 $13,528 $52,114 $1,975 $(2,045)$52,044 
Total Goodwill $3,222 $1,953 $443 $5,618 $— $— $5,618 
(1) FirstEnergy considers this line to be a significant expense.
(2) Consists of Fuel, Purchased power, General taxes, Ohio settlement charges, Impairment of assets, Debt redemption costs, Miscellaneous income, net, Capitalized financing costs, Pension and OPEB mark-to-market adjustments, and Income attributable to noncontrolling interest.
Financial information for JCP&L’s reportable segments and reconciliations are presented below:
(In millions)
For the Years Ended
DistributionTransmissionTotal Reportable
Segments		Reconciling AdjustmentsJCP&L
December 31, 2025
External revenues$2,379 $259 $2,638 $— $2,638 
Internal revenues175 — 175 (175)— 
Total revenues$2,554 $259 $2,813 $(175)$2,638 
Other operating expenses(1)
791 64 855 (175)680 
Depreciation(1)
209 54 263 — 263 
Deferral of regulatory assets, net(134)— (134)— (134)
Interest expense - non-affiliates(1)
98 34 132 — 132 
Interest expense - affiliates(1)
6 — 6 — 6 
Income taxes71 36 107 — 107 
Other expense (income) items(2)
1,309 (31)1,278 — 1,278 
Net Income204 102 306 — 306 
Cash Flows from Investing Activities:
Capital investments$454 $651 $1,105 $— 1,105 
(In millions)
For the Years Ended
Distribution (3)
TransmissionTotal Reportable
Segments		Reconciling AdjustmentsJCP&L
December 31, 2024
External revenues$2,073 $242 $2,315 $— $2,315 
Internal revenues152 — 152 (152)— 
Total revenues$2,225 $242 $2,467 $(152)$2,315 
Other operating expenses(1)
745 61 806 (152)654 
Depreciation(1)
203 46 249 — 249 
Deferral of regulatory assets, net(124)— (124)— (124)
Interest expense - non-affiliates(1)
75 22 97 — 97 
Interest expense - affiliates(1)
20 — 20 — 20 
Income taxes52 35 87 — 87 
Other expense (income) items(2)
1,100 (10)1,090 — 1,090 
Net Income154 88 242 — 242 
Cash Flows from Investing Activities:
Capital investments$360 $519 $879 $— 879 
(In millions)
For the Years Ended
Distribution (3)
TransmissionTotal Reportable
Segments		Reconciling AdjustmentsJCP&L
December 31, 2023
External revenues$1,823 $204 $2,027 $— $2,027 
Internal revenues111 — 111 (111)— 
Total revenues$1,934 $204 $2,138 $(111)$2,027 
Other operating expenses(1)
601 65 666 (111)555 
Depreciation(1)
190 41 231 — 231 
Deferral of regulatory assets, net(67)— (67)— (67)
Interest expense - non-affiliates(1)
86 24 110 — 110 
Interest expense - affiliates(1)
14 — 14 — 14 
Income taxes11 22 33 — 33 
Other expense (income) items(2)
1,036 (10)1,026 — 1,026 
Net Income63 62 125 — 125 
Cash Flows from Investing Activities:
Capital investments$232 $401 $633 $— 633 
As of December 31, 2025
Total assets$7,941 $3,168 $11,109 $— $11,109 
Total goodwill$1,213 $598 $1,811 $— $1,811 
As of December 31, 2024
Total assets (3)
$7,198 $2,715 $9,913 $— $9,913 
Total goodwill$1,213 $598 $1,811 $— $1,811 
(1) JCP&L considers this line to be a significant expense.
(2) Consists of Purchased power, General taxes, Miscellaneous income, net, Capitalized financing costs, and Pension and OPEB mark-to-market adjustments.
(3) Previously issued 2024 and 2023 JCP&L amounts have been revised due to the correction of immaterial errors as discussed in Note 1., "Organization and Basis of Presentation," of the Combined Notes to Financial Statements of the Registrants.
v3.25.4
TRANSACTIONS WITH AFFILIATES (Tables)
 12 Months Ended
Dec. 31, 2025
Related Party Transactions [Abstract]  
Schedule of Transactions with Affiliated Companies
The affiliated company transactions for JCP&L for the years ended December 31, 2025, 2024 and 2023 are as follows:
For the Years Ended December 31,
202520242023
(In millions)
Revenues$1 $1 $1 
Expenses:
FESC support services(1)
180 166 174 
Other affiliate support services(1)
13 26 9 
Interest income 1 — — 
Interest expense6 20 14 
(1) Includes amounts capitalized of $77 million, $74 million and $61 million for 2025, 2024 and 2023, respectively.
v3.25.4
REVISION OF PREVIOUSLY ISSUED QUATERLY FINANCIAL STATEMENTS (Unaudited) (Tables)
 12 Months Ended
Dec. 31, 2025
Accounting Changes and Error Corrections [Abstract]  
Schedule of Error Corrections and Prior Period Adjustments
JCP&L Annual Statements of Income and Comprehensive Income

For the Year Ended December 31, 2024For the Year Ended December 31, 2023
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
Deferral of regulatory assets, net$(135)$11 $(124)$(74)$7 $(67)
Other operating expenses656 (2)654 555 — 555 
Total operating expenses 1,946 9 1,955 1,770 7 1,777 
Operating income369 (9)360 257 (7)250 
Income before income taxes338 (9)329 165 (7)158 
Income taxes90 (3)87 35 (2)33 
Net income248 (6)242 130 (5)125 
Comprehensive income 249 (6)243 130 (5)125 

JCP&L Annual Balance Sheets
As of December 31, 2024As of December 31, 2023
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
PP&E - In service$8,697 $34 $8,731 $8,278 $10 $8,288 
Accumulated provision for depreciation 2,409 30 2,439 2,365 8 2,373 
PP&E Excluding CWIP6,288 4 6,292 5,913 2 5,915 
Total PP&E6,908 4 6,912 6,388 2 6,390 
Regulatory assets/(liabilities)265 (18)247 (48)(8)(56)
Total investments and other noncurrent assets2,640 (18)2,622 2,330 — 2,330 
Total assets 9,927 (14)9,913 9,100 2 9,102 
Accumulated deferred income taxes, net1,196 (4)1,192 957 (2)955 
Total noncurrent liabilities4,605 (4)4,601 3,717 6 3,723 
Total liabilities4,950 (4)4,946 4,968 6 4,974 
Retained earnings 1,322 (10)1,312 1,224 (4)1,220 
Total common stockholder's equity4,977 (10)4,967 4,132 (4)4,128 

JCP&L Annual Statements of Common Stockholder's Equity
For the Years Ended December 31, 2024 and 2023
(In millions)As Reported AdjustmentAs Revised
Balance, January 1, 2023$3,967 $1 $3,968 
Net income130 (5)125 
Balance, December 31, 20234,132 (4)4,128 
Net income248 (6)242 
Balance, December 31, 20244,977 (10)4,967 
JCP&L Annual Statements of Cash Flows
For the Year Ended
December 31, 2024		For the Year Ended
December 31, 2023
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income$248 $(6)$242 $130 $(5)$125 
Adjustments to reconcile net income to net cash from operating activities-
Depreciation, amortization and impairments161 11 172 145 7 152 
Deferred income taxes and investment tax credits, net233 (3)230 50 (2)48 
Net cash provided from operating activities607 2 609 264 — 264 
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital investments$(877)$(2)$(879)$(633)$— $(633)
Net cash used for investing activities(947)(2)(949)(690)— (690)
Net change in cash, cash equivalents, and restricted cash$— $— $— $— $— $— 
A summary of the corrections to the impacted financial statement line items to JCP&L’s previously issued unaudited quarterly Statements of Income and Comprehensive Income, Balance Sheets, Statements of Cash Flows and the Statements of Common Stockholder’s Equity are as follows:
JCP&L Interim Statements of Income and Comprehensive Income
For the Three Months Ended March 31, 2025For the Three Months Ended March 31, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
Deferral of regulatory assets, net$(22)$2 $(20)$(39)$2 $(37)
Other operating expenses145 — 145 187 (1)186 
Total operating expenses492 2 494 462 1 463 
Operating income74 (2)72 4 (1)3 
Income before income taxes65 (2)63 (12)(1)(13)
Income taxes16 — 16 (4)— (4)
Net income (loss)49 (2)47 (8)(1)(9)
Comprehensive income49 (2)47 (8)(1)(9)

For the Three Months Ended June 30, 2025For the Six Months Ended June 30, 2025
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
Deferral of regulatory assets, net$(14)$2 $(12)$(36)$4 $(32)
Other operating expenses133 4 137 278 4 282 
Total operating expenses493 6 499 985 8 993 
Operating income99 (6)93 173 (8)165 
Income before income taxes88 (6)82 153 (8)145 
Income taxes22 (2)20 38 (2)36 
Net income66 (4)62 115 (6)109 
Comprehensive income66 (4)62 115 (6)109 
For the Three Months Ended June 30, 2024For the Six Months Ended June 30, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
Deferral of regulatory assets, net$(34)$4 $(30)$(73)$5 $(68)
Other operating expenses158 (1)157 345 (2)343 
Total operating expenses458 3 461 920 3 923 
Operating income99 (3)96 103 (3)100 
Income before income taxes78 (3)75 66 (3)63 
Income taxes21 (1)20 17 (1)16 
Net income57 (2)55 49 (2)47 
Comprehensive income57 (2)55 49 (2)47 

For the Three Months Ended
September 30, 2025		For the Nine Months Ended
September 30, 2025
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
Amortization (deferral) of regulatory assets, net$11 $2 $13 $(25)$6 $(19)
Other operating expenses158 — 158 436 4 440 
Total operating expenses692 2 694 1,677 10 1,687 
Operating income172 (2)170 345 (10)335 
Income before income taxes160 (2)158 313 (10)303 
Income taxes41 (1)40 79 (3)76 
Net income119 (1)118 234 (7)227 
Comprehensive income119 (1)118 234 (7)227 
For the Three Months Ended
September 30, 2024		For the Nine Months Ended
September 30, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
Amortization (deferral) of regulatory assets, net$(25)$2 $(23)$(98)$8 $(90)
Other operating expenses179 1 180 524 (1)523 
Total operating expenses605 3 608 1,525 7 1,532 
Operating income160 (3)157 263 (7)256 
Income before income taxes150 (3)147 216 (7)209 
Income taxes41 (1)40 58 (2)56 
Net income109 (2)107 158 (5)153 
Comprehensive income109 (2)107 158 (5)153 

JCP&L Interim Balance Sheets
As of March 31, 2025As of March 31, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
PP&E - In service$8,807 $34 $8,841 $8,340 $12 $8,352 
Accumulated provision for depreciation2,415 30 2,445 2,371 8 2,379 
PP&E Excluding CWIP6,392 4 6,396 5,969 4 5,973 
Total PP&E7,053 4 7,057 6,469 4 6,473 
Regulatory assets/(liabilities)292 (20)272 9 (10)(1)
Total investments and other noncurrent assets2,683 (20)2,663 2,353 (9)2,344 
Total assets10,073 (16)10,057 9,212 (5)9,207 
Accumulated deferred income taxes, net1,223 (4)1,219 986 (1)985 
Total noncurrent liabilities3,981 (4)3,977 3,692 — 3,692 
Total liabilities5,075 (4)5,071 4,946 — 4,946 
Retained earnings1,341 (12)1,329 1,216 (5)1,211 
Total common stockholder's equity4,998 (12)4,986 4,266 (5)4,261 

As of June 30, 2025As of June 30, 2024
(In millions)As ReportedAdjustmentAs RevisedAs ReportedAdjustmentAs Revised
PP&E - In service$8,940 $30 $8,970 $8,458 $16 $8,474 
Accumulated provision for depreciation
2,434 30 2,464 2,388 12 2,400 
PP&E Excluding CWIP6,506 — 6,506 6,070 4 6,074 
Total PP&E7,232 — 7,232 6,581 4 6,585 
Regulatory assets/(liabilities)354 (23)331 95 (13)82 
Total investments and other noncurrent assets2,763 (23)2,740 2,444 (13)2,431 
Total assets10,450 (23)10,427 9,498 (9)9,489 
Accumulated deferred income taxes, net1,257 (7)1,250 1,037 (2)1,035 
Total noncurrent liabilities4,017 (7)4,010 3,742 (2)3,740 
Total liabilities5,385 (7)5,378 4,574 (2)4,572 
Retained earnings1,407 (16)1,391 1,273 (7)1,266 
Total common stockholder's equity5,065 (16)5,049 4,924 (7)4,917 
As of September 30, 2025As of September 30, 2024
(In millions)As ReportedAdjustmentAs RevisedAs ReportedAdjustmentAs Revised
PP&E - In service$9,002 $55 $9,057 $8,521 $15 $8,536 
Accumulated provision for depreciation 2,380 55 2,435 2,402 12 2,414 
PP&E Excluding CWIP6,622 — 6,622 6,119 3 6,122 
Total PP&E7,460 — 7,460 6,707 3 6,710 
Regulatory assets/(liabilities)410 (24)386 153 (15)138 
Total investments and other noncurrent assets2,843 (24)2,819 2,515 (15)2,500 
Total assets11,490 (24)11,466 9,611 (12)9,599 
Accumulated deferred income taxes, net1,292 (7)1,285 1,109 (3)1,106 
Total noncurrent liabilities5,380 (7)5,373 3,831 (3)3,828 
Total liabilities6,394 (7)6,387 4,576 (3)4,573 
Retained earnings1,436 (17)1,419 1,382 (9)1,373 
Total common stockholder's equity5,096 (17)5,079 5,035 (9)5,026 

JCP&L Interim Statements of Common Stockholder's of Equity
As of September 30, 2024
(In millions)As Reported AdjustmentAs Revised
Balance, January 1, 2024$4,132 $(4)$4,128 
Net loss(8)(1)(9)
Balance, March 31, 20244,266 (5)4,261 
Net income57 (2)55 
Balance, June 30, 20244,924 (7)4,917 
Net income109 (2)107 
Balance, September 30, 20245,035 (9)5,026 
As of September 30, 2025
(In millions)As Reported AdjustmentAs Revised
Balance, January 1, 2025$4,977 $(10)$4,967 
Net income49 (2)47 
Balance, March 31, 20254,998 (12)4,986 
Net income66 (4)62 
Balance, June 30, 20255,065 (16)5,049 
Net income119 (1)118 
Balance, September 30, 20255,096 (17)5,079 
JCP&L Interim Statements of Cash Flows
For the Three Months Ended
March 31, 2025		For the Three Months Ended
March 31, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income$49 $(2)$47 $(8)$(1)$(9)
Adjustments to reconcile net income to net cash from operating activities-
Depreciation, amortization and impairments43 2 45 71 2 73 
Deferred income taxes and investment tax credits, net23 — 23 27 — 27 
Net cash provided from operating activities205 — 205 83 1 84 
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital investments$(206)$— $(206)$(194)$(1)$(195)
Net cash used for investing activities(226)— (226)(215)(1)(216)
Net change in cash, cash equivalents, and restricted cash$— $— $— $— $— $— 

For the Six Months Ended
June 30, 2025		For the Six Months Ended
June 30, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income$115 $(6)$109 $49 $(2)$47 
Adjustments to reconcile net income to net cash from operating activities-
Depreciation, amortization and impairments94 4 98 108 5 113 
Deferred income taxes and investment tax credits, net53 (2)51 77 (1)76 
Net cash provided from operating activities326 (4)322 164 2 166 
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital investments$(477)$4 $(473)$(387)$(2)$(389)
Net cash used for investing activities(527)4 (523)(421)(2)(423)
Net change in cash, cash equivalents, and restricted cash$— $— $— $— $— $— 
For the Nine Months Ended
September 30, 2025		For the Nine Months Ended
September 30, 2024
(In millions)As Reported AdjustmentAs RevisedAs ReportedAdjustmentAs Revised
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income$234 $(7)$227 $158 $(5)$153 
Adjustments to reconcile net income to net cash from operating activities-
Depreciation, amortization and impairments171 6 177 144 8 152 
Deferred income taxes and investment tax credits, net85 (3)82 148 (2)146 
Net cash provided from operating activities381 (4)377 427 1 428 
CASH FLOWS FROM FINANCING ACTIVITIES:
Capital investments$(782)$4 $(778)$(599)$(1)$(600)
Net cash used for investing activities(877)4 (873)(648)(1)(649)
Net change in cash, cash equivalents, and restricted cash$708 $— $708 $— $— $— 
v3.25.4
ORGANIZATION AND BASIS OF PRESENTATION - Narrative (Details)
individual in Millions, customer in Millions, $ in Millions
 3 Months Ended 6 Months Ended 9 Months Ended 12 Months Ended
Jul. 16, 2025
USD ($)
Feb. 26, 2025
USD ($)
transmission_project
Jul. 17, 2024
USD ($)
Mar. 25, 2024
USD ($)
Dec. 31, 2025
USD ($)
transmissionCenter
individual
mi
MW
Sep. 30, 2025
USD ($)
Jun. 30, 2025
USD ($)
Mar. 31, 2025
USD ($)
Dec. 31, 2024
USD ($)
Sep. 30, 2024
USD ($)
Jun. 30, 2024
USD ($)
Mar. 31, 2024
USD ($)
Jun. 30, 2025
USD ($)
Jun. 30, 2024
USD ($)
Sep. 30, 2025
USD ($)
Sep. 30, 2024
USD ($)
Dec. 31, 2025
USD ($)
customer
transmissionCenter
individual
mi
MW
Dec. 31, 2024
USD ($)
Dec. 31, 2023
USD ($)
Jul. 15, 2025
Feb. 21, 2025
Feb. 02, 2023
USD ($)
director
May 31, 2022
Regulatory Assets [Line Items]                                              
Number of customers | customer                                 6.0            
Number of regional transmission centers | transmissionCenter         2                       2            
Income (loss) before income taxes                                 $ 1,559.0 $ 1,504.0 $ 1,464.0        
Regulatory assets         $ 829.0       $ 617.0               829.0 617.0          
Regulatory liabilities         1,185.0       995.0               1,185.0 995.0          
Regulatory assets currently being recovered through deferred returns         $ 802.0       698.0               802.0 698.0          
Equity method investment earnings, net                                 0.0 58.0 175.0        
Impairment of assets (Note 1.)                                 352.0 115.0 15.0        
Other operating expenses                                 $ 4,122.0 4,044.0 $ 3,579.0        
FET equity interest sale, net of transaction costs                                   $ 2,665.0          
Public utilities, property, plant and equipment, disclosure of composite depreciation rate for plants in service                                 2.80% 2.90% 2.80%        
Capitalized financing costs                                 $ 108.0 $ 60.0 $ 44.0        
Interest costs capitalized                                 77.0 73.0 53.0        
Impairment of long-lived assets to be disposed of                   $ 62.0                          
Operating Segments                                              
Regulatory Assets [Line Items]                                              
Equity method investment earnings, net                                 0.0 0.0 0.0        
Corporate/Other                                              
Regulatory Assets [Line Items]                                              
Equity method investment earnings, net                                 $ 0.0 58.0 175.0        
Impairment of long-lived assets to be disposed of                   3.0                          
VIRGINIA                                              
Regulatory Assets [Line Items]                                              
Plant generation capacity (in MW's) | MW         3,003                       3,003            
NCI                                              
Regulatory Assets [Line Items]                                              
FET equity interest sale, net of transaction costs                                   731.0          
OPIC                                              
Regulatory Assets [Line Items]                                              
FET equity interest sale, net of transaction costs                                   1,934.0          
Brookfield II | FET                                              
Regulatory Assets [Line Items]                                              
Sale of ownership interest by parent                                           30.00%  
Signal Peak                                              
Regulatory Assets [Line Items]                                              
Impairment of equity method investments                 13.0                            
Organizational Changes                                              
Regulatory Assets [Line Items]                                              
Restructuring charges               $ 26.0                              
Restructuring Charges, Statement of Income or Comprehensive Income [Extensible Enumeration]               Other operating expenses                              
Adjustment                                              
Regulatory Assets [Line Items]                                              
Income (loss) before income taxes         $ (24.0)   $ 21.0                                
Deferred tax assets, valuation allowance                                     21.0        
Income (Loss) From Continuing Operations Before Income Taxes, Extraordinary Items, Noncontrolling Interest, Prior Year Adjustments         $ (18.0)                                    
Integrated                                              
Regulatory Assets [Line Items]                                              
Service area | mi         24,000                       24,000            
Integrated | Operating Segments                                              
Regulatory Assets [Line Items]                                              
Equity method investment earnings, net                                 $ 0.0 0.0 0.0        
Integrated Segment                                              
Regulatory Assets [Line Items]                                              
Plant generation capacity (in MW's) | MW         3,610                       3,610            
Integrated                                              
Regulatory Assets [Line Items]                                              
Number of customers | customer                                 2.0            
Integrated | Operating Segments                                              
Regulatory Assets [Line Items]                                              
Equity method investment earnings, net                                 $ 0.0 0.0 0.0        
Impairment of long-lived assets to be disposed of                   17.0                          
Distribution                                              
Regulatory Assets [Line Items]                                              
Number of customers | customer                                 4.3            
Property, plant and equipment, net         $ 2,300.0                       $ 2,300.0            
Distribution | Operating Segments                                              
Regulatory Assets [Line Items]                                              
Equity method investment earnings, net                                 $ 0.0 0.0 0.0        
Stand-Alone Transmission | Operating Segments                                              
Regulatory Assets [Line Items]                                              
Impairment of long-lived assets to be disposed of                   11.0                          
Distribution                                              
Regulatory Assets [Line Items]                                              
Impairment of assets (Note 1.)         $ 352.0                                    
Distribution | Operating Segments                                              
Regulatory Assets [Line Items]                                              
Impairment of long-lived assets to be disposed of                   31.0                          
FET                                              
Regulatory Assets [Line Items]                                              
Net of transaction costs                                   32.0          
Net of taxes                                   803.0          
Number of directors | director                                           5  
FET | Brookfield II                                              
Regulatory Assets [Line Items]                                              
Sale of ownership interest by parent       49.90%               19.90%                     19.90%
Consideration                                           $ 3,500.0  
Number of directors | director                                           2  
FET | FE                                              
Regulatory Assets [Line Items]                                              
Number of directors | director                                           3  
JERSEY CENTRAL POWER & LIGHT COMPANY                                              
Regulatory Assets [Line Items]                                              
Number of customers | customer                                 1.2            
Transmission services available area populations | individual         2.8                       2.8            
Income (loss) before income taxes           $ 158.0 82.0 $ 63.0   147.0 $ 75.0 $ (13.0) $ 145.0 $ 63.0 $ 303.0 $ 209.0 $ 413.0 329.0 158.0        
Regulatory assets         $ 515.0       247.0               515.0 247.0          
Regulatory assets currently being recovered through deferred returns         $ 76.0       45.0               76.0 45.0          
Other operating expenses           158.0 137.0 145.0   180.0 157.0 186.0 282.0 343.0 440.0 523.0 $ 680.0 [1] $ 654.0 [1] $ 555.0 [1]        
Public utilities, property, plant and equipment, disclosure of composite depreciation rate for plants in service                                 2.90% 2.90% 2.80%        
Capitalized financing costs                                 $ 28.0 $ 5.0 $ 5.0        
Interest costs capitalized                                 $ 15.0 23.0 14.0        
Impairment of long-lived assets to be disposed of                   9.0                          
JERSEY CENTRAL POWER & LIGHT COMPANY | Organizational Changes                                              
Regulatory Assets [Line Items]                                              
Restructuring charges               5.0                              
JERSEY CENTRAL POWER & LIGHT COMPANY | Adjustment                                              
Regulatory Assets [Line Items]                                              
Income (loss) before income taxes           (2.0) (6.0) (2.0)   (3.0) (3.0) (1.0) (8.0) (3.0) (10.0) (7.0)   (9.0) (7.0)        
Other operating expenses           $ 0.0 $ 4.0 $ 0.0   $ 1.0 $ (1.0) (1.0) $ 4.0 $ (2.0) $ 4.0 $ (1.0)   (2.0) 0.0        
JERSEY CENTRAL POWER & LIGHT COMPANY | Distribution                                              
Regulatory Assets [Line Items]                                              
Number of customers | customer                                 1.2            
JERSEY CENTRAL POWER & LIGHT COMPANY | Distribution                                              
Regulatory Assets [Line Items]                                              
Impairment of assets (Note 1.)                       $ 53.0                      
Brookfield | Brookfield II                                              
Regulatory Assets [Line Items]                                              
Interest income, operating                                   24.0          
Brookfield | Brookfield II | FET                                              
Regulatory Assets [Line Items]                                              
Liabilities incurred     $ 1,200.0 $ 1,200.0                                      
Payments to acquire businesses, gross                                   2,300.0          
Brookfield | Brookfield II | FET | Promissory Note, $750 Million at 5.75% Due September 2025                                              
Regulatory Assets [Line Items]                                              
Face amount of loan       $ 750.0                                      
Issuance interest rate       5.75%                                      
Brookfield | Brookfield II | FET | Promissory Note, $450 Million at 7.75% Due September 2025                                              
Regulatory Assets [Line Items]                                              
Face amount of loan       $ 450.0                                      
Issuance interest rate       7.75%                                      
AGC | VIRGINIA                                              
Regulatory Assets [Line Items]                                              
Plant generation capacity (in MW's) | MW         487                       487            
Proportionate ownership share         16.25%                       16.25%            
Property, plant and equipment         $ 142.0                       $ 142.0            
Virginia Electric and Power Company | VIRGINIA                                              
Regulatory Assets [Line Items]                                              
Proportionate ownership share         60.00%                       60.00%            
Valley Link | PJM Interconnection, LLC | PJM 2024 RTEP Window 1                                              
Regulatory Assets [Line Items]                                              
Number of transmission projects | transmission_project   2                                          
Transmission solutions to the reliability issues   $ 3,000.0                                          
Valley Link | FET                                              
Regulatory Assets [Line Items]                                              
Equity method investment, ownership percentage                                         34.00%    
Valley Link | FET | PJM Interconnection, LLC | PJM 2024 RTEP Window 1                                              
Regulatory Assets [Line Items]                                              
Transmission solutions to the reliability issues   $ 1,000.0                                          
Valley Link | Dominion HV                                              
Regulatory Assets [Line Items]                                              
Equity method investment, ownership percentage                                         30.00%    
Valley Link | Transource                                              
Regulatory Assets [Line Items]                                              
Equity method investment, ownership percentage                                         36.00%    
Global Holding                                              
Regulatory Assets [Line Items]                                              
Equity method investments                 45.0                 45.0          
Global Holding | FEV                                              
Regulatory Assets [Line Items]                                              
Investment ownership percentage         33.33%                       33.33%     33.33%      
Ownership percentage sold 0.3333                                            
Proceeds from investments sold $ 47.5                                            
Equity method investments         $ 47.5                       $ 47.5            
Global Holding | FEV | Variable Interest Entity, Not Primary Beneficiary                                              
Regulatory Assets [Line Items]                                              
Proceeds from dividends received                                   80.0 165.0        
Global Holding | FEV | Corporate/Other | Other Nonoperating Income (Expense)                                              
Regulatory Assets [Line Items]                                              
Equity method investment earnings, net                                   72.0 $ 175.0        
Other Sundry Investments                                              
Regulatory Assets [Line Items]                                              
Equity method investments         38.0       84.0               38.0 84.0          
Other Sundry Investments | JERSEY CENTRAL POWER & LIGHT COMPANY                                              
Regulatory Assets [Line Items]                                              
Equity method investments         0.0       0.0               0.0 0.0          
Path-WV | Variable Interest Entity, Not Primary Beneficiary                                              
Regulatory Assets [Line Items]                                              
Equity method investments         $ 17.0       $ 17.0               $ 17.0 $ 17.0          
Variable interest entities percentage of high voltage transmission line project owned by variable interest entity one in joint venture party two         50.00%                       50.00%            
FET | FE                                              
Regulatory Assets [Line Items]                                              
Equity method investment, ownership percentage         50.10%                       50.10%            
FET | Brookfield | Brookfield II                                              
Regulatory Assets [Line Items]                                              
Equity method investment, ownership percentage         49.90%                       49.90%            
[1] Includes affiliated operating expenses of $116 million, $118 million and $122 million in 2025, 2024 and 2023, respectively.
v3.25.4
ORGANIZATION AND BASIS OF PRESENTATION - Schedule of Error Corrections related to Statement of Income and Comprehensive Income (Details) - USD ($)
$ in Millions
 3 Months Ended 6 Months Ended 9 Months Ended 12 Months Ended
Dec. 31, 2025
Sep. 30, 2025
Jun. 30, 2025
Mar. 31, 2025
Sep. 30, 2024
Jun. 30, 2024
Mar. 31, 2024
Jun. 30, 2025
Jun. 30, 2024
Sep. 30, 2025
Sep. 30, 2024
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
New Accounting Pronouncements or Change in Accounting Principle [Line Items]                            
Deferral of regulatory assets, net                       $ (109) $ (231) $ (261)
Other operating expenses                       4,122 4,044 3,579
Total operating expenses                       12,884 11,097 10,604
Operating income                       2,206 2,375 2,266
Income before income taxes                       1,559 1,504 1,464
Income taxes                       288 377 267
Net income                       1,271 1,127 1,176
Comprehensive income                       1,271 1,130 1,173
JERSEY CENTRAL POWER & LIGHT COMPANY                            
New Accounting Pronouncements or Change in Accounting Principle [Line Items]                            
Deferral of regulatory assets, net   $ 13 $ (12) $ (20) $ (23) $ (30) $ (37) $ (32) $ (68) $ (19) $ (90) (134) (124) (67)
Other operating expenses   158 137 145 180 157 186 282 343 440 523 680 [1] 654 [1] 555 [1]
Total operating expenses   694 499 494 608 461 463 993 923 1,687 1,532 2,234 1,955 1,777
Operating income   170 93 72 157 96 3 165 100 335 256 404 360 250
Income before income taxes   158 82 63 147 75 (13) 145 63 303 209 413 329 158
Income taxes   40 20 16 40 20 (4) 36 16 76 56 107 87 33
Net income   118 62 47 107 55 (9) 109 47 227 153 306 242 125
Comprehensive income   118 62 47 107 55 (9) 109 47 227 153 $ 306 243 125
As Reported | JERSEY CENTRAL POWER & LIGHT COMPANY                            
New Accounting Pronouncements or Change in Accounting Principle [Line Items]                            
Deferral of regulatory assets, net   11 (14) (22) (25) (34) (39) (36) (73) (25) (98)   (135) (74)
Other operating expenses   158 133 145 179 158 187 278 345 436 524   656 555
Total operating expenses   692 493 492 605 458 462 985 920 1,677 1,525   1,946 1,770
Operating income   172 99 74 160 99 4 173 103 345 263   369 257
Income before income taxes   160 88 65 150 78 (12) 153 66 313 216   338 165
Income taxes   41 22 16 41 21 (4) 38 17 79 58   90 35
Net income   119 66 49 109 57 (8) 115 49 234 158   248 130
Comprehensive income   119 66 49 109 57 (8) 115 49 234 158   249 130
Adjustment                            
New Accounting Pronouncements or Change in Accounting Principle [Line Items]                            
Income before income taxes $ (24)   21                      
Adjustment | JERSEY CENTRAL POWER & LIGHT COMPANY                            
New Accounting Pronouncements or Change in Accounting Principle [Line Items]                            
Deferral of regulatory assets, net   2 2 2 2 4 2 4 5 6 8   11 7
Other operating expenses   0 4 0 1 (1) (1) 4 (2) 4 (1)   (2) 0
Total operating expenses   2 6 2 3 3 1 8 3 10 7   9 7
Operating income   (2) (6) (2) (3) (3) (1) (8) (3) (10) (7)   (9) (7)
Income before income taxes   (2) (6) (2) (3) (3) (1) (8) (3) (10) (7)   (9) (7)
Income taxes   (1) (2) 0 (1) (1) 0 (2) (1) (3) (2)   (3) (2)
Net income   (1) (4) (2) (2) (2) (1) (6) (2) (7) (5)   (6) (5)
Comprehensive income   $ (1) $ (4) $ (2) $ (2) $ (2) $ (1) $ (6) $ (2) $ (7) $ (5)   $ (6) $ (5)
[1] Includes affiliated operating expenses of $116 million, $118 million and $122 million in 2025, 2024 and 2023, respectively.
v3.25.4
ORGANIZATION AND BASIS OF PRESENTATION - Schedule of Error Corrections related to Balance Sheets (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Sep. 30, 2025
Jun. 30, 2025
Mar. 31, 2025
Dec. 31, 2024
Sep. 30, 2024
Jun. 30, 2024
Mar. 31, 2024
Dec. 31, 2023
Dec. 31, 2022
New Accounting Pronouncements or Change in Accounting Principle [Line Items]                    
PP&E - In service $ 56,213       $ 52,896          
Accumulated provision for depreciation 15,189       14,548          
PP&E Excluding CWIP 41,024       38,348          
Total PP&E 44,413       41,102          
Regulatory assets/(liabilities) (356)       (378)          
Total investments and other noncurrent assets 8,512       8,166          
Total Assets [1] 55,904       52,044          
Accumulated deferred income taxes 6,032       5,613          
Total noncurrent liabilities 36,707       33,327          
Total liabilities [1] 41,978       38,324          
Retained earnings 35       43          
Total common stockholders' equity 12,510       12,455          
JERSEY CENTRAL POWER & LIGHT COMPANY                    
New Accounting Pronouncements or Change in Accounting Principle [Line Items]                    
PP&E - In service 9,267 $ 9,057 $ 8,970 $ 8,841 8,731 $ 8,536 $ 8,474 $ 8,352 $ 8,288  
Accumulated provision for depreciation 2,439 2,435 2,464 2,445 2,439 2,414 2,400 2,379 2,373  
PP&E Excluding CWIP 6,828 6,622 6,506 6,396 6,292 6,122 6,074 5,973 5,915  
Total PP&E 7,708 7,460 7,232 7,057 6,912 6,710 6,585 6,473 6,390  
Regulatory assets/(liabilities) 515 386 331 272 247 138 82 (1) (56)  
Total investments and other noncurrent assets 2,997 2,819 2,740 2,663 2,622 2,500 2,431 2,344 2,330  
Total Assets 11,109 11,466 10,427 10,057 9,913 9,599 9,489 9,207 9,102  
Accumulated deferred income taxes 1,348 1,285 1,250 1,219 1,192 1,106 1,035 985 955  
Total noncurrent liabilities 5,411 5,373 4,010 3,977 4,601 3,828 3,740 3,692 3,723  
Total liabilities 5,949 6,387 5,378 5,071 4,946 4,573 4,572 4,946 4,974  
Retained earnings 1,498 1,419 1,391 1,329 1,312 1,373 1,266 1,211 1,220  
Total common stockholders' equity $ 5,160 5,079 5,049 4,986 4,967 5,026 4,917 4,261 4,128 $ 3,968
As Reported | JERSEY CENTRAL POWER & LIGHT COMPANY                    
New Accounting Pronouncements or Change in Accounting Principle [Line Items]                    
PP&E - In service   9,002 8,940 8,807 8,697 8,521 8,458 8,340 8,278  
Accumulated provision for depreciation   2,380 2,434 2,415 2,409 2,402 2,388 2,371 2,365  
PP&E Excluding CWIP   6,622 6,506 6,392 6,288 6,119 6,070 5,969 5,913  
Total PP&E   7,460 7,232 7,053 6,908 6,707 6,581 6,469 6,388  
Regulatory assets/(liabilities)   410 354 292 265 153 95 9 (48)  
Total investments and other noncurrent assets   2,843 2,763 2,683 2,640 2,515 2,444 2,353 2,330  
Total Assets   11,490 10,450 10,073 9,927 9,611 9,498 9,212 9,100  
Accumulated deferred income taxes   1,292 1,257 1,223 1,196 1,109 1,037 986 957  
Total noncurrent liabilities   5,380 4,017 3,981 4,605 3,831 3,742 3,692 3,717  
Total liabilities   6,394 5,385 5,075 4,950 4,576 4,574 4,946 4,968  
Retained earnings   1,436 1,407 1,341 1,322 1,382 1,273 1,216 1,224  
Total common stockholders' equity   5,096 5,065 4,998 4,977 5,035 4,924 4,266 4,132 3,967
Adjustment | JERSEY CENTRAL POWER & LIGHT COMPANY                    
New Accounting Pronouncements or Change in Accounting Principle [Line Items]                    
PP&E - In service   55 30 34 34 15 16 12 10  
Accumulated provision for depreciation   55 30 30 30 12 12 8 8  
PP&E Excluding CWIP   0 0 4 4 3 4 4 2  
Total PP&E   0 0 4 4 3 4 4 2  
Regulatory assets/(liabilities)   (24) (23) (20) (18) (15) (13) (10) (8)  
Total investments and other noncurrent assets   (24) (23) (20) (18) (15) (13) (9) 0  
Total Assets   (24) (23) (16) (14) (12) (9) (5) 2  
Accumulated deferred income taxes   (7) (7) (4) (4) (3) (2) (1) (2)  
Total noncurrent liabilities   (7) (7) (4) (4) (3) (2) 0 6  
Total liabilities   (7) (7) (4) (4) (3) (2) 0 6  
Retained earnings   (17) (16) (12) (10) (9) (7) (5) (4)  
Total common stockholders' equity   $ (17) $ (16) $ (12) $ (10) $ (9) $ (7) $ (5) $ (4) $ 1
[1] As of December 31, 2025 and 2024, the combined assets of the VIEs were $13,269 million and $12,053 million, respectively, that can only be used to settle obligations of the VIEs. As of December 31, 2025 and 2024, these assets include, respectively: Cash and cash equivalents of $8 million and $8 million, Restricted cash of $40 million and $40 million, Accounts receivable of $92 million and $96 million, Materials and supplies, at average cost of $1 million and $1 million, Prepaid taxes and other current assets of $41 million and $22 million, Property, plant, and equipment of $12,475 million and $11,217 million, Goodwill of $224 million and $224 million, Investments of $19 million and $19 million,
Regulatory assets of $21 million and $92 million, and Other noncurrent assets of $348 million and $334 million. The consolidated liabilities as of December 31, 2025 and 2024, include $10,176 million and $9,147 million, respectively, of liabilities of VIEs whose creditors have no recourse to FE. As of December 31, 2025 and 2024, these liabilities include, respectively: Currently payable long-term debt of $126 million and $674 million, Short-term borrowings of $245 million and $300 million, Accrued interest of $108 million and $76 million, Accrued taxes of $335 million and $306 million, other current liabilities of $9 million and $10 million, Long-term debt and other long-term obligations of $6,884 million and $5,544 million, Accumulated deferred income taxes of $1,540 million and $1,411 million, Regulatory liabilities of $598 million and $526 million, and Other noncurrent liabilities of $331 million and $300 million.
v3.25.4
ORGANIZATION AND BASIS OF PRESENTATION - Schedule of Error Corrections related to Statements of Equity (Details) - USD ($)
$ in Millions
 3 Months Ended 12 Months Ended
Sep. 30, 2025
Jun. 30, 2025
Mar. 31, 2025
Sep. 30, 2024
Jun. 30, 2024
Mar. 31, 2024
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Increase (Decrease) in Stockholders' Equity [Roll Forward]                  
Beginning balance     $ 12,455       $ 12,455    
Net income (loss)             1,020 $ 978 $ 1,102
Ending balance             12,510 12,455  
JERSEY CENTRAL POWER & LIGHT COMPANY                  
Increase (Decrease) in Stockholders' Equity [Roll Forward]                  
Beginning balance $ 5,049 $ 4,986 4,967 $ 4,917 $ 4,261 $ 4,128 4,967 4,128 3,968
Net income (loss) 118 62 47 107 55 (9) 306 242 125
Ending balance 5,079 5,049 4,986 5,026 4,917 4,261 5,160 4,967 4,128
As Reported | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Increase (Decrease) in Stockholders' Equity [Roll Forward]                  
Beginning balance 5,065 4,998 4,977 4,924 4,266 4,132 4,977 4,132 3,967
Net income (loss) 119 66 49 109 57 (8)   248 130
Ending balance 5,096 5,065 4,998 5,035 4,924 4,266   4,977 4,132
Adjustment | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Increase (Decrease) in Stockholders' Equity [Roll Forward]                  
Beginning balance (16) (12) (10) (7) (5) (4) $ (10) (4) 1
Net income (loss) (1) (4) (2) (2) (2) (1)   (6) (5)
Ending balance $ (17) $ (16) $ (12) $ (9) $ (7) $ (5)   $ (10) $ (4)
v3.25.4
ORGANIZATION AND BASIS OF PRESENTATION - Schedule of Error Corrections related to Statements of Cash Flows (Details) - USD ($)
$ in Millions
 3 Months Ended 6 Months Ended 9 Months Ended 12 Months Ended
Sep. 30, 2025
Jun. 30, 2025
Mar. 31, 2025
Sep. 30, 2024
Jun. 30, 2024
Mar. 31, 2024
Jun. 30, 2025
Jun. 30, 2024
Sep. 30, 2025
Sep. 30, 2024
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
CASH FLOWS FROM OPERATING ACTIVITIES:                          
Net income                     $ 1,271 $ 1,127 $ 1,176
Adjustments to reconcile net income to net cash from operating activities-                          
Depreciation, amortization, and impairments                     1,607 1,446 1,255
Deferred income taxes and investment tax credits, net                     219 316 252
Net cash provided from operating activities                     3,700 2,891 1,387
CASH FLOWS FROM INVESTING ACTIVITIES:                          
Capital investments                     (4,705) (4,030) (3,356)
Net cash used for investing activities                     (5,065) (4,350) (3,652)
JERSEY CENTRAL POWER & LIGHT COMPANY                          
CASH FLOWS FROM OPERATING ACTIVITIES:                          
Net income $ 118 $ 62 $ 47 $ 107 $ 55 $ (9) $ 109 $ 47 $ 227 $ 153 306 242 125
Adjustments to reconcile net income to net cash from operating activities-                          
Depreciation, amortization, and impairments     45     73 98 113 177 152 130 172 152
Deferred income taxes and investment tax credits, net     23     27 51 76 82 146 143 230 48
Net cash provided from operating activities     205     84 322 166 377 428 571 609 264
CASH FLOWS FROM INVESTING ACTIVITIES:                          
Capital investments     (206)     (195) (473) (389) (778) (600) (1,105) (879) (633)
Net cash used for investing activities     (226)     (216) (523) (423) (873) (649) (1,204) (949) (690)
Net change in cash, cash equivalents, and restricted cash     0     0 0 0 708 0 $ 0 0 0
As Reported | JERSEY CENTRAL POWER & LIGHT COMPANY                          
CASH FLOWS FROM OPERATING ACTIVITIES:                          
Net income 119 66 49 109 57 (8) 115 49 234 158   248 130
Adjustments to reconcile net income to net cash from operating activities-                          
Depreciation, amortization, and impairments     43     71 94 108 171 144   161 145
Deferred income taxes and investment tax credits, net     23     27 53 77 85 148   233 50
Net cash provided from operating activities     205     83 326 164 381 427   607 264
CASH FLOWS FROM INVESTING ACTIVITIES:                          
Capital investments     (206)     (194) (477) (387) (782) (599)   (877) (633)
Net cash used for investing activities     (226)     (215) (527) (421) (877) (648)   (947) (690)
Net change in cash, cash equivalents, and restricted cash     0     0 0 0 708 0   0 0
Adjustment | JERSEY CENTRAL POWER & LIGHT COMPANY                          
CASH FLOWS FROM OPERATING ACTIVITIES:                          
Net income $ (1) $ (4) (2) $ (2) $ (2) (1) (6) (2) (7) (5)   (6) (5)
Adjustments to reconcile net income to net cash from operating activities-                          
Depreciation, amortization, and impairments     2     2 4 5 6 8   11 7
Deferred income taxes and investment tax credits, net     0     0 (2) (1) (3) (2)   (3) (2)
Net cash provided from operating activities     0     1 (4) 2 (4) 1   2 0
CASH FLOWS FROM INVESTING ACTIVITIES:                          
Capital investments     0     (1) 4 (2) 4 (1)   (2) 0
Net cash used for investing activities     0     (1) 4 (2) 4 (1)   (2) 0
Net change in cash, cash equivalents, and restricted cash     $ 0     $ 0 $ 0 $ 0 $ 0 $ 0   $ 0 $ 0
v3.25.4
ORGANIZATION AND BASIS OF PRESENTATION - Schedule of Regulatory Assets on the Balance Sheets (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Sep. 30, 2025
Jun. 30, 2025
Mar. 31, 2025
Dec. 31, 2024
Sep. 30, 2024
Jun. 30, 2024
Mar. 31, 2024
Dec. 31, 2023
Regulatory assets on the Balance Sheets                  
Regulatory liability $ (1,185)       $ (995)        
Regulatory assets 829       617        
Net Regulatory Liabilities included on FirstEnergy's Consolidated Balance Sheets (356)       (378)        
Change 22                
Current Return - FirstEnergy 1,425       1,243        
Change 182                
JERSEY CENTRAL POWER & LIGHT COMPANY                  
Regulatory assets on the Balance Sheets                  
Regulatory assets 515       247        
Net Regulatory Liabilities included on FirstEnergy's Consolidated Balance Sheets 515 $ 386 $ 331 $ 272 247 $ 138 $ 82 $ (1) $ (56)
Change 268                
Current Return - FirstEnergy 538       439        
Change 99                
Customer payables for future income taxes                  
Regulatory assets on the Balance Sheets                  
Regulatory liability (2,041)       (2,234)        
Change 193                
Customer payables for future income taxes | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Regulatory assets on the Balance Sheets                  
Regulatory liability (393)       (410)        
Change 17                
Spent nuclear fuel disposal costs                  
Regulatory assets on the Balance Sheets                  
Regulatory liability (76)       (72)        
Change (4)                
Spent nuclear fuel disposal costs | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Regulatory assets on the Balance Sheets                  
Regulatory liability (76)       (72)        
Change (4)                
Asset removal costs                  
Regulatory assets on the Balance Sheets                  
Regulatory liability (675)       (681)        
Change 6                
Asset removal costs | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Regulatory assets on the Balance Sheets                  
Regulatory liability (87)       (101)        
Change 14                
Deferred transmission costs                  
Regulatory assets on the Balance Sheets                  
Regulatory liability (43)                
Deferred transmission costs | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Regulatory assets on the Balance Sheets                  
Regulatory liability (25)       (3)        
Change (22)                
Ohio settlement charges                  
Regulatory assets on the Balance Sheets                  
Regulatory liability (250)       0        
Change (250)                
Deferred transmission costs                  
Regulatory assets on the Balance Sheets                  
Regulatory assets         190        
Change (233)                
Deferred generation costs                  
Regulatory assets on the Balance Sheets                  
Regulatory assets 405       481        
Change (76)                
Current Return - FirstEnergy 280       314        
Change (34)                
Deferred distribution costs                  
Regulatory assets on the Balance Sheets                  
Regulatory assets 466       287        
Change 179                
Current Return - FirstEnergy 199       153        
Change 46                
Deferred distribution costs | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Regulatory assets on the Balance Sheets                  
Regulatory assets 318       206        
Change 112                
Current Return - FirstEnergy 147       101        
Change 46                
Storm-related costs                  
Regulatory assets on the Balance Sheets                  
Regulatory assets 1,122       1,015        
Change 107                
Current Return - FirstEnergy 844       694        
Change 150                
Storm-related costs | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Regulatory assets on the Balance Sheets                  
Regulatory assets 367       310        
Change 57                
Current Return - FirstEnergy 367       310        
Change 57                
Energy efficiency program costs                  
Regulatory assets on the Balance Sheets                  
Regulatory assets 462       349        
Change 113                
Energy efficiency program costs | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Regulatory assets on the Balance Sheets                  
Regulatory assets 316       208        
Change 108                
New Jersey societal benefit costs                  
Regulatory assets on the Balance Sheets                  
Regulatory assets 80       87        
Change (7)                
New Jersey societal benefit costs | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Regulatory assets on the Balance Sheets                  
Regulatory assets 80       87        
Change (7)                
Vegetation management                  
Regulatory assets on the Balance Sheets                  
Regulatory assets 153       125        
Change 28                
Other                  
Regulatory assets on the Balance Sheets                  
Regulatory assets 41       75        
Change (34)                
Current Return - FirstEnergy 102       82        
Change 20                
Other | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Regulatory assets on the Balance Sheets                  
Regulatory assets 15       22        
Change (7)                
Current Return - FirstEnergy 24       $ 28        
Change $ (4)                
v3.25.4
ORGANIZATION AND BASIS OF PRESENTATION - Schedule of Goodwill (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Goodwill [Line Items]    
Goodwill $ 5,618 $ 5,618
JERSEY CENTRAL POWER & LIGHT COMPANY    
Goodwill [Line Items]    
Goodwill 1,811 1,811
Operating Segments    
Goodwill [Line Items]    
Goodwill 5,618 5,618
Operating Segments | JERSEY CENTRAL POWER & LIGHT COMPANY    
Goodwill [Line Items]    
Goodwill 1,811 1,811
Distribution Segment    
Goodwill [Line Items]    
Goodwill 3,222 3,222
Distribution Segment | Operating Segments    
Goodwill [Line Items]    
Goodwill 3,222 3,222
Distribution Segment | Operating Segments | JERSEY CENTRAL POWER & LIGHT COMPANY    
Goodwill [Line Items]    
Goodwill 1,213 1,213
Integrated Segment    
Goodwill [Line Items]    
Goodwill $ 1,953 $ 1,953
Integrated Segment | Operating Segments | Minimum    
Goodwill [Line Items]    
Useful Service Life 5 years 5 years
Integrated Segment | Operating Segments | Maximum    
Goodwill [Line Items]    
Useful Service Life 80 years 100 years
Stand-Alone Transmission Segment    
Goodwill [Line Items]    
Goodwill $ 443 $ 443
Stand-Alone Transmission Segment | Operating Segments | Minimum    
Goodwill [Line Items]    
Useful Service Life 5 years 5 years
Stand-Alone Transmission Segment | Operating Segments | Maximum    
Goodwill [Line Items]    
Useful Service Life 85 years 85 years
Transmission Segment | Operating Segments | JERSEY CENTRAL POWER & LIGHT COMPANY    
Goodwill [Line Items]    
Goodwill $ 598 $ 598
Transmission Segment | Operating Segments | JERSEY CENTRAL POWER & LIGHT COMPANY | Minimum    
Goodwill [Line Items]    
Useful Service Life 5 years 55 years
Transmission Segment | Operating Segments | JERSEY CENTRAL POWER & LIGHT COMPANY | Maximum    
Goodwill [Line Items]    
Useful Service Life 80 years 80 years
Distribution | Operating Segments | Minimum    
Goodwill [Line Items]    
Useful Service Life 5 years 5 years
Distribution | Operating Segments | Maximum    
Goodwill [Line Items]    
Useful Service Life 80 years 80 years
Distribution | Operating Segments | JERSEY CENTRAL POWER & LIGHT COMPANY | Minimum    
Goodwill [Line Items]    
Useful Service Life 5 years 10 years
Distribution | Operating Segments | JERSEY CENTRAL POWER & LIGHT COMPANY | Maximum    
Goodwill [Line Items]    
Useful Service Life 75 years 75 years
v3.25.4
ORGANIZATION AND BASIS OF PRESENTATION - Schedule of Property, Plant and Equipment Balances (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Sep. 30, 2025
Jun. 30, 2025
Mar. 31, 2025
Dec. 31, 2024
Sep. 30, 2024
Jun. 30, 2024
Mar. 31, 2024
Dec. 31, 2023
Property, Plant and Equipment                  
In Service $ 56,213       $ 52,896        
Accumulated. Depreciation (15,189)       (14,548)        
Net Plant 41,024       38,348        
CWIP 3,389       2,754        
Total 44,413       41,102        
Finance leases 48       46        
Financing lease, accumulated amortization 17       14        
JERSEY CENTRAL POWER & LIGHT COMPANY                  
Property, Plant and Equipment                  
In Service 9,267 $ 9,057 $ 8,970 $ 8,841 8,731 $ 8,536 $ 8,474 $ 8,352 $ 8,288
Accumulated. Depreciation (2,439) (2,435) (2,464) (2,445) (2,439) (2,414) (2,400) (2,379) (2,373)
Net Plant 6,828 6,622 6,506 6,396 6,292 6,122 6,074 5,973 5,915
CWIP 880       620        
Total 7,708 $ 7,460 $ 7,232 $ 7,057 6,912 $ 6,710 $ 6,585 $ 6,473 $ 6,390
Finance leases 12       11        
Financing lease, accumulated amortization 6       5        
Corporate/Other                  
Property, Plant and Equipment                  
In Service 1,130       1,062        
Accumulated. Depreciation (646)       (607)        
Net Plant 484       455        
CWIP 60       74        
Total 544       529        
Distribution | Operating Segments                  
Property, Plant and Equipment                  
In Service 21,944       21,245        
Accumulated. Depreciation (7,511)       (7,338)        
Net Plant 14,433       13,907        
CWIP 682       618        
Total 15,115       14,525        
Distribution | Operating Segments | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Property, Plant and Equipment                  
In Service 6,679       6,438        
Accumulated. Depreciation (1,925)       (1,938)        
Net Plant 4,754       4,500        
CWIP 270       187        
Total 5,024       4,687        
Integrated | Operating Segments                  
Property, Plant and Equipment                  
In Service 18,380       17,080        
Accumulated. Depreciation (4,154)       (3,943)        
Net Plant 14,226       13,137        
CWIP 1,314       1,076        
Total 15,540       14,213        
Stand-Alone Transmission | Operating Segments                  
Property, Plant and Equipment                  
In Service 14,759       13,509        
Accumulated. Depreciation (2,878)       (2,660)        
Net Plant 11,881       10,849        
CWIP 1,333       986        
Total 13,214       11,835        
Transmission | Operating Segments | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Property, Plant and Equipment                  
In Service 2,588       2,293        
Accumulated. Depreciation (514)       (501)        
Net Plant 2,074       1,792        
CWIP 610       433        
Total $ 2,684       $ 2,225        
Minimum | Corporate/Other                  
Property, Plant and Equipment                  
Useful Service Life 3 years       3 years        
Minimum | Distribution | Operating Segments                  
Property, Plant and Equipment                  
Useful Service Life 5 years       5 years        
Minimum | Distribution | Operating Segments | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Property, Plant and Equipment                  
Useful Service Life 5 years       10 years        
Minimum | Integrated | Operating Segments                  
Property, Plant and Equipment                  
Useful Service Life 5 years       5 years        
Minimum | Stand-Alone Transmission | Operating Segments                  
Property, Plant and Equipment                  
Useful Service Life 5 years       5 years        
Minimum | Transmission | Operating Segments | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Property, Plant and Equipment                  
Useful Service Life 5 years       55 years        
Maximum | Corporate/Other                  
Property, Plant and Equipment                  
Useful Service Life 63 years       63 years        
Maximum | Distribution | Operating Segments                  
Property, Plant and Equipment                  
Useful Service Life 80 years       80 years        
Maximum | Distribution | Operating Segments | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Property, Plant and Equipment                  
Useful Service Life 75 years       75 years        
Maximum | Integrated | Operating Segments                  
Property, Plant and Equipment                  
Useful Service Life 80 years       100 years        
Maximum | Stand-Alone Transmission | Operating Segments                  
Property, Plant and Equipment                  
Useful Service Life 85 years       85 years        
Maximum | Transmission | Operating Segments | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Property, Plant and Equipment                  
Useful Service Life 80 years       80 years        
v3.25.4
REVENUE - Narrative (Details)
 12 Months Ended
Dec. 31, 2025
Disaggregation of Revenue [Line Items]  
Utility customer payment period 30 days
v3.25.4
REVENUE - Schedule of Disaggregation of Revenue (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Disaggregation of Revenue [Line Items]      
Total revenues [1] $ 15,090 $ 13,472 $ 12,870
JERSEY CENTRAL POWER & LIGHT COMPANY      
Disaggregation of Revenue [Line Items]      
Total revenues 2,638 2,315 2,027
Operating Segments      
Disaggregation of Revenue [Line Items]      
Total revenues 15,135 13,526 12,922
Operating Segments | JERSEY CENTRAL POWER & LIGHT COMPANY      
Disaggregation of Revenue [Line Items]      
Total revenues 2,813 2,467 2,138
Operating Segments | Distribution      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 7,465 6,783 6,779
Total revenues 7,547 6,863 6,854
Operating Segments | Distribution | JERSEY CENTRAL POWER & LIGHT COMPANY      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 2,550 2,211 1,931
Total revenues 2,554 2,225 1,934
Operating Segments | Distribution | Wholesale      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 16 6 20
Operating Segments | Distribution | Wholesale | JERSEY CENTRAL POWER & LIGHT COMPANY      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 6 6 5
Operating Segments | Distribution | Other revenue from contracts with customers      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 78 80 89
Operating Segments | Distribution | Other revenue from contracts with customers | JERSEY CENTRAL POWER & LIGHT COMPANY      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 14 18 18
Operating Segments | Distribution | Other revenue unrelated to contracts with customers      
Disaggregation of Revenue [Line Items]      
Total revenues 82 80 75
Operating Segments | Distribution | Other revenue unrelated to contracts with customers | JERSEY CENTRAL POWER & LIGHT COMPANY      
Disaggregation of Revenue [Line Items]      
Total revenues 4 4 3
Operating Segments | Integrated      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 5,626 4,824 4,285
Total revenues 5,683 4,876 4,320
Operating Segments | Integrated | Wholesale      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 377 146 208
Operating Segments | Integrated | Transmission      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 425 380 318
Operating Segments | Integrated | Other revenue from contracts with customers      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 6 19 24
Operating Segments | Integrated | Other revenue unrelated to contracts with customers      
Disaggregation of Revenue [Line Items]      
Total revenues 57 42 35
Operating Segments | Stand-Alone Transmission      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 1,886 1,768 1,731
Total revenues 1,905 1,787 1,748
Operating Segments | Stand-Alone Transmission | Other revenue unrelated to contracts with customers      
Disaggregation of Revenue [Line Items]      
Total revenues 19 19 17
Operating Segments | Transmission | JERSEY CENTRAL POWER & LIGHT COMPANY      
Disaggregation of Revenue [Line Items]      
Total revenues 259 242 204
Operating Segments | Residential | Distribution      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 4,948 4,514 4,344
Operating Segments | Residential | Distribution | JERSEY CENTRAL POWER & LIGHT COMPANY      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 1,705 1,470 1,240
Operating Segments | Residential | Integrated      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 2,877 2,528 2,137
Operating Segments | Commercial | Distribution      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 1,699 1,522 1,528
Operating Segments | Commercial | Distribution | JERSEY CENTRAL POWER & LIGHT COMPANY      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 728 627 579
Operating Segments | Commercial | Integrated      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 1,294 1,142 1,023
Operating Segments | Industrial | Distribution      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 651 588 726
Operating Segments | Industrial | Distribution | JERSEY CENTRAL POWER & LIGHT COMPANY      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 76 70 68
Operating Segments | Industrial | Integrated      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 615 577 545
Operating Segments | Street lighting | Distribution | JERSEY CENTRAL POWER & LIGHT COMPANY      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 21 20 21
Operating Segments | Other | Distribution      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 73 73 72
Operating Segments | Other | Integrated      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 32 32 30
Operating Segments | ARP | Distribution | JERSEY CENTRAL POWER & LIGHT COMPANY      
Disaggregation of Revenue [Line Items]      
Total revenues 0 10 0
Operating Segments | ARP | Integrated | ARP      
Disaggregation of Revenue [Line Items]      
Total revenues 0 10 0
Operating Segments | ATSI | Stand-Alone Transmission      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 1,058 980 967
Operating Segments | TrAIL | Stand-Alone Transmission      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 260 269 279
Operating Segments | MAIT | Stand-Alone Transmission      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 483 436 394
Operating Segments | KATCo | Stand-Alone Transmission      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 85 85 89
Operating Segments | Other | Stand-Alone Transmission      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 0 (2) 2
Corporate/Other and Reconciling Adjustments      
Disaggregation of Revenue [Line Items]      
Total revenues (45) (54) (52)
Corporate/Other and Reconciling Adjustments | Wholesale      
Disaggregation of Revenue [Line Items]      
Total revenues from contracts with customers 18 9 11
Corporate/Other and Reconciling Adjustments | Eliminations and reconciling adjustments      
Disaggregation of Revenue [Line Items]      
Total revenues (63) (63) (63)
Reconciling Adjustments      
Disaggregation of Revenue [Line Items]      
Total revenues (63) (63) (63)
Reconciling Adjustments | JERSEY CENTRAL POWER & LIGHT COMPANY      
Disaggregation of Revenue [Line Items]      
Total revenues $ (175) $ (152) $ (111)
[1] Includes excise and gross receipts tax collections of $463 million, $429 million and $420 million in 2025, 2024 and 2023, respectively.
v3.25.4
REVENUE - Schedule of Receivables from Customers (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Accounts, Notes, Loans and Financing Receivable [Line Items]    
Customers $ 1,783 $ 1,585
Less: Uncollectible Reserve 57 55
Receivable 1,726 1,530
JERSEY CENTRAL POWER & LIGHT COMPANY    
Accounts, Notes, Loans and Financing Receivable [Line Items]    
Customers 330 284
Less: Uncollectible Reserve 6 6
Receivable 324 278
Billed    
Accounts, Notes, Loans and Financing Receivable [Line Items]    
Customers 939 867
Billed | JERSEY CENTRAL POWER & LIGHT COMPANY    
Accounts, Notes, Loans and Financing Receivable [Line Items]    
Customers 178 166
Billed | Financial Asset, Greater than 30 Days Past Due    
Accounts, Notes, Loans and Financing Receivable [Line Items]    
Customers 323 284
Unbilled    
Accounts, Notes, Loans and Financing Receivable [Line Items]    
Customers 844 718
Unbilled | JERSEY CENTRAL POWER & LIGHT COMPANY    
Accounts, Notes, Loans and Financing Receivable [Line Items]    
Customers $ 152 $ 118
v3.25.4
REVENUE - Schedule of Activity in the Allowance for Uncollectible Accounts on Customer Receivables and Other Receivables (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Customer Receivables      
Accounts Receivable, Allowance for Credit Loss [Roll Forward]      
Beginning balance $ 55 $ 64 $ 137
Provision for expected credit losses 94 73 8
Charged to other accounts 37 39 34
Write-offs (129) (121) (115)
Ending balance 57 55 64
Deferred future recovery (refund) 31 17 (15)
Customer Receivables | JERSEY CENTRAL POWER & LIGHT COMPANY      
Accounts Receivable, Allowance for Credit Loss [Roll Forward]      
Beginning balance 6 9 21
Provision for expected credit losses 8 5 (1)
Charged to other accounts 3 4 3
Write-offs (11) (12) (14)
Ending balance 6 6 9
Deferred future recovery (refund) 8 5 (1)
Other Receivables      
Accounts Receivable, Allowance for Credit Loss [Roll Forward]      
Beginning balance 6 15 11
Provision for expected credit losses 9 1 7
Charged to other accounts 0 (5) (1)
Write-offs (4) (5) (2)
Ending balance 11 6 15
Other Receivables | JERSEY CENTRAL POWER & LIGHT COMPANY      
Accounts Receivable, Allowance for Credit Loss [Roll Forward]      
Beginning balance 0 6 6
Provision for expected credit losses 1 0 0
Charged to other accounts 0 (6) 0
Write-offs (1) 0 0
Ending balance $ 0 $ 0 $ 6
v3.25.4
EARNINGS PER SHARE OF COMMON STOCK - Schedule of Reconciliation of Basic and Diluted EPS Attributable to FE (Details) - USD ($)
$ / shares in Units, shares in Millions, $ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Earnings Per Share [Abstract]      
Earnings Attributable to FE - continuing operations $ 1,020 $ 978 $ 1,123
Earnings Attributable to FE - discontinued operations, net of tax [1] 0 0 (21)
EARNINGS ATTRIBUTABLE TO FIRSTENERGY CORP. $ 1,020 $ 978 $ 1,102
Share Count information:      
Weighted average number of basic shares outstanding (in shares) 577 575 573
Assumed exercise of dilutive share-based awards (in shares) 1 2 1
Weighted average number of diluted shares outstanding (in shares) 578 577 574
EPS Attributable to FE:      
Income from continuing operations, basic (in dollars per share) $ 1.77 $ 1.70 $ 1.96
Discontinued operations, basic (in dollars per share) 0 0 (0.04)
Basic EPS (in dollars per share) 1.77 1.70 1.92
Income from continuing operations, diluted (in dollars per share) 1.76 1.70 1.96
Discontinued operations, diluted (in dollars per share) 0 0 (0.04)
Diluted EPS (in dollars per share) $ 1.76 $ 1.70 $ 1.92
[1] Consists of income taxes of $21 million in 2023.
v3.25.4
EARNINGS PER SHARE OF COMMON STOCK - Narrative (Details) - $ / shares
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Notes Maturity 2029 & 2031 | Convertible Debt      
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]      
Debt instrument, conversation price (in dollars per share) $ 47.78 $ 47.78 $ 47.78
Convertible Notes 2026 | Convertible Debt      
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]      
Debt instrument, conversation price (in dollars per share) $ 46.42    
Stock Options      
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]      
Antidilutive securities excluded from computation of EPS (in shares) 0 0 0
v3.25.4
PENSION AND OTHER POSTEMPLOYMENT BENEFITS - Narrative (Details)
employee in Thousands, $ in Millions
 1 Months Ended 12 Months Ended
Jan. 31, 2025
USD ($)
employee
Dec. 31, 2025
USD ($)
Dec. 31, 2024
USD ($)
Dec. 31, 2023
USD ($)
Defined Benefit Plan Disclosure [Line Items]        
Employee benefit plan funding and related payments   $ 49 $ 59 $ 50
JERSEY CENTRAL POWER & LIGHT COMPANY        
Defined Benefit Plan Disclosure [Line Items]        
Employee benefit plan funding and related payments   0 7 7
Mark-to-market adjustment, net of capitalized amounts   $ 10 2 (31)
Pension        
Defined Benefit Plan Disclosure [Line Items]        
Weighted-average discount rate   8.00%    
Expected future contributions   $ 250    
Pension | MetLife        
Defined Benefit Plan Disclosure [Line Items]        
Transfer of plan assets $ 640      
Transfer of benefit obligations $ 652      
Defined benefit plan, number of covered employees by plan | employee 2      
Pensions and OPEB        
Defined Benefit Plan Disclosure [Line Items]        
Pension & OPEB mark-to-market adjustments   (253)    
Pensions and OPEB | JERSEY CENTRAL POWER & LIGHT COMPANY        
Defined Benefit Plan Disclosure [Line Items]        
Mark-to-market adjustment, net of capitalized amounts   45 22 2
Pensions and OPEB | JCP&L        
Defined Benefit Plan Disclosure [Line Items]        
Pension & OPEB mark-to-market adjustments   55    
Pensions and OPEB | Integrated        
Defined Benefit Plan Disclosure [Line Items]        
Mark-to-market adjustment, net of capitalized amounts   $ (29) $ (8) $ 36
v3.25.4
PENSION AND OTHER POSTEMPLOYMENT BENEFITS - Schedule of Assumptions Used to Determine Net Periodic Benefit Cost (Details)
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Pension      
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]      
Discount rate 5.59% 5.72% 5.05%
Rate of compensation increase 4.30% 4.30% 4.30%
Cash balance weighted average interest crediting rate 4.64% 4.37% 4.94%
Effective rate for interest on benefit obligations 5.41% 4.92%  
Effective rate for service costs 5.89% 5.17%  
Effective rate for interest on service costs 5.66% 5.05%  
Expected return on plan assets 8.50% 8.00% 8.00%
Rate of compensation increase 4.30% 4.30% 4.30%
Pension | Minimum      
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]      
Effective rate for interest on benefit obligations     5.10%
Effective rate for service costs     5.34%
Effective rate for interest on service costs     5.22%
Pension | Maximum      
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]      
Effective rate for interest on benefit obligations     4.80%
Effective rate for service costs     5.11%
Effective rate for interest on service costs     4.94%
OPEB      
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]      
Discount rate 5.37% 5.60% 4.97%
Effective rate for interest on benefit obligations 5.28% 4.88%  
Effective rate for service costs 5.98% 5.23%  
Effective rate for interest on service costs 5.88% 5.16%  
Expected return on plan assets 7.00% 7.00% 7.00%
Rate to which the cost trend rate is assumed to decline (ultimate trend rate) 4.50% 4.50% 4.50%
OPEB | Minimum      
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]      
Effective rate for interest on benefit obligations     5.06%
Effective rate for service costs     5.41%
Effective rate for interest on service costs     5.33%
Other Postretirement Benefits Plan - Pre Medicare      
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]      
Health care cost trend rate assumed (pre/post-Medicare) 6.50% 7.00% 7.00%
Other Postretirement Benefits Plan - Post Medicare      
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]      
Health care cost trend rate assumed (pre/post-Medicare) 5.80% 6.00% 6.50%
v3.25.4
PENSION AND OTHER POSTEMPLOYMENT BENEFITS - Schedule of Assumed Rate of Return on Pension Plan Assets Considers Historical Market Returns and Economic Forecasts (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Pensions and OPEB      
Defined Benefit Plan Disclosure [Line Items]      
Actual gains or (losses) on plan assets $ 880 $ 3 $ 751
Actual gains or (losses) on plan assets, percent 15.40% 0.70% 11.20%
Expected return on plan assets $ 499 $ 565 $ 601
Pension      
Defined Benefit Plan Disclosure [Line Items]      
Actual gains or (losses) on plan assets 809 (62)  
Expected return on plan assets $ 461 $ 530 $ 570
Expected return on plan assets, percent 8.50% 8.00% 8.00%
OPEB      
Defined Benefit Plan Disclosure [Line Items]      
Actual gains or (losses) on plan assets $ 71 $ 65  
Expected return on plan assets $ 38 $ 35 $ 31
Expected return on plan assets, percent 7.00% 7.00% 7.00%
v3.25.4
PENSION AND OTHER POSTEMPLOYMENT BENEFITS - Schedule of Components of Net Periodic Benefit Costs (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Pension      
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]      
Service cost $ 131 $ 140 $ 139
Interest cost 374 398 428
Expected return on plan assets (461) (530) (570)
Amortization of prior service costs (credits) 1 2 2
Special termination benefits 0 0 21
Pension & OPEB mark-to-market adjustments (231) 66 108
Net periodic benefit costs (credits) (186) 76 128
OPEB      
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]      
Service cost 2 3 2
Interest cost 20 20 21
Expected return on plan assets (38) (35) (31)
Amortization of prior service costs (credits) (1) (1) (8)
Special termination benefits 0 0 8
Pension & OPEB mark-to-market adjustments (22) (44) (30)
Net periodic benefit costs (credits) $ (39) $ (57) $ (38)
v3.25.4
PENSION AND OTHER POSTEMPLOYMENT BENEFITS - Schedule of Obligations and Funded Status (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Pension      
Change in benefit obligation:      
Benefit obligation as of January 1 $ 7,824 $ 8,363  
Service cost 131 140 $ 139
Interest cost 374 398 428
Plan participants’ contributions 0 0  
Medicare retiree drug subsidy 0 0  
Lift-out transaction (652) 0  
Actuarial loss (gain) 129 (526)  
Benefits paid (526) (551)  
Benefit obligation as of December 31 7,280 7,824 8,363
Change in fair value of plan assets:      
Fair value of plan assets as of January 1 6,296 6,879  
Actual return on plan assets 809 (62)  
Lift-out transaction (640) 0  
Company contributions 28 30  
Plan participants’ contributions 0 0  
Benefits paid (526) (551)  
Fair value of plan assets as of December 31 5,967 6,296 6,879
Funded Status:      
Funded Status - Net asset (liability) as of December 31 (1,313) (1,528)  
Accumulated benefit obligation 7,047 7,572  
Amounts Recognized in AOCI:      
Prior service cost (credit) 1 2  
Pension | Qualified plan      
Funded Status:      
Funded Status - Net asset (liability) as of December 31 (952) (1,165)  
Pension | Non-qualified plans      
Funded Status:      
Funded Status - Net asset (liability) as of December 31 (361) (363)  
OPEB      
Change in benefit obligation:      
Benefit obligation as of January 1 407 441  
Service cost 2 3 2
Interest cost 20 20 21
Plan participants’ contributions 3 4  
Medicare retiree drug subsidy 0 1  
Lift-out transaction 0 0  
Actuarial loss (gain) 11 (14)  
Benefits paid (45) (48)  
Benefit obligation as of December 31 398 407 441
Change in fair value of plan assets:      
Fair value of plan assets as of January 1 567 516  
Actual return on plan assets 71 65  
Lift-out transaction 0 0  
Company contributions 21 30  
Plan participants’ contributions 3 4  
Benefits paid (45) (48)  
Fair value of plan assets as of December 31 617 567 $ 516
Funded Status:      
Funded Status - Net asset (liability) as of December 31 219 160  
Accumulated benefit obligation 0 0  
Amounts Recognized in AOCI:      
Prior service cost (credit) 1 1  
OPEB | Qualified plan      
Funded Status:      
Funded Status - Net asset (liability) as of December 31 0 0  
OPEB | Non-qualified plans      
Funded Status:      
Funded Status - Net asset (liability) as of December 31 $ 0 $ 0  
v3.25.4
PENSION AND OTHER POSTEMPLOYMENT BENEFITS - Schedule of Pension Investments Measured at Fair Value (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Pension    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value $ 5,941 $ 6,249
Asset Allocation 100.00% 100.00%
Excluded from total investments $ 26 $ 47
Pension | Investments Excluding in Investments at NAV    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value $ 3,888 $ 4,130
Asset Allocation 65.00% 66.00%
Pension | Cash and short-term securities    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value $ 402 $ 1,173
Asset Allocation 7.00% 19.00%
Pension | Public equity    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value $ 1,982 $ 1,590
Asset Allocation 33.00% 25.00%
Pension | Fixed income    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value $ 1,507 $ 1,425
Asset Allocation 25.00% 23.00%
Pension | Derivatives    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value   $ (58)
Asset Allocation   (1.00%)
Pension | Derivatives    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value $ (3)  
Asset Allocation 0.00%  
Pension | Private - equity and debt funds    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value $ 1,278 $ 1,273
Asset Allocation 22.00% 20.00%
Pension | Insurance-linked securities    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value $ 7 $ 39
Asset Allocation 0.00% 1.00%
Pension | Hedge funds    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value $ 270 $ 253
Asset Allocation 5.00% 4.00%
Pension | Real estate funds    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value $ 498 $ 554
Asset Allocation 8.00% 9.00%
Pension | Level 1 | Investments Excluding in Investments at NAV    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value $ 1,955 $ 1,490
Pension | Level 1 | Cash and short-term securities    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 0 0
Pension | Level 1 | Public equity    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 1,976 1,585
Pension | Level 1 | Fixed income    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 0 0
Pension | Level 1 | Derivatives    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value   (95)
Pension | Level 1 | Derivatives    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value (21)  
Pension | Level 2 | Investments Excluding in Investments at NAV    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 1,933 2,640
Pension | Level 2 | Cash and short-term securities    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 402 1,173
Pension | Level 2 | Public equity    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 6 5
Pension | Level 2 | Fixed income    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 1,507 1,425
Pension | Level 2 | Derivatives    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value   37
Pension | Level 2 | Derivatives    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 18  
Pension | Level 3 | Investments Excluding in Investments at NAV    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 0 0
Pension | Level 3 | Cash and short-term securities    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 0 0
Pension | Level 3 | Public equity    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 0 0
Pension | Level 3 | Fixed income    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 0 0
Pension | Level 3 | Derivatives    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value   0
Pension | Level 3 | Derivatives    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 0  
OPEB    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value $ 630 $ 572
Asset Allocation 100.00% 100.00%
Excluded from total investments $ (13) $ (5)
OPEB | Cash and short-term securities    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value $ 128 $ 112
Asset Allocation 20.00% 20.00%
OPEB | Public equity    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value $ 361 $ 314
Asset Allocation 57.00% 55.00%
OPEB | Fixed income    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value $ 141 $ 146
Asset Allocation 23.00% 25.00%
OPEB | Level 1    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value $ 361 $ 314
OPEB | Level 1 | Cash and short-term securities    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 0 0
OPEB | Level 1 | Public equity    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 361 314
OPEB | Level 1 | Fixed income    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 0 0
OPEB | Level 2    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 269 258
OPEB | Level 2 | Cash and short-term securities    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 128 112
OPEB | Level 2 | Public equity    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 0 0
OPEB | Level 2 | Fixed income    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 141 146
OPEB | Level 3    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 0 0
OPEB | Level 3 | Cash and short-term securities    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 0 0
OPEB | Level 3 | Public equity    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value 0 0
OPEB | Level 3 | Fixed income    
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]    
Pension investments measured at fair value $ 0 $ 0
v3.25.4
PENSION AND OTHER POSTEMPLOYMENT BENEFITS - Schedule of Target Asset Allocations for Pension and OPEB Portfolio (Details)
Dec. 31, 2025
Pension  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Target Asset Allocations 100.00%
OPEB  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Target Asset Allocations 100.00%
Equities | Pension  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Target Asset Allocations 30.00%
Equities | OPEB  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Target Asset Allocations 50.00%
Fixed income | Pension  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Target Asset Allocations 28.50%
Fixed income | OPEB  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Target Asset Allocations 50.00%
Alternative investments | Pension  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Target Asset Allocations 5.00%
Alternative investments | OPEB  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Target Asset Allocations 0.00%
Real estate | Pension  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Target Asset Allocations 10.00%
Real estate | OPEB  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Target Asset Allocations 0.00%
Private - equity and debt funds | Pension  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Target Asset Allocations 20.00%
Private - equity and debt funds | OPEB  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Target Asset Allocations 0.00%
Cash and derivatives | Pension  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Target Asset Allocations 6.50%
Cash and derivatives | OPEB  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Target Asset Allocations 0.00%
v3.25.4
PENSION AND OTHER POSTEMPLOYMENT BENEFITS - Schedule of Estimated Future Benefit Payments (Details)
$ in Millions
Dec. 31, 2025
USD ($)
Pension Benefit Payments  
Estimated Future Benefit Payments  
2026 $ 517
2027 522
2028 526
2029 530
2030 532
Years 2031-2035 2,660
OPEB  
Estimated Future Benefit Payments  
2026 40
2027 39
2028 38
2029 37
2030 35
Years 2031-2035 155
Defined Benefit Plan, Expected Future Prescription Drug Subsidy Receipt [Abstract]  
2026 (1)
2027 (1)
2028 0
2029 0
2030 0
Years 2031-2035 $ (2)
v3.25.4
PENSION AND OTHER POSTEMPLOYMENT BENEFITS - Schedule of JCP&L’s Net Periodic Benefit Costs (Credits) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Defined Benefit Plan Disclosure [Line Items]      
Other noncurrent liabilities $ 2,513 $ 2,525  
JERSEY CENTRAL POWER & LIGHT COMPANY      
Defined Benefit Plan Disclosure [Line Items]      
Mark-to-market adjustment, net of capitalized amounts 10 2 $ (31)
Contributions from affiliates   7  
Non-current mark-to-market adjustment, net 492 502  
Other noncurrent liabilities 763 764  
Pension      
Defined Benefit Plan Disclosure [Line Items]      
JCP&L's share of net periodic benefit credits (186) 76 128
Pension | JERSEY CENTRAL POWER & LIGHT COMPANY      
Defined Benefit Plan Disclosure [Line Items]      
JCP&L's share of net periodic benefit credits (37) (12) 10
Allocated net periodic benefit costs from affiliates (1) 6 40
JCP&L's share of Parent funded status (29) (67)  
OPEB      
Defined Benefit Plan Disclosure [Line Items]      
JCP&L's share of net periodic benefit credits (39) (57) (38)
OPEB | JERSEY CENTRAL POWER & LIGHT COMPANY      
Defined Benefit Plan Disclosure [Line Items]      
JCP&L's share of net periodic benefit credits (28) (27) (29)
Allocated net periodic benefit costs from affiliates 1 0 1
JCP&L's share of Parent funded status 243 215  
Pensions and OPEB | JERSEY CENTRAL POWER & LIGHT COMPANY      
Defined Benefit Plan Disclosure [Line Items]      
Mark-to-market adjustment, net of capitalized amounts $ 45 $ 22 $ 2
v3.25.4
STOCK-BASED COMPENSATION PLANS - Narrative (Details)
$ / shares in Units, $ in Millions
 12 Months Ended
Dec. 31, 2025
USD ($)
$ / shares
shares
Dec. 31, 2024
USD ($)
$ / shares
shares
Dec. 31, 2023
USD ($)
$ / shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Realized tax benefits $ 7 $ 17 $ 6
Tax benefit associated with stock-based compensation expense 1 5 $ 6
EDCP      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Net liability recognized 153 166  
EDCP | JERSEY CENTRAL POWER & LIGHT COMPANY      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Net liability recognized $ 3 3  
DCPD      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Net liability recognized   $ 4  
Restricted stock units      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Stock-based compensation award vesting period 3 years 3 years 3 years
Award paid in cash, percentage   33.33%  
Award paid in stock, percentage   66.67%  
Unrecognized cost, period for recognition 3 years 3 years 3 years
Granted (in dollars per share) | $ / shares $ 39.94 $ 36.79 $ 38.36
Fair value of restricted stock units vested $ 23 $ 55 $ 24
Unrecognized cost $ 38    
Performance-based Restricted Stock Units      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Weighted total shareholder return percentage, performance measure one 0.35 0.35  
Weighted total shareholder return percentage, performance measure two 0.65 0.65  
Cumulative earnings targets period 3 years 3 years  
Award performance period 3 years 3 years  
Award paid in stock, percentage 60.00%    
Maximum payout of awards during negative performance period 100.00% 100.00%  
Liability recognized $ 17    
Cash portion of RSU paid $ 6    
Time-Based Restricted Stock Units      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Stock-based compensation award vesting period 3 years    
Award paid in stock, percentage 40.00%    
Restricted stock      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Unrecognized cost, period for recognition 2 years 6 months    
Granted (in dollars per share) | $ / shares $ 41.98    
Fair value of restricted stock units vested $ 3    
Share-based payment arrangement, nonvested award, cost not yet recognized, weighted average vesting period 1 year 10 months 9 days    
Minimum      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Stock-based compensation award vesting period 1 year    
Maximum      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Stock-based compensation award vesting period 4 years    
ICP 2015      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Share-based compensation arrangement by share-based payment award, number of shares authorized (in shares) | shares 10,000,000    
ICP 2020      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Share-based compensation arrangement by share-based payment award, number of shares authorized (in shares) | shares 10,000,000    
Share-based compensation arrangement by share-based payment, award, number of shares available for grant (in shares) | shares 7,400,000    
ICP 2020 | Maximum      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Stock-based compensation award vesting period 4 years    
401(k) savings plan      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Shares authorized for issuance (in shares) | shares 1,000,000 1,000,000  
v3.25.4
STOCK-BASED COMPENSATION PLANS - Schedule of Stock-based Compensation Expense (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Total stock based compensation costs $ 85 $ 86 $ 83
Stock-based compensation costs, net of amounts capitalized 39 43 44
401(k) savings plan      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Total stock based compensation costs 39 41 38
EDCP & DCPD      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Total stock based compensation costs 7 6 1
Restricted stock units | Incentive Plans      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Total stock based compensation costs 35 32 39
Restricted stock | Incentive Plans      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Total stock based compensation costs $ 4 $ 7 $ 5
v3.25.4
STOCK-BASED COMPENSATION PLANS - Schedule of Nonvested Restricted Stock Units Activity (Details) - $ / shares
shares in Thousands
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Weighted-Average Grant Date Fair Value (per share)      
Dividend shares earned during period, number of shares (in shares) 67    
Restricted stock units      
Shares (in millions)      
Nonvested, beginning balance (in shares) 2,800    
Granted (in shares) 1,100    
Forfeited (in shares) (400)    
Vested (in shares) (600)    
Nonvested, ending balance (in shares) 2,900 2,800  
Weighted-Average Grant Date Fair Value (per share)      
Beginning balance (in dollars per share) $ 37.32    
Granted (in dollars per share) 39.94 $ 36.79 $ 38.36
Forfeited (in dollars per share) 39.48    
Vested (in dollars per share) 38.38    
Ending balance (in dollars per share) $ 36.38 $ 37.32  
Restricted stock      
Shares (in millions)      
Nonvested, beginning balance (in shares) 270    
Granted (in shares) 60    
Forfeited (in shares) (10)    
Vested (in shares) (80)    
Nonvested, ending balance (in shares) 240 270  
Weighted-Average Grant Date Fair Value (per share)      
Beginning balance (in dollars per share) $ 38.29    
Granted (in dollars per share) 41.98    
Forfeited (in dollars per share) 38.16    
Vested (in dollars per share) 39.71    
Ending balance (in dollars per share) $ 38.70 $ 38.29  
v3.25.4
TAXES - Narrative (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Mar. 31, 2024
Mar. 25, 2024
Dec. 31, 2023
May 31, 2022
Provision for Income Tax [Line Items]            
Net deferred income tax liability $ 6,032 $ 5,613 $ 46      
Deferred tax assets     $ 803      
Corporate AMT credit carryforwards, not subject to expiration 18          
State and Local Jurisdiction            
Provision for Income Tax [Line Items]            
Operating loss carryforwards, not subject to expiration 13,700          
Operating loss carryforwards, not subject to expiration, net of tax 447          
Pre-tax net operating loss carryforwards expected to utilized 5,200          
Operating loss carryforwards expected to utilized, net of tax 226          
Federal Tax Authority            
Provision for Income Tax [Line Items]            
Operating loss carryforwards, not subject to expiration 2,200          
Operating loss carryforwards, not subject to expiration, net of tax 454          
JERSEY CENTRAL POWER & LIGHT COMPANY            
Provision for Income Tax [Line Items]            
Net deferred income tax liability 1,348 $ 1,192        
JERSEY CENTRAL POWER & LIGHT COMPANY | State and Local Jurisdiction            
Provision for Income Tax [Line Items]            
Pre-tax net operating loss carryforwards expected to utilized 1,900          
Operating loss carryforwards expected to utilized, net of tax 135          
JERSEY CENTRAL POWER & LIGHT COMPANY | Federal Tax Authority            
Provision for Income Tax [Line Items]            
Operating loss carryforwards, not subject to expiration 299          
Operating loss carryforwards, not subject to expiration, net of tax $ 63          
JCP&L            
Provision for Income Tax [Line Items]            
Income tax examination, liability (refund) adjustment from settlement with taxing authority         $ 9  
Brookfield II | FET            
Provision for Income Tax [Line Items]            
Operating loss carryforwards, subject to expiration       $ 7,000    
Sale of ownership interest by parent     19.90% 49.90%   19.90%
v3.25.4
TAXES - Schedule of Provision for Income Taxes (Benefits) (Details) - USD ($)
$ in Millions
 3 Months Ended 6 Months Ended 9 Months Ended 12 Months Ended
Sep. 30, 2025
Jun. 30, 2025
Mar. 31, 2025
Sep. 30, 2024
Jun. 30, 2024
Mar. 31, 2024
Jun. 30, 2025
Jun. 30, 2024
Sep. 30, 2025
Sep. 30, 2024
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Currently payable/Currently receivable                          
Federal                     $ 58 $ 32 $ 14
State                     11 29 1
Currently payable (receivable) Total                     69 61 15
Deferred, net -                          
Federal                     135 190 279
State                     88 130 (24)
Deferred Tax Total                     223 320 255
Investment tax credit amortization                     (4) (4) (3)
Total income taxes on income from continuing operations                     288 377 267
Discontinued Operations, Disposed of by Means Other than Sale | FES and FENOC | Federal                          
Deferred, net -                          
Federal                         21
JERSEY CENTRAL POWER & LIGHT COMPANY                          
Currently payable/Currently receivable                          
Federal                     (36) (143) (7)
State                     0 0 (8)
Currently payable (receivable) Total                     (36) (143) (15)
Deferred, net -                          
Federal                     108 200 34
State                     35 30 14
Deferred Tax Total                     143 230 48
Total income taxes on income from continuing operations $ 40 $ 20 $ 16 $ 40 $ 20 $ (4) $ 36 $ 16 $ 76 $ 56 $ 107 $ 87 $ 33
v3.25.4
TAXES - Schedule of Reconciliation of Federal Income Tax Expense (Details) - USD ($)
$ in Millions
 3 Months Ended 6 Months Ended 9 Months Ended 12 Months Ended
Sep. 30, 2025
Jun. 30, 2025
Mar. 31, 2025
Sep. 30, 2024
Jun. 30, 2024
Mar. 31, 2024
Jun. 30, 2025
Jun. 30, 2024
Sep. 30, 2025
Sep. 30, 2024
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Amount                          
Income before income taxes                     $ 1,559 $ 1,504 $ 1,464
Federal statutory income tax                     327 316 307
Tax credits                     (5) (6) (6)
AFUDC equity income                     (23) (13) (9)
AFUDC equity depreciation                     4 1 6
Nondeductible SEC and OAG Settlements                       27  
Tax related to FE's equity investment in FET                     13 16  
Changes in valuation allowances                     3 1 (33)
Excess deferred tax amortization                     (42) (52) (46)
Remeasurement of excess deferred income taxes                     (70) (43)  
Federal and state related flow-through                     (37) (18) (27)
Deductions associated with certain equity investments                       (19)  
Deferred taxes associated with FET equity interest sale                     6 6 58
Other                     2 6 9
Changes in unrecognized tax benefits                     1   41
State and municipal income taxes, net of federal effect                     109 155 (33)
Total income taxes on income from continuing operations                     $ 288 $ 377 $ 267
Percent                          
Federal statutory income tax                     21.00% 21.00% 21.00%
Tax credits                     (0.30%) (0.40%) (0.40%)
AFUDC equity income                     (1.50%) (0.90%) (0.60%)
AFUDC equity depreciation                     0.30% 0.10% 0.40%
Nondeductible SEC and OAG Settlements                       1.80%  
Tax related to FE's equity investment in FET                     0.80% 1.10%  
Changes in valuation allowances                     0.20% 0.10% (2.30%)
Excess deferred tax amortization                     (2.70%) (3.50%) (3.10%)
Remeasurement of excess deferred income taxes                     (4.50%) (2.90%)  
Federal and state related flow-through                     (2.40%) (1.20%) (1.80%)
Deductions associated with certain equity investments                       (1.30%)  
Deferred taxes associated with FET equity interest sale                     0.40% 0.40% 4.00%
Other                     0.10% 0.40% 0.60%
Changes in unrecognized tax benefits                     0.10%   2.80%
State and municipal income taxes, net of federal effect                     7.00% 10.30% (2.30%)
Total income taxes                     18.50% 25.10% 18.20%
JERSEY CENTRAL POWER & LIGHT COMPANY                          
Amount                          
Income before income taxes $ 158 $ 82 $ 63 $ 147 $ 75 $ (13) $ 145 $ 63 $ 303 $ 209 $ 413 $ 329 $ 158
Federal statutory income tax                     87 69 33
Tax credits                     0 0 0
AFUDC equity income                     (6) (1) (1)
AFUDC equity depreciation                     0 0 0
Nondeductible SEC and OAG Settlements                       0  
Tax related to FE's equity investment in FET                     0 0  
Changes in valuation allowances                     0 0 0
Excess deferred tax amortization                     (1) (4) (4)
Remeasurement of excess deferred income taxes                     0 0  
Federal and state related flow-through                     (2) 0 0
Deductions associated with certain equity investments                       0  
Deferred taxes associated with FET equity interest sale                     0 0 0
Other                     0 0 (1)
Changes in unrecognized tax benefits                     0   (28)
State and municipal income taxes, net of federal effect                     29 23 34
Total income taxes on income from continuing operations $ 40 $ 20 $ 16 $ 40 $ 20 $ (4) $ 36 $ 16 $ 76 $ 56 $ 107 $ 87 $ 33
Percent                          
Federal statutory income tax                     21.00% 21.00% 21.00%
Tax credits                     0.00% 0.00% 0.00%
AFUDC equity income                     (1.40%) (0.30%) (0.60%)
AFUDC equity depreciation                     0.00% 0.00% 0.00%
Nondeductible SEC and OAG Settlements                       0.00%  
Tax related to FE's equity investment in FET                     0.00% 0.00%  
Changes in valuation allowances                     0.00% 0.00% 0.00%
Excess deferred tax amortization                     (0.20%) (1.30%) (2.60%)
Remeasurement of excess deferred income taxes                     0.00% 0.00%  
Federal and state related flow-through                     (0.50%) 0.00% 0.00%
Deductions associated with certain equity investments                       0.00%  
Deferred taxes associated with FET equity interest sale                     0.00% 0.00% 0.00%
Other                     0.00% 0.00% (0.60%)
Changes in unrecognized tax benefits                     0.00%   (17.80%)
State and municipal income taxes, net of federal effect                     7.00% 7.00% 21.50%
Total income taxes                     25.90% 26.40% 20.90%
v3.25.4
TAXES - Schedule of Accumulated Deferred Income Taxes (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Mar. 31, 2024
Provision for Income Tax [Line Items]      
Property basis differences $ 6,579 $ 6,079  
Pension and OPEB (249) (322)  
Regulatory asset/liability 732 744  
Loss carryforwards and tax credits (920) (762)  
Valuation allowances 245 240  
Other (355) (366)  
Net accumulated deferred income tax liability 6,032 5,613 $ 46
JERSEY CENTRAL POWER & LIGHT COMPANY      
Provision for Income Tax [Line Items]      
Property basis differences 1,330 1,167  
Pension and OPEB (78) (99)  
Regulatory asset/liability 366 296  
Loss carryforwards and tax credits (199) (116)  
Nuclear fuel disposal costs (66) (59)  
Other (5) 3  
Net accumulated deferred income tax liability $ 1,348 $ 1,192  
v3.25.4
TAXES - Schedule of Pre-tax Net Operating Loss Expiration Period (Details)
$ in Millions
Dec. 31, 2025
USD ($)
State  
Pre-tax net operating loss expiration period  
Pre-tax net operating loss carryforwards for state and local income tax purposes $ 7,519
Local  
Pre-tax net operating loss expiration period  
Pre-tax net operating loss carryforwards for state and local income tax purposes 6,161
2026-2030 | State  
Pre-tax net operating loss expiration period  
Pre-tax net operating loss carryforwards for state and local income tax purposes 1,658
2026-2030 | Local  
Pre-tax net operating loss expiration period  
Pre-tax net operating loss carryforwards for state and local income tax purposes 6,161
2031-2035 | State  
Pre-tax net operating loss expiration period  
Pre-tax net operating loss carryforwards for state and local income tax purposes 1,168
2031-2035 | Local  
Pre-tax net operating loss expiration period  
Pre-tax net operating loss carryforwards for state and local income tax purposes 0
2036-2040 | State  
Pre-tax net operating loss expiration period  
Pre-tax net operating loss carryforwards for state and local income tax purposes 1,026
2036-2040 | Local  
Pre-tax net operating loss expiration period  
Pre-tax net operating loss carryforwards for state and local income tax purposes 0
2041-2045 | State  
Pre-tax net operating loss expiration period  
Pre-tax net operating loss carryforwards for state and local income tax purposes 1,216
2041-2045 | Local  
Pre-tax net operating loss expiration period  
Pre-tax net operating loss carryforwards for state and local income tax purposes 0
Indefinite | State  
Pre-tax net operating loss expiration period  
Pre-tax net operating loss carryforwards for state and local income tax purposes 2,451
Indefinite | Local  
Pre-tax net operating loss expiration period  
Pre-tax net operating loss carryforwards for state and local income tax purposes $ 0
v3.25.4
TAXES - Schedule of Changes in Valuation Allowances (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Loss Carry Forward Valuation Reserve      
Beginning of year balance $ 240 $ 226 $ 440
Charged to income 5 14 (214)
Charged to other accounts 0 0 0
Write-offs 0 0 0
End of year balance $ 245 $ 240 $ 226
v3.25.4
TAXES - Schedule of Changes in Unrecognized Tax Benefits (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Changes in unrecognized tax benefits      
Beginning balance $ 105 $ 105 $ 42
Prior years increases 0 0 88
Effectively settled with taxing authorities 0 0 (24)
Decrease for lapse in statute 0 0 (1)
Ending balance 105 105 105
JERSEY CENTRAL POWER & LIGHT COMPANY      
Changes in unrecognized tax benefits      
Beginning balance 1 1 25
Prior years increases 0 0 0
Effectively settled with taxing authorities 0 0 (24)
Decrease for lapse in statute 0 0 0
Ending balance $ 1 $ 1 $ 1
v3.25.4
TAXES - Schedule of Income Taxes Net of Refunds (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Effective Income Tax Rate Reconciliation [Line Items]      
Total Federal $ 48 $ 146 $ 49
Total State & Municipal 25 15 9
Total Income Taxes Paid (net of Refunds) 73 161 58
New Jersey      
Effective Income Tax Rate Reconciliation [Line Items]      
Total State & Municipal 0 (8) 0
Pennsylvania      
Effective Income Tax Rate Reconciliation [Line Items]      
Total State & Municipal 21 21 8
Other      
Effective Income Tax Rate Reconciliation [Line Items]      
Total State & Municipal 4 2 1
JERSEY CENTRAL POWER & LIGHT COMPANY      
Effective Income Tax Rate Reconciliation [Line Items]      
Total Federal (15) (93) (11)
Total State & Municipal 0 (8) 0
Total Income Taxes Paid (net of Refunds) (15) (101) (11)
JERSEY CENTRAL POWER & LIGHT COMPANY | New Jersey      
Effective Income Tax Rate Reconciliation [Line Items]      
Total State & Municipal 0 (8) 0
JERSEY CENTRAL POWER & LIGHT COMPANY | Pennsylvania      
Effective Income Tax Rate Reconciliation [Line Items]      
Total State & Municipal 0 0 0
JERSEY CENTRAL POWER & LIGHT COMPANY | Other      
Effective Income Tax Rate Reconciliation [Line Items]      
Total State & Municipal $ 0 $ 0 $ 0
v3.25.4
TAXES - Schedule of Details of General Taxes (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
General Taxes      
kWh excise $ 189 $ 186 $ 185
State gross receipts 278 247 235
Real and personal property 735 642 615
Social security and unemployment 126 113 113
Other 17 24 16
Total general taxes 1,345 1,212 1,164
JERSEY CENTRAL POWER & LIGHT COMPANY      
General Taxes      
Real and personal property 7 6 7
Social security and unemployment 16 15 14
Total general taxes $ 23 $ 21 $ 21
v3.25.4
LEASES - Narrative (Details)
$ in Millions
 12 Months Ended
Dec. 31, 2025
USD ($)
extensionOption
Nov. 25, 2025
USD ($)
Dec. 31, 2024
USD ($)
Nov. 30, 2024
Lessor, Lease, Description [Line Items]        
Number of options to extend | extensionOption 1      
Amount of leases $ 14      
Operating lease, right-of-use asset 276   $ 228  
Operating lease liability 287      
JERSEY CENTRAL POWER & LIGHT COMPANY        
Lessor, Lease, Description [Line Items]        
Amount of leases $ 2      
Lease agreement period       22 years
Expected commencement period of lease 18 months      
Operating lease, right-of-use asset $ 58 $ 16 $ 43  
Operating lease liability $ 67 $ 17    
Minimum        
Lessor, Lease, Description [Line Items]        
Renewal term of lease yet to be commenced 1 year      
Operating lease, term of contract 5 years      
Minimum | JERSEY CENTRAL POWER & LIGHT COMPANY        
Lessor, Lease, Description [Line Items]        
Operating lease, term of contract 5 years      
Maximum        
Lessor, Lease, Description [Line Items]        
Renewal term of lease yet to be commenced 40 years      
Operating lease, term of contract 20 years      
Maximum | JERSEY CENTRAL POWER & LIGHT COMPANY        
Lessor, Lease, Description [Line Items]        
Operating lease, term of contract 20 years      
v3.25.4
LEASES - Schedule of Components of Lease Expense (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Lessee, Lease, Description [Line Items]      
Operating lease costs $ 113 $ 91 $ 79
Amortization of right-of-use assets 3 4 8
Interest on lease liabilities 2 2 5
Total finance lease cost 5 6 13
Total lease cost 118 97 92
Short-term lease costs 45 35 27
Cash paid for amounts included in the measurement of lease liabilities:      
Operating cash flows from operating leases 71 60 54
Operating cash flows from finance leases 2 2 3
Finance cash flows from finance leases 2 2 8
Right-of-use assets obtained in exchange for lease obligations:      
Operating leases 104 69 13
Finance leases 0 0 0
JERSEY CENTRAL POWER & LIGHT COMPANY      
Lessee, Lease, Description [Line Items]      
Operating lease costs 13 11 11
Amortization of right-of-use assets 1 1 1
Interest on lease liabilities 1 1 1
Total finance lease cost 2 2 2
Total lease cost 15 13 13
Short-term lease costs 1 2 2
Cash paid for amounts included in the measurement of lease liabilities:      
Operating cash flows from operating leases 13 12 11
Operating cash flows from finance leases 1 1 1
Finance cash flows from finance leases 2 1 1
Right-of-use assets obtained in exchange for lease obligations:      
Operating leases 24 10 3
Finance leases 0 0 0
Vehicles      
Lessee, Lease, Description [Line Items]      
Operating lease costs 106 82 60
Amortization of right-of-use assets 0 1 4
Interest on lease liabilities 0 0 0
Total finance lease cost 0 1 4
Total lease cost 106 83 64
Buildings      
Lessee, Lease, Description [Line Items]      
Operating lease costs 2 3 5
Amortization of right-of-use assets 1 1 2
Interest on lease liabilities 2 2 5
Total finance lease cost 3 3 7
Total lease cost 5 6 12
Other      
Lessee, Lease, Description [Line Items]      
Operating lease costs 5 6 14
Amortization of right-of-use assets 2 2 2
Interest on lease liabilities 0 0 0
Total finance lease cost 2 2 2
Total lease cost $ 7 $ 8 $ 16
v3.25.4
LEASES - Schedule of Assets and Liabilities, Lessee (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Nov. 25, 2025
Dec. 31, 2024
Dec. 31, 2023
Weighted-average remaining lease terms (years)        
Operating leases 6 years 4 months 24 days   5 years 7 months 13 days 5 years 11 months 4 days
Finance leases 12 years 9 months 14 days   12 years 4 months 17 days 12 years 3 months 3 days
Weighted-average discount rate        
Operating leases 5.16%   5.00% 4.51%
Finance leases 16.24%   15.39% 14.73%
Assets        
Operating lease $ 276   $ 228  
Finance lease 31   32  
Total leased assets 307   260  
Current:        
Operating 60   51  
Finance 3   3  
Noncurrent:        
Operating 227   192  
Finance 7   9  
Total leased liabilities 297   255  
Operating lease assets, accumulated amortization 217   174  
Financing lease, accumulated amortization $ 17   $ 14  
Operating lease, right-of-use asset, Statement of financial position [extensible list] Other   Other  
Finance lease, right-of-use asset, Statement of financial position [extensible list] In service   In service  
Operating lease, liability, current, statement of financial position [extensible list] Other current liabilities   Other current liabilities  
Finance lease, liability, current, statement of financial position [extensible list] Long-Term Debt and Lease Obligation, Current   Long-Term Debt and Lease Obligation, Current  
Operating lease, liability, noncurrent, statement of financial position [extensible list] Other   Other  
Finance lease, liability, noncurrent, statement of financial position [extensible list] Total long-term debt and other long-term obligations   Total long-term debt and other long-term obligations  
JERSEY CENTRAL POWER & LIGHT COMPANY        
Weighted-average remaining lease terms (years)        
Operating leases 9 years 4 months 20 days   6 years 6 years 7 months 6 days
Finance leases 12 years 1 month 24 days   9 years 7 months 6 days 10 years 3 months 18 days
Weighted-average discount rate        
Operating leases 5.83%   5.76% 5.68%
Finance leases 15.94%   16.07% 16.15%
Assets        
Operating lease $ 58 $ 16 $ 43  
Finance lease 6   6  
Total leased assets 64   49  
Current:        
Operating 11   11  
Finance 2   1  
Noncurrent:        
Operating 56   43  
Finance 2   4  
Total leased liabilities 71   59  
Operating lease assets, accumulated amortization 36   30  
Financing lease, accumulated amortization $ 6   $ 5  
Operating lease, right-of-use asset, Statement of financial position [extensible list] Other   Other  
Finance lease, right-of-use asset, Statement of financial position [extensible list] In service   In service  
Operating lease, liability, current, statement of financial position [extensible list] Other current liabilities   Other current liabilities  
Finance lease, liability, current, statement of financial position [extensible list] Long-Term Debt and Lease Obligation, Current   Long-Term Debt and Lease Obligation, Current  
Operating lease, liability, noncurrent, statement of financial position [extensible list] Other   Other  
Finance lease, liability, noncurrent, statement of financial position [extensible list] Total long-term debt and other long-term obligations   Total long-term debt and other long-term obligations  
v3.25.4
LEASES - Schedule of Maturity of Operating and Finance Lease Liabilities (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Nov. 25, 2025
Dec. 31, 2024
Operating Leases      
2026 $ 72    
2027 61    
2028 58    
2029 43    
2030 29    
Thereafter 85    
Total lease payments 348    
Less imputed interest 61    
Total net present value 287    
Finance Leases      
2026 4    
2027 3    
2028 4    
2029 0    
2030 0    
Thereafter 0    
Total lease payments 11    
Less imputed interest 1    
Total net present value 10   $ 12
Total      
2026 76    
2027 64    
2028 62    
2029 43    
2030 29    
Thereafter 85    
Total lease payments 359    
Less imputed interest 62    
Total net present value 297    
Sublease income $ 6    
Sublease income term 7 years    
JERSEY CENTRAL POWER & LIGHT COMPANY      
Operating Leases      
2026 $ 13    
2027 11    
2028 13    
2029 9    
2030 7    
Thereafter 42    
Total lease payments 95    
Less imputed interest 28    
Total net present value 67 $ 17  
Finance Leases      
2026 2    
2027 2    
2028 0    
2029 0    
2030 0    
Thereafter 0    
Total lease payments 4    
Less imputed interest 0    
Total net present value 4   $ 5
Total      
2026 15    
2027 13    
2028 13    
2029 9    
2030 7    
Thereafter 42    
Total lease payments 99    
Less imputed interest 28    
Total net present value 71    
Sublease income $ 5    
Sublease income term 7 years    
v3.25.4
VARIABLE INTEREST ENTITIES (Details)
$ in Millions
Dec. 31, 2025
USD ($)
Jul. 16, 2025
Dec. 31, 2024
USD ($)
Feb. 02, 2023
Jun. 30, 2013
USD ($)
Business Combination [Line Items]          
Environmental control bonds outstanding $ 156   $ 188    
Restricted cash $ 42   43    
FET          
Business Combination [Line Items]          
Noncontrolling interest ownership percentage 49.90%        
MP, PE and the Ohio Companies          
Business Combination [Line Items]          
Restricted cash $ 40        
FE | FET          
Business Combination [Line Items]          
Minority interest ownership percentage sold percentage       0.30  
Ownership percentage by parent 50.10%        
FEV | Global Holding          
Business Combination [Line Items]          
Ownership percentage sold   0.3333      
Phase In Recovery Bonds          
Business Combination [Line Items]          
Long-term debt and other long-term obligations $ 159   $ 175    
Phase In Recovery Bonds | Ohio Funding Companies          
Business Combination [Line Items]          
Face amount of loan         $ 445
v3.25.4
ASSET RETIREMENT OBLIGATIONS - Schedule of Changes to the ARO Balances (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]    
Beginning balance $ 455 $ 209
Changes in timing and amount of estimated cash flows (51) 131
Liabilities incurred 1 95
Liabilities settled (154) (4)
Accretion 26 24
Ending balance 277 455
JERSEY CENTRAL POWER & LIGHT COMPANY    
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]    
Beginning balance 8 7
Changes in timing and amount of estimated cash flows 0 0
Liabilities incurred 0 0
Liabilities settled 0 0
Accretion 0 1
Ending balance $ 8 $ 8
v3.25.4
ASSET RETIREMENT OBLIGATIONS - Narrative (Details) - USD ($)
$ in Millions
 3 Months Ended 6 Months Ended 12 Months Ended
Mar. 04, 2025
Feb. 03, 2025
Dec. 31, 2025
Dec. 31, 2024
Jun. 30, 2024
Dec. 31, 2025
Dec. 31, 2024
Segment Reporting Information [Line Items]              
Changes in timing and amount of estimated cash flows           $ (51) $ 131
Cash payments to escrow deposit           46  
JERSEY CENTRAL POWER & LIGHT COMPANY              
Segment Reporting Information [Line Items]              
Changes in timing and amount of estimated cash flows           0 0
Other Operating Income (Expense)              
Segment Reporting Information [Line Items]              
Changes in timing and amount of estimated cash flows     $ (49) $ (49)      
Other Operating Income (Expense) | Corporate/Other              
Segment Reporting Information [Line Items]              
Changes in timing and amount of estimated cash flows       (32)      
Environmental Liability              
Segment Reporting Information [Line Items]              
Asset retirement obligation, escrow deposit $ 130 $ 160 $ 46 160   $ 46 $ 160
Agreed funding period 5 years 5 years         5 years
Recognition period 5 years            
Asset retirement obligation, discount rate 4.80%            
Environmental Liability | Weighted Average              
Segment Reporting Information [Line Items]              
Asset retirement obligation, discount rate 4.80%            
Regulation of Waste Disposal              
Segment Reporting Information [Line Items]              
Changes in timing and amount of estimated cash flows         $ 139   $ 139
Regulation of Waste Disposal | JERSEY CENTRAL POWER & LIGHT COMPANY              
Segment Reporting Information [Line Items]              
Changes in timing and amount of estimated cash flows             0
Regulation of Waste Disposal | Other Operating Income (Expense)              
Segment Reporting Information [Line Items]              
Changes in timing and amount of estimated cash flows             113
Regulation of Waste Disposal | Other Operating Income (Expense) | Corporate/Other              
Segment Reporting Information [Line Items]              
Changes in timing and amount of estimated cash flows             51
Corporate Non Segment              
Segment Reporting Information [Line Items]              
Changes in timing and amount of estimated cash flows             87
Integrated | Other Operating Income (Expense) | Operating Segments              
Segment Reporting Information [Line Items]              
Changes in timing and amount of estimated cash flows       $ (17)      
Integrated | Regulation of Waste Disposal | Other Operating Income (Expense) | Operating Segments              
Segment Reporting Information [Line Items]              
Changes in timing and amount of estimated cash flows             16
Distribution | Regulation of Waste Disposal | Other Operating Income (Expense) | Operating Segments              
Segment Reporting Information [Line Items]              
Changes in timing and amount of estimated cash flows             $ 46
v3.25.4
FAIR VALUE MEASUREMENTS - Schedule of Assets and Liabilities Measured on Recurring Basis (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Assets    
Derivative assets $ 21 $ 7
Equity securities 2 2
U.S. state debt securities 280 276
Cash, cash equivalents and restricted cash 99 154
Other 56 45
Total assets 458 484
Liabilities    
Derivative liabilities FTRs (1) 0
Total liabilities (1) 0
Net assets (liabilities) 457 484
Restricted cash $ 42 $ 43
Derivative Asset Statement Of Financial Position Extensible Enumeration Not Disclosed Flag Total assets Total assets
Level 1    
Assets    
Derivative assets $ 0 $ 0
Equity securities 2 2
U.S. state debt securities 0 0
Cash, cash equivalents and restricted cash 99 154
Other 0 0
Total assets 101 156
Liabilities    
Derivative liabilities FTRs 0 0
Total liabilities 0 0
Net assets (liabilities) 101 156
Level 2    
Assets    
Derivative assets 0 0
Equity securities 0 0
U.S. state debt securities 280 276
Cash, cash equivalents and restricted cash 0 0
Other 56 45
Total assets 336 321
Liabilities    
Derivative liabilities FTRs 0 0
Total liabilities 0 0
Net assets (liabilities) 336 321
Level 3    
Assets    
Derivative assets 21 7
Equity securities 0 0
U.S. state debt securities 0 0
Cash, cash equivalents and restricted cash 0 0
Other 0 0
Total assets 21 7
Liabilities    
Derivative liabilities FTRs (1) 0
Total liabilities (1) 0
Net assets (liabilities) $ 20 $ 7
v3.25.4
FAIR VALUE MEASUREMENTS - Schedule of Amortized Cost Basis, Unrealized Gains and Losses and Fair Values of Investments in Available-for-sale Securities (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Debt Securities, Available-for-sale [Abstract]    
Short-term cash investments $ 17 $ 6
Debt securities    
Debt Securities, Available-for-sale [Abstract]    
Cost Basis 290 299
Unrealized Gains 2 0
Unrealized Losses (12) (23)
Fair Value $ 280 $ 276
v3.25.4
FAIR VALUE MEASUREMENTS - Schedule of Proceeds from the Sale of Investments in Available-for-sale Debt Securities (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Fair Value Disclosures [Abstract]      
Sale Proceeds $ 102 $ 121 $ 38
Realized Gains 1 0 0
Realized Losses (12) (15) (3)
Interest and Dividend Income $ 13 $ 13 $ 12
v3.25.4
FAIR VALUE MEASUREMENTS - Narrative (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]      
Investments not required to be disclosed $ 344 $ 370  
Corporate-Owned Life Insurance      
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]      
Gain (loss) on investments $ 19 $ 16 $ 18
v3.25.4
FAIR VALUE MEASUREMENTS - Schedule of Fair Value and Related Carrying Amounts of Long-term Debt (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Carrying Value    
Fair value and related carrying amounts of long-term debt and other long-term obligations    
Long-term debt and other long-term obligations $ 26,390 $ 23,594
Carrying Value | JERSEY CENTRAL POWER & LIGHT COMPANY    
Fair value and related carrying amounts of long-term debt and other long-term obligations    
Long-term debt and other long-term obligations 3,050 2,350
Fair Value    
Fair value and related carrying amounts of long-term debt and other long-term obligations    
Long-term debt and other long-term obligations 25,756 22,128
Fair Value | JERSEY CENTRAL POWER & LIGHT COMPANY    
Fair value and related carrying amounts of long-term debt and other long-term obligations    
Long-term debt and other long-term obligations $ 3,059 $ 2,284
v3.25.4
CAPITALIZATION - Schedule of Dividends Declared and Paid (Details) - $ / shares
 3 Months Ended 12 Months Ended
Dec. 31, 2025
Sep. 30, 2025
Jun. 30, 2025
Mar. 31, 2025
Dec. 31, 2024
Sep. 30, 2024
Jun. 30, 2024
Mar. 31, 2024
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Capitalization, Long-Term Debt and Equity [Abstract]                      
Dividends declared (in dollars per share) $ 0.445 $ 0.890 $ 0 $ 0.445 $ 0.425 $ 0.850 $ 0 $ 0.425 $ 1.78 $ 1.70 $ 1.60
Dividends paid (in dollars per share) $ 0.445 $ 0.445 $ 0.445 $ 0.425 $ 0.425 $ 0.425 $ 0.425 $ 0.410 $ 1.760 $ 1.685  
v3.25.4
CAPITALIZATION - Narrative (Details)
$ / shares in Units, $ in Millions
 1 Months Ended 12 Months Ended
Jun. 12, 2025
USD ($)
tradingDay
consecutiveTradingDay
$ / shares
May 04, 2023
USD ($)
series
Jun. 30, 2025
USD ($)
Dec. 31, 2025
USD ($)
$ / shares
shares
Dec. 31, 2024
USD ($)
shares
Dec. 31, 2023
USD ($)
shares
Sep. 04, 2025
USD ($)
Aug. 31, 2025
Aug. 13, 2025
USD ($)
Dec. 05, 2024
USD ($)
Apr. 30, 2023
Jun. 30, 2013
USD ($)
Debt Instrument [Line Items]                        
FERC-defined equity to total capitalization ratio       35.00%                
Preference shares outstanding (in shares) | shares       0 0              
Preferred shares, outstanding (in shares) | shares       0 0              
Repayments of debt       $ 3,129 $ 2,760 $ 537            
Environmental control bonds outstanding       156 188              
Principal default amount specified in debt covenants       $ 100                
2026 Convertible Notes | Unsecured Debt                        
Debt Instrument [Line Items]                        
Issuance interest rate                     4.00%  
Proceeds from issuance of debt   $ 1,480                    
Observation period (in trading days) | series   40                    
Number of trading days prior to maturity date | series   40                    
Convertible Notes 2026 | Convertible Debt                        
Debt Instrument [Line Items]                        
Debt instrument, conversation price (in dollars per share) | $ / shares       $ 46.42                
Repayments of debt     $ 1,200                  
3.625%, Convertible Notes Maturity 2029 | Convertible Debt                        
Debt Instrument [Line Items]                        
Face amount of loan $ 1,350                      
3.875%, Convertible Notes Maturity 2031 | Convertible Debt                        
Debt Instrument [Line Items]                        
Face amount of loan $ 1,150                      
Convertible Notes Maturity 2029 | Convertible Debt                        
Debt Instrument [Line Items]                        
Issuance interest rate 3.625%                      
Convertible Notes Maturity 2031 | Convertible Debt                        
Debt Instrument [Line Items]                        
Issuance interest rate 3.875%                      
Convertible Notes Maturity 2029 & 2031 | Convertible Debt                        
Debt Instrument [Line Items]                        
Proceeds from issuance of debt $ 2,470                      
Debt instrument, convertible, conversion ratio 0.0209275                      
Debt instrument, conversation price (in dollars per share) | $ / shares $ 47.78                      
Debt instrument convertible premium 0.20                      
Number of trading days prior to maturity date 40                      
Redemption price, percentage 100.00%                      
Convertible Notes Maturity 2029 & 2031 | Convertible Debt | Debt Conversion Terms One                        
Debt Instrument [Line Items]                        
Debt instrument, convertible, threshold trading days | tradingDay 20                      
Debt instrument, convertible, threshold consecutive trading days | tradingDay 30                      
Debt instrument, convertible, threshold percentage of stock price trigger 130.00%                      
Convertible Notes Maturity 2029 & 2031 | Convertible Debt | Debt Conversion Terms Two                        
Debt Instrument [Line Items]                        
Debt instrument, convertible, threshold trading days | consecutiveTradingDay 5                      
Debt instrument, convertible, threshold consecutive trading days | consecutiveTradingDay 10                      
Threshold trading days measurement period | tradingDay 10                      
Debt instrument, measurement period percentage 98.00%                      
4.75%, $450 Million Notes Maturity 2033 | Unsecured Debt                        
Debt Instrument [Line Items]                        
Face amount of loan                 $ 450      
Phase In Recovery Bonds                        
Debt Instrument [Line Items]                        
Long-term debt and other long-term obligations       $ 159 $ 175              
Registered Shareholders, Directors and Employees of Subsidiaries                        
Debt Instrument [Line Items]                        
Consolidated tax benefit allocation (in shares) | shares       1,000,000 3,000,000 2,000,000            
JERSEY CENTRAL POWER & LIGHT COMPANY                        
Debt Instrument [Line Items]                        
Repayments of debt       $ 650 $ 500 $ 0            
JERSEY CENTRAL POWER & LIGHT COMPANY | Senior Notes Maturity 2035 | Unsecured Debt                        
Debt Instrument [Line Items]                        
Face amount of loan                   $ 700    
JERSEY CENTRAL POWER & LIGHT COMPANY | Unsecured Senior Notes Due 2029 | Unsecured Debt                        
Debt Instrument [Line Items]                        
Face amount of loan             $ 350          
JERSEY CENTRAL POWER & LIGHT COMPANY | Unsecured Senior Notes Due 2031 | Unsecured Debt                        
Debt Instrument [Line Items]                        
Face amount of loan             500          
JERSEY CENTRAL POWER & LIGHT COMPANY | Unsecured Senior Notes Due 2036 | Unsecured Debt                        
Debt Instrument [Line Items]                        
Face amount of loan             $ 500          
FET | 4.75%, $450 Million Notes Maturity 2033 | Promissory Notes                        
Debt Instrument [Line Items]                        
Issuance interest rate               4.75%        
FET | Brookfield II                        
Debt Instrument [Line Items]                        
Gain (loss) from disposal of discontinued operation         $ 7,000              
AGC                        
Debt Instrument [Line Items]                        
FERC-defined equity to total capitalization ratio       45.00%                
FE | 4.00%, $1,500 Million Notes Maturity 2026 | Promissory Notes                        
Debt Instrument [Line Items]                        
Face amount of loan   $ 1,500                    
Ohio Funding Companies | Phase In Recovery Bonds                        
Debt Instrument [Line Items]                        
Face amount of loan                       $ 445
v3.25.4
CAPITALIZATION - Schedule of Preferred and Preference Stock (Details)
Dec. 31, 2025
$ / shares
shares
CEI  
Preferred stock and preference stock authorizations  
Preferred Stock, Shares Authorized (in shares) 4,000,000
JCP&L  
Preferred stock and preference stock authorizations  
Preferred Stock, Shares Authorized (in shares) 15,600,000
PE  
Preferred stock and preference stock authorizations  
Preferred Stock, Shares Authorized (in shares) 10,000,000
Preferred Stock, Par Value (in dollars per share) | $ / shares $ 0.01
Preferred Stock With Par Value $100 | FE  
Preferred stock and preference stock authorizations  
Preferred Stock, Shares Authorized (in shares) 5,000,000
Preferred Stock, Par Value (in dollars per share) | $ / shares $ 100
Preferred Stock With Par Value $100 | OE  
Preferred stock and preference stock authorizations  
Preferred Stock, Shares Authorized (in shares) 6,000,000
Preferred Stock, Par Value (in dollars per share) | $ / shares $ 100
Preferred Stock With Par Value $100 | TE  
Preferred stock and preference stock authorizations  
Preferred Stock, Shares Authorized (in shares) 3,000,000
Preferred Stock, Par Value (in dollars per share) | $ / shares $ 100
Preferred Stock With Par Value $100 | MP  
Preferred stock and preference stock authorizations  
Preferred Stock, Shares Authorized (in shares) 940,000
Preferred Stock, Par Value (in dollars per share) | $ / shares $ 100
Preferred Stock With Par Value $25 | OE  
Preferred stock and preference stock authorizations  
Preferred Stock, Shares Authorized (in shares) 8,000,000
Preferred Stock, Par Value (in dollars per share) | $ / shares $ 25
Preferred Stock With Par Value $25 | TE  
Preferred stock and preference stock authorizations  
Preferred Stock, Shares Authorized (in shares) 12,000,000
Preferred Stock, Par Value (in dollars per share) | $ / shares $ 25
Preference Stock | OE  
Preferred stock and preference stock authorizations  
Preference Stock, Shares Authorized (in shares) 8,000,000
Preference Stock | CEI  
Preferred stock and preference stock authorizations  
Preference Stock, Shares Authorized (in shares) 3,000,000
Preference Stock | TE  
Preferred stock and preference stock authorizations  
Preference Stock, Shares Authorized (in shares) 5,000,000
Preference Stock, Par Value (in dollars per share) | $ / shares $ 25
v3.25.4
CAPITALIZATION - Schedule of Long-term Debt and Other Long-term Obligations (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Schedule of Capitalization [Line Items]    
Finance lease obligations $ 10 $ 12
Unamortized debt discounts (20) (14)
Unamortized debt issuance costs (150) (122)
Unamortized fair value adjustments 1 3
Currently payable long-term debt (723) (977)
Total long-term debt and other long-term obligations 25,508 22,496
JERSEY CENTRAL POWER & LIGHT COMPANY    
Schedule of Capitalization [Line Items]    
Finance lease obligations 4 5
Unamortized debt discounts (7) (4)
Unamortized debt issuance costs (22) (11)
Currently payable long-term debt (2) (1)
Total long-term debt and other long-term obligations 3,023 2,339
FMBs and secured notes - fixed rate    
Schedule of Capitalization [Line Items]    
FMBs and secured notes - fixed rate $ 5,214 4,963
FMBs and secured notes - fixed rate | Minimum    
Schedule of Capitalization [Line Items]    
Interest rate (percent) 2.65%  
FMBs and secured notes - fixed rate | Maximum    
Schedule of Capitalization [Line Items]    
Interest rate (percent) 8.25%  
Unsecured notes - fixed rate    
Schedule of Capitalization [Line Items]    
Unsecured notes - fixed rate $ 21,176 18,631
Unsecured notes - fixed rate | Minimum    
Schedule of Capitalization [Line Items]    
Interest rate (percent) 2.25%  
Unsecured notes - fixed rate | Maximum    
Schedule of Capitalization [Line Items]    
Interest rate (percent) 6.875%  
Unsecured notes - fixed rate | JERSEY CENTRAL POWER & LIGHT COMPANY    
Schedule of Capitalization [Line Items]    
Unsecured notes - fixed rate $ 3,050 $ 2,350
Unsecured notes - fixed rate | JERSEY CENTRAL POWER & LIGHT COMPANY | Minimum    
Schedule of Capitalization [Line Items]    
Interest rate (percent) 2.75%  
Unsecured notes - fixed rate | JERSEY CENTRAL POWER & LIGHT COMPANY | Maximum    
Schedule of Capitalization [Line Items]    
Interest rate (percent) 6.40%  
v3.25.4
CAPITALIZATION - Schedule of Long-term Debt Redemption and Issuance (Details) - USD ($)
$ in Millions
 1 Months Ended 12 Months Ended
Dec. 31, 2025
Oct. 16, 2025
Dec. 31, 2025
Oct. 31, 2025
Sep. 30, 2025
Aug. 31, 2025
Jun. 30, 2025
May 31, 2025
Apr. 30, 2025
Mar. 31, 2025
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Debt Instrument [Line Items]                          
Repayments of debt                     $ 3,129 $ 2,760 $ 537
Debt issuances                     5,925 2,100 3,150
JCP&L                          
Debt Instrument [Line Items]                          
Repayments of debt                     650 500 0
Debt issuances                     $ 1,350 $ 700 $ 0
2.05% Unsecured Senior Notes Maturity 2025 | Unsecured Notes | FE                          
Debt Instrument [Line Items]                          
Issuance interest rate                   2.05%      
Repayments of debt                   $ 300      
3.76% Unsecured Senior Notes Maturing 2025 | Unsecured Notes | TrAIL                          
Debt Instrument [Line Items]                          
Issuance interest rate               3.76%          
Repayments of debt               $ 75          
3.85% Unsecured Senior Notes Maturing 2025 | Unsecured Notes | TrAIL                          
Debt Instrument [Line Items]                          
Issuance interest rate             3.85%            
Repayments of debt             $ 550            
4.00% Unsecured Senior Notes Maturing 2026 | Convertible Debt | FE                          
Debt Instrument [Line Items]                          
Issuance interest rate             4.00%            
Repayments of debt             $ 1,206            
Repayments of long-term debt including premium             1,225            
Make-whole premium             $ 19            
4.30% Unsecured Senior Notes Maturing 2026 | Unsecured Notes | JCP&L                          
Debt Instrument [Line Items]                          
Issuance interest rate       4.30%                  
Repayments of debt       $ 650                  
4.30% Unsecured Senior Notes Maturing 2026 | Senior Notes | JCP&L                          
Debt Instrument [Line Items]                          
Issuance interest rate   4.30%                      
Repayments of debt   $ 650                      
1.60% Unsecured Senior Notes Maturing 2026 | Unsecured Notes | FE                          
Debt Instrument [Line Items]                          
Issuance interest rate 1.60%   1.60%               1.60%    
Repayments of debt     $ 300                    
1.60% Unsecured Senior Notes Maturing 2026 | Senior Notes | FE                          
Debt Instrument [Line Items]                          
Issuance interest rate 1.60%   1.60%               1.60%    
Repayments of debt $ 300                        
5.00%, $600 Million Notes Maturity 2031 | Unsecured Notes | TrAIL                          
Debt Instrument [Line Items]                          
Issuance interest rate                 5.00%        
Debt issuances                 $ 600        
5.00% Unsecured Senior Notes Maturing 2030 | Unsecured Notes | ATSI                          
Debt Instrument [Line Items]                          
Issuance interest rate               5.00%          
Debt issuances               $ 225          
4.95% Unsecured Senior Notes Maturing 2029 | Unsecured Notes | OE                          
Debt Instrument [Line Items]                          
Issuance interest rate               4.95%          
Debt issuances               $ 300          
5.00% Unsecured Senior Notes Maturing 2031 | Unsecured Notes | MAIT                          
Debt Instrument [Line Items]                          
Issuance interest rate             5.00%            
Debt issuances             $ 200            
5.00%, 200 Million Notes Maturing 2030 | First Mortgage Bond | PE                          
Debt Instrument [Line Items]                          
Issuance interest rate             5.00%            
Debt issuances             $ 200            
5.18%, $100 Million Notes Maturity 2030 | Senior Notes | TE                          
Debt Instrument [Line Items]                          
Issuance interest rate             5.18%            
Debt issuances             $ 100            
3.63%, $1,350 Million Notes Maturity 2029 | Convertible Debt | FE                          
Debt Instrument [Line Items]                          
Issuance interest rate             3.63%            
Debt issuances             $ 1,350            
3.88%, $1,150 Million Notes Maturity 2031 | Convertible Debt | FE                          
Debt Instrument [Line Items]                          
Issuance interest rate             3.88%            
Debt issuances             $ 1,150            
4.75%, $450 Million Notes Maturity 2033 | Unsecured Notes | FET                          
Debt Instrument [Line Items]                          
Issuance interest rate           4.75%              
Debt issuances           $ 450              
4.15%, $350 Million Notes Maturity 2029 | Unsecured Notes | JCP&L                          
Debt Instrument [Line Items]                          
Issuance interest rate         4.15%                
Debt issuances         $ 350                
4.30%, 650 Million Senior Notes Due 2026 | Unsecured Notes | JCP&L | Revolving Credit Facility                          
Debt Instrument [Line Items]                          
Issuance interest rate         4.30%                
Face amount of loan         $ 650                
4.40%, $500 Million Notes Maturity 2031 | Unsecured Notes | JCP&L                          
Debt Instrument [Line Items]                          
Issuance interest rate         4.40%                
Debt issuances         $ 500                
5.15%, $500 Million Notes Maturity 2036 | Unsecured Notes | JCP&L                          
Debt Instrument [Line Items]                          
Issuance interest rate         5.15%                
Debt issuances         $ 500                
v3.25.4
CAPITALIZATION - Schedule of Maturities of Long-term Debt (Details)
$ in Millions
Dec. 31, 2025
USD ($)
Debt Instrument [Line Items]  
2026 $ 720
2027 2,003
2028 2,453
2029 3,064
2030 2,456
JERSEY CENTRAL POWER & LIGHT COMPANY  
Debt Instrument [Line Items]  
2026 0
2027 0
2028 0
2029 350
2030 $ 0
v3.25.4
SHORT-TERM BORROWINGS AND BANK LINES OF CREDIT - Narrative (Details)
$ in Millions
 12 Months Ended
Oct. 27, 2025
Dec. 31, 2025
USD ($)
Dec. 31, 2024
USD ($)
Short-term Debt [Line Items]      
Short-term borrowings   $ 325 $ 550
Short-term debt, weighted average interest rate, at point in time (percent)   5.72% 7.10%
Maximum | Money Pool      
Short-term Debt [Line Items]      
Debt term   364 days  
Minimum | Available for Issuance of Letters of Credit      
Short-term Debt [Line Items]      
Cross-default provision for other indebtedness   $ 100  
Revolving Credit Facility | Line of Credit      
Short-term Debt [Line Items]      
Available liquidity   $ 5,600  
Letter of Credit | Line of Credit      
Short-term Debt [Line Items]      
Debt term   1 year  
Outstanding borrowings   $ 185  
Letter of Credit | Line of Credit | FE      
Short-term Debt [Line Items]      
Letters of credit outstanding, amount   52  
JERSEY CENTRAL POWER & LIGHT COMPANY      
Short-term Debt [Line Items]      
Short-term borrowings   $ 93 $ 22
Short-term debt, weighted average interest rate, at point in time (percent)   7.58% 6.76%
JERSEY CENTRAL POWER & LIGHT COMPANY | Revolving Credit Facility | Line of Credit      
Short-term Debt [Line Items]      
Available liquidity   $ 750  
FE | Revolving Credit Facility | Line of Credit      
Short-term Debt [Line Items]      
Credit spread adjustment 0.0010    
Debt term 1 year    
Parent, FET, the Utilities and the Transmission Companies | Revolving Credit Facility | Line of Credit | Maximum      
Short-term Debt [Line Items]      
Debt term   364 days  
FET, the Utilities and the Transmission Companies | Revolving Credit Facility | Line of Credit      
Short-term Debt [Line Items]      
Coverage ratio   250.00%  
FET, the Utilities and the Transmission Companies | Revolving Credit Facility | Line of Credit | Maximum      
Short-term Debt [Line Items]      
Consolidated debt to total capitalization ratio (percent)   75.00%  
FET, the Utilities and the Transmission Companies | Revolving Credit Facility | Line of Credit | Minimum      
Short-term Debt [Line Items]      
Consolidated debt to total capitalization ratio (percent)   65.00%  
v3.25.4
SHORT-TERM BORROWINGS AND BANK LINES OF CREDIT - Schedule of Interest Rate (Details)
Dec. 31, 2025
Dec. 31, 2024
Regulated Companies’ Money Pool    
Short-term Debt [Line Items]    
Average Interest Rates 4.51% 5.74%
Unregulated Companies’ Money Pool    
Short-term Debt [Line Items]    
Average Interest Rates 4.89% 6.44%
v3.25.4
REGULATORY MATTERS - Schedule of Distribution Rate Orders (Details)
 12 Months Ended
Nov. 19, 2025
Dec. 31, 2025
CEI    
Public Utilities, General Disclosures [Line Items]    
Allowed debt   51.00%
Allowed equity   49.00%
Allowed ROE   10.50%
MP    
Public Utilities, General Disclosures [Line Items]    
Allowed ROE   9.80%
JCP&L    
Public Utilities, General Disclosures [Line Items]    
Allowed debt   48.10%
Allowed equity   51.90%
Allowed ROE   9.60%
OE    
Public Utilities, General Disclosures [Line Items]    
Allowed debt   51.00%
Allowed equity   49.00%
Allowed ROE   10.50%
PE | West Virginia    
Public Utilities, General Disclosures [Line Items]    
Allowed ROE   9.80%
PE | Maryland    
Public Utilities, General Disclosures [Line Items]    
Allowed debt   47.00%
Allowed equity   53.00%
Allowed ROE   9.50%
TE    
Public Utilities, General Disclosures [Line Items]    
Allowed debt   51.00%
Allowed equity   49.00%
Allowed ROE   10.50%
Ohio Companies    
Public Utilities, General Disclosures [Line Items]    
Allowed debt 48.80%  
Allowed equity 51.20%  
Allowed ROE 9.63%  
v3.25.4
REGULATORY MATTERS - Maryland and New Jersey (Details)
 12 Months Ended
Jan. 14, 2026
USD ($)
Aug. 13, 2025
Jun. 04, 2025
GW
Apr. 23, 2025
USD ($)
Aug. 15, 2024
USD ($)
Jul. 01, 2024
USD ($)
Mar. 21, 2024
Dec. 29, 2023
USD ($)
Nov. 09, 2023
USD ($)
Oct. 31, 2023
windFarm
MW
Aug. 01, 2023
USD ($)
scenario
Apr. 17, 2023
Oct. 26, 2022
USD ($)
Dec. 31, 2025
USD ($)
Jul. 16, 2025
recommendation
Jun. 18, 2025
USD ($)
Jan. 16, 2025
USD ($)
JCP&L                                  
Regulatory Matters [Line Items]                                  
Allowed ROE                           9.60%      
Maryland | Per Year 2022 Through 2024 | PE                                  
Regulatory Matters [Line Items]                                  
Incremental energy savings goal thereafter (percent)             2.00%                    
Maryland | Per Year 2025 And 2026 | PE                                  
Regulatory Matters [Line Items]                                  
Incremental energy savings goal thereafter (percent)             2.25%                    
Maryland | Per Year 2027 | PE                                  
Regulatory Matters [Line Items]                                  
Incremental energy savings goal thereafter (percent)             2.50%                    
Maryland | 2024-2026 EmPOWER Program Cycle | PE                                  
Regulatory Matters [Line Items]                                  
Number of scenarios with projected costs submitted for cost recovery program | scenario                     3            
Recovery period for expenditures for cost recovery program                     3 years            
Public utilities, requested year one                     $ 311,000,000            
Public utilities, requested year two                     354,000,000            
Public utilities, requested year three                     $ 510,000,000            
Approved amount of rate increase (decrease)               $ 311,000,000                  
Public utilities, revised requested rate, amount         $ 314,000,000                        
Amortization period                           5 years      
Public utilities, requested cost percentage, year one                     0.67            
Public utilities, requested cost percentage, year two                     1            
Maryland | 2024-2030 EmPOWER Program Cycle | PE | Minimum                                  
Regulatory Matters [Line Items]                                  
Public utilities, expected reduction to pre-tax return on programs           $ 25,000,000                      
Maryland | 2024-2030 EmPOWER Program Cycle | PE | Maximum                                  
Regulatory Matters [Line Items]                                  
Public utilities, expected reduction to pre-tax return on programs           $ 30,000,000                      
New Jersey | JCP And L                                  
Regulatory Matters [Line Items]                                  
Approved amount of rate increase (decrease)                         $ 723,000,000        
Number of recommendations to be implemented | recommendation                             100    
Total number of recommendations | recommendation                             105    
Allowed ROE                         10.20%        
Public utility, offshore development, percent                         20.00%        
Recovery of transmission incentive rates, percentage                       100.00%          
Recovery of transmission incentive rates, percentage                       50.00%          
Number of cease development | windFarm                   2              
Plant capacity (in MW's)     1.5             2,248              
Approved loan guarantee of maximum amount                                 $ 716,000,000
New Jersey | JCP And L | NJBPU                                  
Regulatory Matters [Line Items]                                  
Transmission investment plan period   2 years 6 months                              
New Jersey | Energy Efficiency and Peak Demand Reduction | JCP&L | NJBPU | Subsequent Event                                  
Regulatory Matters [Line Items]                                  
Revenue impact of sales losses to be recovered $ 16,000,000                                
Conversion plan period 1 year                                
New Jersey | Energy Efficiency and Peak Demand Reduction | JCP&L | NJBPU | Distribution                                  
Regulatory Matters [Line Items]                                  
Approved amount of rate increase (decrease)       $ 339,000,000                          
Amount of requested rate increase                 $ 935,000,000                
Implementation period                 5 years                
Amount of requested rate increase, capital commitments                 $ 906,000,000                
Amount of requested rate increase, operating and maintenance expense                 $ 29,000,000                
Approved capital commitments       203,000,000                          
Approved matching capital commitments       132,000,000                          
Public utilities, requested rate increase (decrease), amount, operating and maintenance expense       $ 4,000,000                          
Approved temporary electric rate                               $ 30.00  
Deferred regulatory asset and recovered rate                               $ 10.00  
Temporary rate credit regulatory asset balance                           $ 20,000,000      
v3.25.4
REGULATORY MATTERS - Ohio (Details)
$ in Thousands
 1 Months Ended 3 Months Ended 12 Months Ended
Dec. 19, 2025
intervenor
Nov. 19, 2025
USD ($)
Feb. 21, 2025
Dec. 18, 2024
USD ($)
Sep. 30, 2024
USD ($)
payment
Jul. 31, 2024
USD ($)
May 31, 2024
USD ($)
Apr. 05, 2023
Jan. 31, 2025
USD ($)
Sep. 30, 2024
USD ($)
Dec. 31, 2025
Jan. 07, 2026
USD ($)
May 15, 2024
USD ($)
Sep. 13, 2021
requirement
Aug. 06, 2021
USD ($)
Regulatory Matters [Line Items]                              
Impairment of long-lived assets to be disposed of                   $ 62,000          
Ohio Companies                              
Regulatory Matters [Line Items]                              
Allowed ROE   9.63%                          
Allowed debt   48.80%                          
Approved capital structure   51.20%                          
CEI                              
Regulatory Matters [Line Items]                              
Allowed ROE                     10.50%        
Allowed debt                     51.00%        
Approved capital structure                     49.00%        
OE                              
Regulatory Matters [Line Items]                              
Allowed ROE                     10.50%        
Allowed debt                     51.00%        
Approved capital structure                     49.00%        
PUCO                              
Regulatory Matters [Line Items]                              
Commitment to spend                 $ 6,500            
PUCO | Ohio                              
Regulatory Matters [Line Items]                              
Proposed goal to reduce CO2 pollution (percent)       90.00%                      
PUCO | DCR Rider | Ohio                              
Regulatory Matters [Line Items]                              
Annual revenue cap for DCR rider       $ 390,000                      
Requested increase in revenue cap       15,000                      
PUCO | Energy Conservation, Economic Development and Job Retention | Ohio                              
Regulatory Matters [Line Items]                              
Contribution amount       $ 6,390                      
PUCO | DMR Revenues | Ohio                              
Regulatory Matters [Line Items]                              
Monetary penalties assessed by the PUCO   $ 250,000                          
Number of intervenors | intervenor 14                            
PUCO | DMR Revenues | Ohio | Subsequent Event                              
Regulatory Matters [Line Items]                              
Customer restitution total                       $ 275,000      
Customer restitution after tax                       213,000      
PUCO | DMR Revenues | Ohio | Subsequent Event | Other Current Liabilities                              
Regulatory Matters [Line Items]                              
Customer restitution total                       25,000      
PUCO | DMR Revenues | Ohio | Subsequent Event | Regulatory Liabilities                              
Regulatory Matters [Line Items]                              
Customer restitution total                       $ 250,000      
PUCO | Ohio Companies | ESP V                              
Regulatory Matters [Line Items]                              
Public utilities, approved bill assistance contribution, amount                         $ 32,500    
PUCO | Ohio Companies | Energy Efficiency and Peak Demand Reduction Stipulation Settlement | Ohio | Distribution                              
Regulatory Matters [Line Items]                              
Impairment of long-lived assets to be disposed of   $ 352,000                          
PUCO | Ohio Companies | Rider Delivery Capital Recovery Audit Report | Ohio                              
Regulatory Matters [Line Items]                              
Refund to customer of pole attachment rates         $ 15         $ 15         $ 15
Loss contingency, payment audit, number of payments examined | payment         53                    
Loss contingency, payment audit, total payments in support of Passage of house bill         $ 75,000                    
Number of minor non-compliance with requirements | requirement                           8  
Number of requirements were in compliance | requirement                           23  
PUCO | CEI | DCR Rider | Ohio | Distribution                              
Regulatory Matters [Line Items]                              
Allowed ROE   9.63%         10.80%                
Allowed debt   48.80%         44.00%                
Approved capital structure   51.20% 51.20%       56.00%                
PUCO | CEI | Energy Efficiency and Peak Demand Reduction Stipulation Settlement | Ohio | Distribution                              
Regulatory Matters [Line Items]                              
Increase base distribution rate             $ 94,000                
Public utilities, adjusted rate increase base distribution           $ 190,000                  
Approved amount of rate increase (decrease)   $ 34,000                          
PUCO | OE | DCR Rider | Ohio | Distribution                              
Regulatory Matters [Line Items]                              
Allowed debt             46.00%                
Approved capital structure             54.00%                
PUCO | TE | DCR Rider | Ohio | Distribution                              
Regulatory Matters [Line Items]                              
Allowed debt             45.00%                
Approved capital structure             55.00%                
Minimum | PUCO                              
Regulatory Matters [Line Items]                              
Amount of revenue increase                 37,000            
Minimum | PUCO | Ohio Companies                              
Regulatory Matters [Line Items]                              
Approved rate plan period               8 years              
Maximum | PUCO                              
Regulatory Matters [Line Items]                              
Amount of revenue increase                 $ 43,000            
Maximum | PUCO | Ohio Companies | Rider Delivery Capital Recovery Audit Report | Ohio                              
Regulatory Matters [Line Items]                              
Loss contingency, payment audit, payments in support of passage of house bill allocated to defendants         $ 5,000                    
v3.25.4
REGULATORY MATTERS - Pennsylvania, West Virginia, FERC Audit, Transmission ROE Incentive, Valley Link Formula Transmission Rate and Abandonment Transmission Rate Incentive (Details)
$ in Millions
 12 Months Ended
Feb. 13, 2026
USD ($)
MW
Nov. 26, 2025
USD ($)
Oct. 01, 2025
USD ($)
MW
Sep. 10, 2025
Aug. 29, 2025
USD ($)
Mar. 14, 2025
Jan. 17, 2025
Dec. 08, 2023
auditMatter
Apr. 24, 2023
site
MW
May 01, 2022
MW
Feb. 24, 2022
Dec. 31, 2025
USD ($)
Dec. 31, 2024
USD ($)
site
Dec. 31, 2022
USD ($)
Transmission Related Vegetation Management Programs | FERC | FE                            
Regulatory Matters [Line Items]                            
Utilities reclassification to operating expense                           $ 105.0
Public utilities, number of unresolved audit matters referred to other offices | auditMatter               2            
Utilities, transmission owning utilities join an RTO                     0.00500000      
Transmission Related Vegetation Management Programs | FERC | JERSEY CENTRAL POWER & LIGHT COMPANY | FE                            
Regulatory Matters [Line Items]                            
Utilities reclassification to operating expense                           $ 13.0
Transmission ROE Incentive | FERC                            
Regulatory Matters [Line Items]                            
Utilities, transmission owing utilities join an RTO             0.00500000              
Public utilities, amount awarded from other party                         $ 46.0  
Transmission ROE Incentive | FERC | Miscellaneous Income                            
Regulatory Matters [Line Items]                            
Public utilities, amount awarded from other party                         4.0  
Transmission ROE Incentive | FERC | Transmission | Transmission Revenues                            
Regulatory Matters [Line Items]                            
Public utilities, amount awarded from other party                         $ 42.0  
PJM 2024 RTEP Window 1 | Valley Link Transmission Rate                            
Regulatory Matters [Line Items]                            
Capital structure, percentage           40.00%                
Equity ratio, percentage           60.00%                
Transmission rate, base ROE           10.90%                
Recovery of project abandonment costs (percent)       50.00%                    
Recovery of project abandonment costs incurred thereafter (percent)       100.00%                    
Pennsylvania | EE&C Phase IV | PPUC                            
Regulatory Matters [Line Items]                            
Public utilities, approved energy consumption reduction targets, cost recovery                       $ 390.0    
Pennsylvania | EE&C Phase IV | PPUC | ME                            
Regulatory Matters [Line Items]                            
Demand reduction targets                       2.90%    
Energy consumption reduction targets                       3.10%    
Pennsylvania | EE&C Phase IV | PPUC | PN                            
Regulatory Matters [Line Items]                            
Demand reduction targets                       3.30%    
Energy consumption reduction targets                       3.00%    
Pennsylvania | EE&C Phase IV | PPUC | Penn                            
Regulatory Matters [Line Items]                            
Demand reduction targets                       2.00%    
Energy consumption reduction targets                       2.70%    
Pennsylvania | EE&C Phase IV | PPUC | WP                            
Regulatory Matters [Line Items]                            
Demand reduction targets                       2.50%    
Energy consumption reduction targets                       2.40%    
Pennsylvania | Energy Efficiency and Conservation Phase V | PPUC                            
Regulatory Matters [Line Items]                            
Public utilities, approved energy consumption reduction targets, cost recovery   $ 390.0                        
Pennsylvania | Energy Efficiency and Conservation Phase V | PPUC | FE PA                            
Regulatory Matters [Line Items]                            
Demand reduction targets   2.01%                        
Energy consumption reduction targets   2.00%                        
West Virginia | WVPSC | MP and PE                            
Regulatory Matters [Line Items]                            
Utilities requested rate increase amount         $ 14.0                  
Public utilities, increase of total revenues, percentage         0.80%                  
West Virginia | WVPSC | MP and PE | Solar Generation Project                            
Regulatory Matters [Line Items]                            
Percent of subscriptions required prior to commencement of construction                   85.00%        
Plant capacity (in MW's) | MW                 30 50        
Number of approved solar sites | site                 3       2  
Utilities number of overall solar sites | site                 5       5  
Amount of requested rate increase         $ (3.2)                  
Public utilities, near-term market capacity purchases (in MV's) | MW     70                      
West Virginia | WVPSC | MP and PE | Solar Generation Project | Subsequent Event                            
Regulatory Matters [Line Items]                            
Public utilities, near-term market capacity purchases (in MV's) | MW 70                          
West Virginia | WVPSC | MP and PE | Natural Gas Generation Project                            
Regulatory Matters [Line Items]                            
Public utilities, near-term market capacity purchases (in MV's) | MW     1,200                      
Estimated initial investment     $ 2,500.0                      
West Virginia | WVPSC | MP and PE | Natural Gas Generation Project | Subsequent Event                            
Regulatory Matters [Line Items]                            
Public utilities, near-term market capacity purchases (in MV's) | MW 1,200                          
Estimated initial investment $ 2,700.0                          
v3.25.4
REGULATORY MATTERS - Schedule of Reliability and FERC Matters (Details)
 12 Months Ended
Dec. 31, 2025
JCP&L  
Regulatory Matters [Line Items]  
Allowed ROE 9.60%
Allowed debt 48.10%
Integrated | ATSI  
Regulatory Matters [Line Items]  
Allowed ROE 9.88%
Demand reduction targets 0.50%
Demand reduction targets 10.38%
Utilities, transmission owing utilities join an RTO 0.0050
Integrated | JCP&L  
Regulatory Matters [Line Items]  
Allowed ROE 10.20%
Integrated | MP  
Regulatory Matters [Line Items]  
Allowed ROE 10.45%
Allowed debt 56.00%
Integrated | PE  
Regulatory Matters [Line Items]  
Allowed ROE 10.45%
Allowed debt 56.00%
Integrated | KATCo  
Regulatory Matters [Line Items]  
Allowed ROE 10.45%
Allowed debt 49.30%
Integrated | MAIT  
Regulatory Matters [Line Items]  
Allowed ROE 10.30%
Allowed debt 60.00%
Integrated | TrAIL | TrAIL the Line and Black Oak SVC  
Regulatory Matters [Line Items]  
Allowed ROE 12.70%
Integrated | TrAIL | All Other Projects  
Regulatory Matters [Line Items]  
Allowed ROE 11.70%
v3.25.4
COMMITMENTS, GUARANTEES AND CONTINGENCIES - Narrative (Details) - USD ($)
$ in Millions
 3 Months Ended 6 Months Ended 12 Months Ended
Mar. 04, 2025
Feb. 03, 2025
Jul. 21, 2021
Dec. 31, 2025
Jun. 30, 2024
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Guarantor Obligations [Line Items]                
Outstanding guarantees and other assurances aggregated       $ 1,100   $ 1,100    
Company posted collateral related to net liability positions       185   185    
Collateral received       33   33    
Liabilities incurred           1 $ 95  
Charges (credits) associated with changes in ARO (Note 9.)           $ (54) 200 $ 10
United States v. Householder, et al. | U.S. Attorney's Office                
Guarantor Obligations [Line Items]                
Term of DPA     3 years          
Loss in period     $ 230          
Term of payments     60 days          
United States v. Householder, et al. | United States Treasury                
Guarantor Obligations [Line Items]                
Proposed penalty     $ 115          
United States v. Householder, et al. | Ohio Development Service                
Guarantor Obligations [Line Items]                
Proposed penalty     115          
Amount that won't be recovered in rates or charged to customers     $ 230          
Regulation of Waste Disposal                
Guarantor Obligations [Line Items]                
Changes in timing and amount of estimated cash flows         $ 139   139  
Charges (credits) associated with changes in ARO (Note 9.)       $ 49        
Environmental Loss Contingency, Statement of Financial Position [Extensible Enumeration]       Regulatory liabilities   Regulatory liabilities    
Accrual for environmental loss contingencies       $ 97   $ 97    
Environmental liabilities former gas facilities       70   70    
Regulation of Waste Disposal | Corporate Non Segment                
Guarantor Obligations [Line Items]                
Liabilities incurred $ 130           87  
Environmental Liability                
Guarantor Obligations [Line Items]                
Asset retirement obligation, escrow deposit $ 130 $ 160   46   46 $ 160  
Agreed funding period 5 years 5 years         5 years  
Asset retirement obligation, discount rate 4.80%              
JERSEY CENTRAL POWER & LIGHT COMPANY                
Guarantor Obligations [Line Items]                
Company posted collateral related to net liability positions       28   28    
Collateral received       $ 2   2    
Liabilities incurred           $ 0 $ 0  
JERSEY CENTRAL POWER & LIGHT COMPANY | Regulation of Waste Disposal                
Guarantor Obligations [Line Items]                
Changes in timing and amount of estimated cash flows             $ 0  
v3.25.4
COMMITMENTS, GUARANTEES AND CONTINGENCIES - Schedule of Potential Amount of Future Payments (Details)
$ in Millions
Dec. 31, 2025
USD ($)
Guarantor Obligations [Line Items]  
Total Guarantees and Other Assurances $ 1,053
JERSEY CENTRAL POWER & LIGHT COMPANY  
Guarantor Obligations [Line Items]  
Total Guarantees and Other Assurances 48
FE's Guarantees on Behalf of its Consolidated Subsidiaries  
Guarantor Obligations [Line Items]  
Total Guarantees and Other Assurances 614
FE's Guarantees on Other Assurances  
Guarantor Obligations [Line Items]  
Total Guarantees and Other Assurances 439
Deferred compensation arrangements | FE's Guarantees on Behalf of its Consolidated Subsidiaries  
Guarantor Obligations [Line Items]  
Total Guarantees and Other Assurances 395
Deferred compensation arrangements | FE's Guarantees on Other Assurances  
Guarantor Obligations [Line Items]  
Total Guarantees and Other Assurances 93
Vehicle leases | FE's Guarantees on Behalf of its Consolidated Subsidiaries  
Guarantor Obligations [Line Items]  
Total Guarantees and Other Assurances 75
McElroy Run transfer | FE's Guarantees on Behalf of its Consolidated Subsidiaries  
Guarantor Obligations [Line Items]  
Total Guarantees and Other Assurances 129
Other | FE's Guarantees on Behalf of its Consolidated Subsidiaries  
Guarantor Obligations [Line Items]  
Total Guarantees and Other Assurances 15
Surety Bonds | FE's Guarantees on Other Assurances  
Guarantor Obligations [Line Items]  
Total Guarantees and Other Assurances 161
Surety Bonds | FE's Guarantees on Other Assurances | JERSEY CENTRAL POWER & LIGHT COMPANY  
Guarantor Obligations [Line Items]  
Total Guarantees and Other Assurances 20
LOCs | FE's Guarantees on Other Assurances  
Guarantor Obligations [Line Items]  
Total Guarantees and Other Assurances 185
LOCs | FE's Guarantees on Other Assurances | JERSEY CENTRAL POWER & LIGHT COMPANY  
Guarantor Obligations [Line Items]  
Total Guarantees and Other Assurances $ 28
v3.25.4
COMMITMENTS, GUARANTEES AND CONTINGENCIES - Schedule of Potential Collateral Obligations (Details)
$ in Millions
 12 Months Ended
Dec. 31, 2025
USD ($)
Guarantor Obligations [Line Items]  
Percent of face amount of debt 100.00%
Curing period 30 days
JERSEY CENTRAL POWER & LIGHT COMPANY  
Guarantor Obligations [Line Items]  
Percent of face amount of debt 100.00%
Curing period 30 days
Total Exposure from Contractual Obligations  
Guarantor Obligations [Line Items]  
Potential Collateral Obligations $ 366
Total Exposure from Contractual Obligations | JERSEY CENTRAL POWER & LIGHT COMPANY  
Guarantor Obligations [Line Items]  
Potential Collateral Obligations 87
Total Exposure from Contractual Obligations | FE  
Guarantor Obligations [Line Items]  
Potential Collateral Obligations 154
Total Exposure from Contractual Obligations | Electric Companies and Transmission Companies  
Guarantor Obligations [Line Items]  
Potential Collateral Obligations 212
Upon Further Downgrade  
Guarantor Obligations [Line Items]  
Potential Collateral Obligations 100
Upon Further Downgrade | JERSEY CENTRAL POWER & LIGHT COMPANY  
Guarantor Obligations [Line Items]  
Potential Collateral Obligations 67
Upon Further Downgrade | FE  
Guarantor Obligations [Line Items]  
Potential Collateral Obligations 1
Upon Further Downgrade | Electric Companies and Transmission Companies  
Guarantor Obligations [Line Items]  
Potential Collateral Obligations 99
Surety Bonds (collateralized amount)  
Guarantor Obligations [Line Items]  
Potential Collateral Obligations $ 266
Percent of face amount of debt 60.00%
Capped portion of surety bond obligations $ 22
Surety Bonds (collateralized amount) | JERSEY CENTRAL POWER & LIGHT COMPANY  
Guarantor Obligations [Line Items]  
Potential Collateral Obligations $ 20
Percent of face amount of debt 60.00%
Capped portion of surety bond obligations $ 1
Surety Bonds (collateralized amount) | FE  
Guarantor Obligations [Line Items]  
Potential Collateral Obligations 153
Surety Bonds (collateralized amount) | Electric Companies and Transmission Companies  
Guarantor Obligations [Line Items]  
Potential Collateral Obligations $ 113
v3.25.4
SEGMENT INFORMATION - Narrative (Details)
customer in Millions, $ in Millions
 12 Months Ended
Oct. 01, 2025
USD ($)
MW
Jul. 16, 2025
USD ($)
Dec. 31, 2025
USD ($)
customer
site
MW
Jul. 15, 2025
Dec. 31, 2024
USD ($)
Segment Reporting Information [Line Items]          
Number Of Reportable Segments Not Disclosed Flag     reportable segments    
Number of customers | customer     6.0    
Global Holding          
Segment Reporting Information [Line Items]          
Equity method investments | $         $ 45.0
FEV | Global Holding          
Segment Reporting Information [Line Items]          
Investment ownership percentage     33.33% 33.33%  
Ownership percentage sold   0.3333      
Equity method investments | $     $ 47.5    
Proceeds from investments sold | $   $ 47.5      
JERSEY CENTRAL POWER & LIGHT COMPANY          
Segment Reporting Information [Line Items]          
Number of customers | customer     1.2    
Solar Generation Project | MP and PE | West Virginia | WVPSC          
Segment Reporting Information [Line Items]          
Public utilities, near-term market capacity purchases (in MV's) | MW 70        
Natural Gas Generation Project | MP and PE | West Virginia | WVPSC          
Segment Reporting Information [Line Items]          
Public utilities, near-term market capacity purchases (in MV's) | MW 1,200        
Estimated initial investment | $ $ 2,500.0        
Distribution          
Segment Reporting Information [Line Items]          
Number of customers | customer     4.3    
Distribution | JERSEY CENTRAL POWER & LIGHT COMPANY          
Segment Reporting Information [Line Items]          
Number of customers | customer     1.2    
Integrated          
Segment Reporting Information [Line Items]          
Number of customers | customer     2.0    
Integrated | Solar Generation Project | MP and PE          
Segment Reporting Information [Line Items]          
Number of completed solar sites | site     3    
Integrated | Solar Generation Project | MP and PE | West Virginia          
Segment Reporting Information [Line Items]          
Plant generation capacity (in MW's) | MW     30    
Other Business Operations | FE          
Segment Reporting Information [Line Items]          
Long-term debt and other long-term obligations | $     $ 6,800.0    
Other Business Operations | OVEC          
Segment Reporting Information [Line Items]          
Plant generation capacity (in MW's) | MW     67    
v3.25.4
SEGMENT INFORMATION - Schedule of Segment Financial Information (Details) - USD ($)
$ in Millions
 3 Months Ended 6 Months Ended 9 Months Ended 12 Months Ended
Sep. 30, 2025
Jun. 30, 2025
Mar. 31, 2025
Sep. 30, 2024
Jun. 30, 2024
Mar. 31, 2024
Jun. 30, 2025
Jun. 30, 2024
Sep. 30, 2025
Sep. 30, 2024
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Segment Financial Information                          
Total revenues [1]                     $ 15,090 $ 13,472 $ 12,870
Other operating expenses                     4,122 4,044 3,579
Depreciation                     1,664 1,581 1,461
Amortization (deferral) of regulatory assets, net                     (109) (231) (261)
Ohio settlement charges                     275 0 0
Equity method investment earnings, net                     0 58 175
Interest expense                     1,217 1,144 1,124
Income taxes (benefits)                     288 377 267
Other expense (income) items                     6,888 5,637 5,752
Earnings Attributable to FE - continuing operations                     1,020 978 1,123
Net income                     1,020 978 1,102
Cash Flows from Investing Activities                          
Capital investments                     4,705 4,030 3,356
Total Assets [2]                     55,904 52,044  
Total Goodwill                     5,618 5,618  
JERSEY CENTRAL POWER & LIGHT COMPANY                          
Segment Financial Information                          
Total revenues                     2,638 2,315 2,027
Other operating expenses                     680 654 555
Depreciation                     263 249 231
Amortization (deferral) of regulatory assets, net                     (134) (124) (67)
Income taxes (benefits) $ 40 $ 20 $ 16 $ 40 $ 20 $ (4) $ 36 $ 16 $ 76 $ 56 107 87 33
Other expense (income) items                     1,278 1,090 1,026
Net income 118 62 47 107 55 (9)         306 242 125
Cash Flows from Investing Activities                          
Capital investments                     1,105 879 633
Total Assets $ 11,466 $ 10,427 $ 10,057 $ 9,599 $ 9,489 $ 9,207 $ 10,427 $ 9,489 $ 11,466 $ 9,599 11,109 9,913 9,102
Total Goodwill                     1,811 1,811  
JERSEY CENTRAL POWER & LIGHT COMPANY | Nonrelated Party                          
Segment Financial Information                          
Interest expense                     132 97 110
JERSEY CENTRAL POWER & LIGHT COMPANY | Related Party                          
Segment Financial Information                          
Total revenues                     1 1 1
Interest expense                     6 20 14
External revenues                          
Segment Financial Information                          
Total revenues                     15,090 13,472 12,870
External revenues | JERSEY CENTRAL POWER & LIGHT COMPANY                          
Segment Financial Information                          
Total revenues                     2,638 2,315 2,027
Internal revenues                          
Segment Financial Information                          
Total revenues                     0 0 0
Internal revenues | JERSEY CENTRAL POWER & LIGHT COMPANY                          
Segment Financial Information                          
Total revenues                     0 0 0
Distribution                          
Cash Flows from Investing Activities                          
Total Goodwill                     3,222 3,222  
Operating Segments                          
Segment Financial Information                          
Total revenues                     15,135 13,526 12,922
Other operating expenses                     4,223 3,979 3,623
Depreciation                     1,586 1,505 1,386
Amortization (deferral) of regulatory assets, net                     (109) (231) (261)
Ohio settlement charges                     275    
Equity method investment earnings, net                     0 0 0
Interest expense                     1,005 969 892
Income taxes (benefits)                     363 461 330
Other expense (income) items                     6,759 5,390 5,666
Earnings Attributable to FE - continuing operations                     1,308 1,453 1,286
Cash Flows from Investing Activities                          
Capital investments                     4,787 3,938 3,241
Total Assets                     55,908 52,114  
Total Goodwill                     5,618 5,618  
Operating Segments | JERSEY CENTRAL POWER & LIGHT COMPANY                          
Segment Financial Information                          
Total revenues                     2,813 2,467 2,138
Other operating expenses                     855 806 666
Depreciation                     263 249 231
Amortization (deferral) of regulatory assets, net                     (134) (124) (67)
Income taxes (benefits)                     107 87 33
Other expense (income) items                     1,278 1,090 1,026
Net income                     306 242 125
Cash Flows from Investing Activities                          
Capital investments                     1,105 879 633
Total Assets                     11,109 9,913  
Total Goodwill                     1,811 1,811  
Operating Segments | JERSEY CENTRAL POWER & LIGHT COMPANY | Nonrelated Party                          
Segment Financial Information                          
Interest expense                     132 97 110
Operating Segments | JERSEY CENTRAL POWER & LIGHT COMPANY | Related Party                          
Segment Financial Information                          
Interest expense                     6 20 14
Operating Segments | External revenues                          
Segment Financial Information                          
Total revenues                     15,072 13,463 12,859
Operating Segments | External revenues | JERSEY CENTRAL POWER & LIGHT COMPANY                          
Segment Financial Information                          
Total revenues                     2,638 2,315 2,027
Operating Segments | Internal revenues                          
Segment Financial Information                          
Total revenues                     63 63 63
Operating Segments | Internal revenues | JERSEY CENTRAL POWER & LIGHT COMPANY                          
Segment Financial Information                          
Total revenues                     175 152 111
Operating Segments | Distribution                          
Segment Financial Information                          
Total revenues                     7,547 6,863 6,854
Total revenues from contracts with customers                     7,465 6,783 6,779
Other operating expenses                     2,479 2,378 2,129
Depreciation                     655 648 620
Amortization (deferral) of regulatory assets, net                     (103) (171) (259)
Ohio settlement charges                     275    
Equity method investment earnings, net                     0 0 0
Interest expense                     399 432 390
Income taxes (benefits)                     74 135 147
Other expense (income) items                     3,680 2,817 3,240
Earnings Attributable to FE - continuing operations                     363 624 587
Cash Flows from Investing Activities                          
Capital investments                     1,344 1,130 936
Total Assets                     20,653 19,949  
Total Goodwill                     3,222 3,222  
Operating Segments | Distribution | JERSEY CENTRAL POWER & LIGHT COMPANY                          
Segment Financial Information                          
Total revenues                     2,554 2,225 1,934
Total revenues from contracts with customers                     2,550 2,211 1,931
Other operating expenses                     791 745 601
Depreciation                     209 203 190
Amortization (deferral) of regulatory assets, net                     (134) (124) (67)
Income taxes (benefits)                     71 52 11
Other expense (income) items                     1,309 1,100 1,036
Net income                     204 154 63
Cash Flows from Investing Activities                          
Capital investments                     454 360 232
Total Assets                     7,941 7,198  
Total Goodwill                     1,213 1,213  
Operating Segments | Distribution | JERSEY CENTRAL POWER & LIGHT COMPANY | Nonrelated Party                          
Segment Financial Information                          
Interest expense                     98 75 86
Operating Segments | Distribution | JERSEY CENTRAL POWER & LIGHT COMPANY | Related Party                          
Segment Financial Information                          
Interest expense                     6 20 14
Operating Segments | Distribution | External revenues                          
Segment Financial Information                          
Total revenues                     7,508 6,824 6,813
Operating Segments | Distribution | External revenues | JERSEY CENTRAL POWER & LIGHT COMPANY                          
Segment Financial Information                          
Total revenues                     2,379 2,073 1,823
Operating Segments | Distribution | Internal revenues                          
Segment Financial Information                          
Total revenues                     39 39 41
Operating Segments | Distribution | Internal revenues | JERSEY CENTRAL POWER & LIGHT COMPANY                          
Segment Financial Information                          
Total revenues                     175 152 111
Operating Segments | Integrated                          
Segment Financial Information                          
Total revenues                     5,683 4,876 4,320
Other operating expenses                     1,416 1,254 1,156
Depreciation                     562 521 462
Amortization (deferral) of regulatory assets, net                     (12) (66) (10)
Ohio settlement charges                     0    
Equity method investment earnings, net                     0 0 0
Interest expense                     284 262 257
Income taxes (benefits)                     190 153 37
Other expense (income) items                     2,655 2,217 2,118
Earnings Attributable to FE - continuing operations                     588 535 300
Cash Flows from Investing Activities                          
Capital investments                     1,842 1,542 1,212
Total Assets                     20,352 18,637  
Total Goodwill                     1,953 1,953  
Operating Segments | Integrated | External revenues                          
Segment Financial Information                          
Total revenues                     5,678 4,871 4,315
Operating Segments | Integrated | Internal revenues                          
Segment Financial Information                          
Total revenues                     5 5 5
Operating Segments | Stand-Alone Transmission                          
Segment Financial Information                          
Total revenues                     1,905 1,787 1,748
Other operating expenses                     328 347 338
Depreciation                     369 336 304
Amortization (deferral) of regulatory assets, net                     6 6 8
Ohio settlement charges                     0    
Equity method investment earnings, net                     0 0 0
Interest expense                     322 275 245
Income taxes (benefits)                     99 173 146
Other expense (income) items                     424 356 308
Earnings Attributable to FE - continuing operations                     357 294 399
Cash Flows from Investing Activities                          
Capital investments                     1,601 1,266 1,093
Total Assets                     14,903 13,528  
Total Goodwill                     443 443  
Operating Segments | Stand-Alone Transmission | External revenues                          
Segment Financial Information                          
Total revenues                     1,886 1,768 1,731
Operating Segments | Stand-Alone Transmission | Internal revenues                          
Segment Financial Information                          
Total revenues                     19 19 17
Operating Segments | Transmission | JERSEY CENTRAL POWER & LIGHT COMPANY                          
Segment Financial Information                          
Total revenues                     259 242 204
Other operating expenses                     64 61 65
Depreciation                     54 46 41
Amortization (deferral) of regulatory assets, net                     0 0 0
Income taxes (benefits)                     36 35 22
Other expense (income) items                     (31) (10) (10)
Net income                     102 88 62
Cash Flows from Investing Activities                          
Capital investments                     651 519 401
Total Assets                     3,168 2,715  
Total Goodwill                     598 598  
Operating Segments | Transmission | JERSEY CENTRAL POWER & LIGHT COMPANY | Nonrelated Party                          
Segment Financial Information                          
Interest expense                     34 22 24
Operating Segments | Transmission | JERSEY CENTRAL POWER & LIGHT COMPANY | Related Party                          
Segment Financial Information                          
Interest expense                     0 0 0
Operating Segments | Transmission | External revenues | JERSEY CENTRAL POWER & LIGHT COMPANY                          
Segment Financial Information                          
Total revenues                     259 242 204
Operating Segments | Transmission | Internal revenues | JERSEY CENTRAL POWER & LIGHT COMPANY                          
Segment Financial Information                          
Total revenues                     0 0 0
Corporate/Other                          
Segment Financial Information                          
Total revenues                     18 9 11
Other operating expenses                     (90) 75 (34)
Depreciation                     78 76 75
Amortization (deferral) of regulatory assets, net                     0 0 0
Ohio settlement charges                     0    
Equity method investment earnings, net                     0 58 175
Interest expense                     338 360 340
Income taxes (benefits)                     (75) (84) (63)
Other expense (income) items                     3 62 (22)
Earnings Attributable to FE - continuing operations                     (288) (475) (163)
Cash Flows from Investing Activities                          
Capital investments                     (82) 92 115
Total Assets                     1,793 1,975  
Total Goodwill                     0 0  
Corporate/Other | External revenues                          
Segment Financial Information                          
Total revenues                     18 9 11
Corporate/Other | Internal revenues                          
Segment Financial Information                          
Total revenues                     0 0 0
Reconciling Adjustments                          
Segment Financial Information                          
Total revenues                     (63) (63) (63)
Other operating expenses                     (11) (10) (10)
Depreciation                     0 0 0
Amortization (deferral) of regulatory assets, net                     0 0 0
Ohio settlement charges                     0    
Equity method investment earnings, net                     0 0 0
Interest expense                     (126) (185) (108)
Income taxes (benefits)                     0 0 0
Other expense (income) items                     126 185 108
Earnings Attributable to FE - continuing operations                     0 0 0
Cash Flows from Investing Activities                          
Capital investments                     0 0 0
Total Assets                     (1,797) (2,045)  
Total Goodwill                     0 0  
Reconciling Adjustments | JERSEY CENTRAL POWER & LIGHT COMPANY                          
Segment Financial Information                          
Total revenues                     (175) (152) (111)
Other operating expenses                     (175) (152) (111)
Depreciation                     0 0 0
Amortization (deferral) of regulatory assets, net                     0 0 0
Income taxes (benefits)                     0 0 0
Other expense (income) items                     0 0 0
Net income                     0 0 0
Cash Flows from Investing Activities                          
Capital investments                     0 0 0
Total Assets                     0 0  
Total Goodwill                     0 0  
Reconciling Adjustments | JERSEY CENTRAL POWER & LIGHT COMPANY | Nonrelated Party                          
Segment Financial Information                          
Interest expense                     0 0 0
Reconciling Adjustments | JERSEY CENTRAL POWER & LIGHT COMPANY | Related Party                          
Segment Financial Information                          
Interest expense                     0 0 0
Reconciling Adjustments | External revenues                          
Segment Financial Information                          
Total revenues                     0 0 0
Reconciling Adjustments | External revenues | JERSEY CENTRAL POWER & LIGHT COMPANY                          
Segment Financial Information                          
Total revenues                     0 0 0
Reconciling Adjustments | Internal revenues                          
Segment Financial Information                          
Total revenues                     (63) (63) (63)
Reconciling Adjustments | Internal revenues | JERSEY CENTRAL POWER & LIGHT COMPANY                          
Segment Financial Information                          
Total revenues                     $ (175) $ (152) $ (111)
[1] Includes excise and gross receipts tax collections of $463 million, $429 million and $420 million in 2025, 2024 and 2023, respectively.
[2] As of December 31, 2025 and 2024, the combined assets of the VIEs were $13,269 million and $12,053 million, respectively, that can only be used to settle obligations of the VIEs. As of December 31, 2025 and 2024, these assets include, respectively: Cash and cash equivalents of $8 million and $8 million, Restricted cash of $40 million and $40 million, Accounts receivable of $92 million and $96 million, Materials and supplies, at average cost of $1 million and $1 million, Prepaid taxes and other current assets of $41 million and $22 million, Property, plant, and equipment of $12,475 million and $11,217 million, Goodwill of $224 million and $224 million, Investments of $19 million and $19 million,
Regulatory assets of $21 million and $92 million, and Other noncurrent assets of $348 million and $334 million. The consolidated liabilities as of December 31, 2025 and 2024, include $10,176 million and $9,147 million, respectively, of liabilities of VIEs whose creditors have no recourse to FE. As of December 31, 2025 and 2024, these liabilities include, respectively: Currently payable long-term debt of $126 million and $674 million, Short-term borrowings of $245 million and $300 million, Accrued interest of $108 million and $76 million, Accrued taxes of $335 million and $306 million, other current liabilities of $9 million and $10 million, Long-term debt and other long-term obligations of $6,884 million and $5,544 million, Accumulated deferred income taxes of $1,540 million and $1,411 million, Regulatory liabilities of $598 million and $526 million, and Other noncurrent liabilities of $331 million and $300 million.
v3.25.4
TRANSACTIONS WITH AFFILIATES (Details) - USD ($)
$ in Millions
 3 Months Ended 6 Months Ended 9 Months Ended 12 Months Ended
Sep. 30, 2025
Jun. 30, 2025
Mar. 31, 2025
Sep. 30, 2024
Jun. 30, 2024
Mar. 31, 2024
Jun. 30, 2025
Jun. 30, 2024
Sep. 30, 2025
Sep. 30, 2024
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Related Party Transaction [Line Items]                          
REVENUES [1]                     $ 15,090 $ 13,472 $ 12,870
Other operating expenses                     4,122 4,044 3,579
Interest expense                     1,217 1,144 1,124
JERSEY CENTRAL POWER & LIGHT COMPANY                          
Related Party Transaction [Line Items]                          
REVENUES                     2,638 2,315 2,027
Other operating expenses $ 158 $ 137 $ 145 $ 180 $ 157 $ 186 $ 282 $ 343 $ 440 $ 523 680 [2] 654 [2] 555 [2]
JERSEY CENTRAL POWER & LIGHT COMPANY | Related Party                          
Related Party Transaction [Line Items]                          
REVENUES                     1 1 1
Other operating expenses                     116 118 122
Interest income                     1 0 0
Interest expense                     6 20 14
Operating expenses capitalized                     77 74 61
JERSEY CENTRAL POWER & LIGHT COMPANY | FESC support services | Related Party                          
Related Party Transaction [Line Items]                          
Other operating expenses                     180 166 174
JERSEY CENTRAL POWER & LIGHT COMPANY | Other affiliate support services | Related Party                          
Related Party Transaction [Line Items]                          
Other operating expenses                     $ 13 $ 26 $ 9
[1] Includes excise and gross receipts tax collections of $463 million, $429 million and $420 million in 2025, 2024 and 2023, respectively.
[2] Includes affiliated operating expenses of $116 million, $118 million and $122 million in 2025, 2024 and 2023, respectively.
v3.25.4
REVISION OF PREVIOUSLY ISSUED QUATERLY FINANCIAL STATEMENTS (Unaudited) - Schedule of Error Corrections related to Statement of Income and Comprehensive Income (Details) - USD ($)
$ in Millions
 3 Months Ended 6 Months Ended 9 Months Ended 12 Months Ended
Dec. 31, 2025
Sep. 30, 2025
Jun. 30, 2025
Mar. 31, 2025
Sep. 30, 2024
Jun. 30, 2024
Mar. 31, 2024
Jun. 30, 2025
Jun. 30, 2024
Sep. 30, 2025
Sep. 30, 2024
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
New Accounting Pronouncements or Change in Accounting Principle [Line Items]                            
Amortization (deferral) of regulatory assets, net                       $ (109) $ (231) $ (261)
Other operating expenses                       4,122 4,044 3,579
Total operating expenses                       12,884 11,097 10,604
Operating income                       2,206 2,375 2,266
Income before income taxes                       1,559 1,504 1,464
Income taxes                       288 377 267
Net income                       1,271 1,127 1,176
Comprehensive income                       1,271 1,130 1,173
JERSEY CENTRAL POWER & LIGHT COMPANY                            
New Accounting Pronouncements or Change in Accounting Principle [Line Items]                            
Amortization (deferral) of regulatory assets, net   $ 13 $ (12) $ (20) $ (23) $ (30) $ (37) $ (32) $ (68) $ (19) $ (90) (134) (124) (67)
Other operating expenses   158 137 145 180 157 186 282 343 440 523 680 [1] 654 [1] 555 [1]
Total operating expenses   694 499 494 608 461 463 993 923 1,687 1,532 2,234 1,955 1,777
Operating income   170 93 72 157 96 3 165 100 335 256 404 360 250
Income before income taxes   158 82 63 147 75 (13) 145 63 303 209 413 329 158
Income taxes   40 20 16 40 20 (4) 36 16 76 56 107 87 33
Net income   118 62 47 107 55 (9) 109 47 227 153 306 242 125
Comprehensive income   118 62 47 107 55 (9) 109 47 227 153 $ 306 243 125
As Reported | JERSEY CENTRAL POWER & LIGHT COMPANY                            
New Accounting Pronouncements or Change in Accounting Principle [Line Items]                            
Amortization (deferral) of regulatory assets, net   11 (14) (22) (25) (34) (39) (36) (73) (25) (98)   (135) (74)
Other operating expenses   158 133 145 179 158 187 278 345 436 524   656 555
Total operating expenses   692 493 492 605 458 462 985 920 1,677 1,525   1,946 1,770
Operating income   172 99 74 160 99 4 173 103 345 263   369 257
Income before income taxes   160 88 65 150 78 (12) 153 66 313 216   338 165
Income taxes   41 22 16 41 21 (4) 38 17 79 58   90 35
Net income   119 66 49 109 57 (8) 115 49 234 158   248 130
Comprehensive income   119 66 49 109 57 (8) 115 49 234 158   249 130
Adjustment                            
New Accounting Pronouncements or Change in Accounting Principle [Line Items]                            
Income before income taxes $ (24)   21                      
Adjustment | JERSEY CENTRAL POWER & LIGHT COMPANY                            
New Accounting Pronouncements or Change in Accounting Principle [Line Items]                            
Amortization (deferral) of regulatory assets, net   2 2 2 2 4 2 4 5 6 8   11 7
Other operating expenses   0 4 0 1 (1) (1) 4 (2) 4 (1)   (2) 0
Total operating expenses   2 6 2 3 3 1 8 3 10 7   9 7
Operating income   (2) (6) (2) (3) (3) (1) (8) (3) (10) (7)   (9) (7)
Income before income taxes   (2) (6) (2) (3) (3) (1) (8) (3) (10) (7)   (9) (7)
Income taxes   (1) (2) 0 (1) (1) 0 (2) (1) (3) (2)   (3) (2)
Net income   (1) (4) (2) (2) (2) (1) (6) (2) (7) (5)   (6) (5)
Comprehensive income   $ (1) $ (4) $ (2) $ (2) $ (2) $ (1) $ (6) $ (2) $ (7) $ (5)   $ (6) $ (5)
[1] Includes affiliated operating expenses of $116 million, $118 million and $122 million in 2025, 2024 and 2023, respectively.
v3.25.4
REVISION OF PREVIOUSLY ISSUED QUATERLY FINANCIAL STATEMENTS (Unaudited) - Schedule of Error Corrections related to Balance Sheets (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Sep. 30, 2025
Jun. 30, 2025
Mar. 31, 2025
Dec. 31, 2024
Sep. 30, 2024
Jun. 30, 2024
Mar. 31, 2024
Dec. 31, 2023
Dec. 31, 2022
New Accounting Pronouncements or Change in Accounting Principle [Line Items]                    
PP&E - In service $ 56,213       $ 52,896          
Accumulated provision for depreciation 15,189       14,548          
PP&E Excluding CWIP 41,024       38,348          
Total PP&E 44,413       41,102          
Regulatory assets/(liabilities) (356)       (378)          
Total investments and other noncurrent assets 8,512       8,166          
Total Assets [1] 55,904       52,044          
Accumulated deferred income taxes 6,032       5,613          
Total noncurrent liabilities 36,707       33,327          
Total liabilities [1] 41,978       38,324          
Retained earnings 35       43          
Total common stockholders' equity 12,510       12,455          
JERSEY CENTRAL POWER & LIGHT COMPANY                    
New Accounting Pronouncements or Change in Accounting Principle [Line Items]                    
PP&E - In service 9,267 $ 9,057 $ 8,970 $ 8,841 8,731 $ 8,536 $ 8,474 $ 8,352 $ 8,288  
Accumulated provision for depreciation 2,439 2,435 2,464 2,445 2,439 2,414 2,400 2,379 2,373  
PP&E Excluding CWIP 6,828 6,622 6,506 6,396 6,292 6,122 6,074 5,973 5,915  
Total PP&E 7,708 7,460 7,232 7,057 6,912 6,710 6,585 6,473 6,390  
Regulatory assets/(liabilities) 515 386 331 272 247 138 82 (1) (56)  
Total investments and other noncurrent assets 2,997 2,819 2,740 2,663 2,622 2,500 2,431 2,344 2,330  
Total Assets 11,109 11,466 10,427 10,057 9,913 9,599 9,489 9,207 9,102  
Accumulated deferred income taxes 1,348 1,285 1,250 1,219 1,192 1,106 1,035 985 955  
Total noncurrent liabilities 5,411 5,373 4,010 3,977 4,601 3,828 3,740 3,692 3,723  
Total liabilities 5,949 6,387 5,378 5,071 4,946 4,573 4,572 4,946 4,974  
Retained earnings 1,498 1,419 1,391 1,329 1,312 1,373 1,266 1,211 1,220  
Total common stockholders' equity $ 5,160 5,079 5,049 4,986 4,967 5,026 4,917 4,261 4,128 $ 3,968
As Reported | JERSEY CENTRAL POWER & LIGHT COMPANY                    
New Accounting Pronouncements or Change in Accounting Principle [Line Items]                    
PP&E - In service   9,002 8,940 8,807 8,697 8,521 8,458 8,340 8,278  
Accumulated provision for depreciation   2,380 2,434 2,415 2,409 2,402 2,388 2,371 2,365  
PP&E Excluding CWIP   6,622 6,506 6,392 6,288 6,119 6,070 5,969 5,913  
Total PP&E   7,460 7,232 7,053 6,908 6,707 6,581 6,469 6,388  
Regulatory assets/(liabilities)   410 354 292 265 153 95 9 (48)  
Total investments and other noncurrent assets   2,843 2,763 2,683 2,640 2,515 2,444 2,353 2,330  
Total Assets   11,490 10,450 10,073 9,927 9,611 9,498 9,212 9,100  
Accumulated deferred income taxes   1,292 1,257 1,223 1,196 1,109 1,037 986 957  
Total noncurrent liabilities   5,380 4,017 3,981 4,605 3,831 3,742 3,692 3,717  
Total liabilities   6,394 5,385 5,075 4,950 4,576 4,574 4,946 4,968  
Retained earnings   1,436 1,407 1,341 1,322 1,382 1,273 1,216 1,224  
Total common stockholders' equity   5,096 5,065 4,998 4,977 5,035 4,924 4,266 4,132 3,967
Adjustment | JERSEY CENTRAL POWER & LIGHT COMPANY                    
New Accounting Pronouncements or Change in Accounting Principle [Line Items]                    
PP&E - In service   55 30 34 34 15 16 12 10  
Accumulated provision for depreciation   55 30 30 30 12 12 8 8  
PP&E Excluding CWIP   0 0 4 4 3 4 4 2  
Total PP&E   0 0 4 4 3 4 4 2  
Regulatory assets/(liabilities)   (24) (23) (20) (18) (15) (13) (10) (8)  
Total investments and other noncurrent assets   (24) (23) (20) (18) (15) (13) (9) 0  
Total Assets   (24) (23) (16) (14) (12) (9) (5) 2  
Accumulated deferred income taxes   (7) (7) (4) (4) (3) (2) (1) (2)  
Total noncurrent liabilities   (7) (7) (4) (4) (3) (2) 0 6  
Total liabilities   (7) (7) (4) (4) (3) (2) 0 6  
Retained earnings   (17) (16) (12) (10) (9) (7) (5) (4)  
Total common stockholders' equity   $ (17) $ (16) $ (12) $ (10) $ (9) $ (7) $ (5) $ (4) $ 1
[1] As of December 31, 2025 and 2024, the combined assets of the VIEs were $13,269 million and $12,053 million, respectively, that can only be used to settle obligations of the VIEs. As of December 31, 2025 and 2024, these assets include, respectively: Cash and cash equivalents of $8 million and $8 million, Restricted cash of $40 million and $40 million, Accounts receivable of $92 million and $96 million, Materials and supplies, at average cost of $1 million and $1 million, Prepaid taxes and other current assets of $41 million and $22 million, Property, plant, and equipment of $12,475 million and $11,217 million, Goodwill of $224 million and $224 million, Investments of $19 million and $19 million,
Regulatory assets of $21 million and $92 million, and Other noncurrent assets of $348 million and $334 million. The consolidated liabilities as of December 31, 2025 and 2024, include $10,176 million and $9,147 million, respectively, of liabilities of VIEs whose creditors have no recourse to FE. As of December 31, 2025 and 2024, these liabilities include, respectively: Currently payable long-term debt of $126 million and $674 million, Short-term borrowings of $245 million and $300 million, Accrued interest of $108 million and $76 million, Accrued taxes of $335 million and $306 million, other current liabilities of $9 million and $10 million, Long-term debt and other long-term obligations of $6,884 million and $5,544 million, Accumulated deferred income taxes of $1,540 million and $1,411 million, Regulatory liabilities of $598 million and $526 million, and Other noncurrent liabilities of $331 million and $300 million.
v3.25.4
REVISION OF PREVIOUSLY ISSUED QUATERLY FINANCIAL STATEMENTS (Unaudited) - Schedule of Error Corrections related to Statements of Equity (Details) - USD ($)
$ in Millions
 3 Months Ended 12 Months Ended
Sep. 30, 2025
Jun. 30, 2025
Mar. 31, 2025
Sep. 30, 2024
Jun. 30, 2024
Mar. 31, 2024
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Increase (Decrease) in Stockholders' Equity [Roll Forward]                  
Beginning balance     $ 12,455       $ 12,455    
Net income             1,020 $ 978 $ 1,102
Ending balance             12,510 12,455  
JERSEY CENTRAL POWER & LIGHT COMPANY                  
Increase (Decrease) in Stockholders' Equity [Roll Forward]                  
Beginning balance $ 5,049 $ 4,986 4,967 $ 4,917 $ 4,261 $ 4,128 4,967 4,128 3,968
Net income 118 62 47 107 55 (9) 306 242 125
Ending balance 5,079 5,049 4,986 5,026 4,917 4,261 5,160 4,967 4,128
As Reported | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Increase (Decrease) in Stockholders' Equity [Roll Forward]                  
Beginning balance 5,065 4,998 4,977 4,924 4,266 4,132 4,977 4,132 3,967
Net income 119 66 49 109 57 (8)   248 130
Ending balance 5,096 5,065 4,998 5,035 4,924 4,266   4,977 4,132
Adjustment | JERSEY CENTRAL POWER & LIGHT COMPANY                  
Increase (Decrease) in Stockholders' Equity [Roll Forward]                  
Beginning balance (16) (12) (10) (7) (5) (4) $ (10) (4) 1
Net income (1) (4) (2) (2) (2) (1)   (6) (5)
Ending balance $ (17) $ (16) $ (12) $ (9) $ (7) $ (5)   $ (10) $ (4)
v3.25.4
REVISION OF PREVIOUSLY ISSUED QUATERLY FINANCIAL STATEMENTS (Unaudited) - Schedule of Error Corrections related to Statements of Cash Flows (Details) - USD ($)
$ in Millions
 3 Months Ended 6 Months Ended 9 Months Ended 12 Months Ended
Sep. 30, 2025
Jun. 30, 2025
Mar. 31, 2025
Sep. 30, 2024
Jun. 30, 2024
Mar. 31, 2024
Jun. 30, 2025
Jun. 30, 2024
Sep. 30, 2025
Sep. 30, 2024
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
CASH FLOWS FROM OPERATING ACTIVITIES:                          
Net income                     $ 1,271 $ 1,127 $ 1,176
Adjustments to reconcile net income to net cash from operating activities-                          
Depreciation, amortization, and impairments                     1,607 1,446 1,255
Deferred income taxes and investment tax credits, net                     219 316 252
Net cash provided from operating activities                     3,700 2,891 1,387
CASH FLOWS FROM INVESTING ACTIVITIES:                          
Capital investments                     (4,705) (4,030) (3,356)
Net cash used for investing activities                     (5,065) (4,350) (3,652)
JERSEY CENTRAL POWER & LIGHT COMPANY                          
CASH FLOWS FROM OPERATING ACTIVITIES:                          
Net income $ 118 $ 62 $ 47 $ 107 $ 55 $ (9) $ 109 $ 47 $ 227 $ 153 306 242 125
Adjustments to reconcile net income to net cash from operating activities-                          
Depreciation, amortization, and impairments     45     73 98 113 177 152 130 172 152
Deferred income taxes and investment tax credits, net     23     27 51 76 82 146 143 230 48
Net cash provided from operating activities     205     84 322 166 377 428 571 609 264
CASH FLOWS FROM INVESTING ACTIVITIES:                          
Capital investments     (206)     (195) (473) (389) (778) (600) (1,105) (879) (633)
Net cash used for investing activities     (226)     (216) (523) (423) (873) (649) (1,204) (949) (690)
Net change in cash, cash equivalents, and restricted cash     0     0 0 0 708 0 $ 0 0 0
As Reported | JERSEY CENTRAL POWER & LIGHT COMPANY                          
CASH FLOWS FROM OPERATING ACTIVITIES:                          
Net income 119 66 49 109 57 (8) 115 49 234 158   248 130
Adjustments to reconcile net income to net cash from operating activities-                          
Depreciation, amortization, and impairments     43     71 94 108 171 144   161 145
Deferred income taxes and investment tax credits, net     23     27 53 77 85 148   233 50
Net cash provided from operating activities     205     83 326 164 381 427   607 264
CASH FLOWS FROM INVESTING ACTIVITIES:                          
Capital investments     (206)     (194) (477) (387) (782) (599)   (877) (633)
Net cash used for investing activities     (226)     (215) (527) (421) (877) (648)   (947) (690)
Net change in cash, cash equivalents, and restricted cash     0     0 0 0 708 0   0 0
Adjustment | JERSEY CENTRAL POWER & LIGHT COMPANY                          
CASH FLOWS FROM OPERATING ACTIVITIES:                          
Net income $ (1) $ (4) (2) $ (2) $ (2) (1) (6) (2) (7) (5)   (6) (5)
Adjustments to reconcile net income to net cash from operating activities-                          
Depreciation, amortization, and impairments     2     2 4 5 6 8   11 7
Deferred income taxes and investment tax credits, net     0     0 (2) (1) (3) (2)   (3) (2)
Net cash provided from operating activities     0     1 (4) 2 (4) 1   2 0
CASH FLOWS FROM INVESTING ACTIVITIES:                          
Capital investments     0     (1) 4 (2) 4 (1)   (2) 0
Net cash used for investing activities     0     (1) 4 (2) 4 (1)   (2) 0
Net change in cash, cash equivalents, and restricted cash     $ 0     $ 0 $ 0 $ 0 $ 0 $ 0   $ 0 $ 0