DTE ENERGY CO, 10-K filed on 2/17/2026
Annual Report
v3.25.4
Cover - USD ($)
$ in Billions
 12 Months Ended
Dec. 31, 2025
Jan. 30, 2026
Jun. 30, 2025
Entity 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 1-11607    
Entity Registrant Name DTE Energy Co    
Entity Incorporation, State or Country Code MI    
Entity Tax Identification Number 38-3217752    
Entity Address, Address Line One One Energy Plaza    
Entity Address, City or Town Detroit    
Entity Address, State or Province MI    
Entity Address, Postal Zip Code 48226-1221    
City Area Code 313    
Local Phone Number 235-4000    
Entity Well-known Seasoned Issuer Yes    
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 [Flag] false    
Entity Shell Company false    
Entity Public Float     $ 27.3
Entity Common Stock, Shares Outstanding   207,803,764  
Documents Incorporated by Reference
Certain information in DTE Energy's definitive Proxy Statement for its 2026 Annual Meeting of Common Shareholders to be held May 7, 2026, which will be filed with the Securities and Exchange Commission pursuant to Regulation 14A, not later than 120 days after the end of the Registrants' fiscal year covered by this report on Form 10-K, is incorporated herein by reference to Part III (Items 10, 11, 12, 13, and 14) of this Form 10-K.
This combined Form 10-K is filed separately by two registrants: DTE Energy and DTE Electric. Information contained herein relating to any individual registrant is filed by such registrant solely on its own behalf. DTE Electric makes no representation as to information relating exclusively to DTE Energy.
DTE Electric, an indirect wholly-owned subsidiary of DTE Energy, meets the conditions set forth in General Instructions I(1)(a) and (b) of Form 10-K and is therefore filing this form with the reduced disclosure format specified in General Instruction I(2) of Form 10-K.
    
Entity Central Index Key 0000936340    
Document Fiscal Year Focus 2025    
Document Fiscal Period Focus FY    
Amendment Flag false    
Common stock, without par value      
Entity Information [Line Items]      
Title of 12(b) Security Common stock, without par value    
Trading Symbol DTE    
Security Exchange Name NYSE    
2017 Series E 5.25% Junior Subordinated Debentures due 2077      
Entity Information [Line Items]      
Title of 12(b) Security 2017 Series E 5.25% Junior Subordinated Debentures due 2077    
Trading Symbol DTW    
Security Exchange Name NYSE    
2021 Series E 4.375% Junior Subordinated Debentures due 2081      
Entity Information [Line Items]      
Title of 12(b) Security 2020 Series G 4.375% Junior Subordinated Debentures due 2080    
Trading Symbol DTB    
Security Exchange Name NYSE    
2021 Series E 4.375% Junior Subordinated Debentures due 2081      
Entity Information [Line Items]      
Title of 12(b) Security 2021 Series E 4.375% Junior Subordinated Debentures due 2081    
Trading Symbol DTG    
Security Exchange Name NYSE    
Series H, 2025, 6.25% Junior Subordinated Debentures Due 2085      
Entity Information [Line Items]      
Title of 12(b) Security 2025 Series H 6.25% Junior Subordinated Debenture due 2085    
Trading Symbol DTK    
Security Exchange Name NYSE    
DTE Electric      
Entity Information [Line Items]      
Entity File Number 1-2198    
Entity Registrant Name DTE Electric Co    
Entity Incorporation, State or Country Code MI    
Entity Tax Identification Number 38-0478650    
Entity Well-known Seasoned Issuer Yes    
Entity Voluntary Filers No    
Entity Current Reporting Status Yes    
Entity Interactive Data Current Yes    
Entity Filer Category Non-accelerated Filer    
Entity Small Business false    
Entity Emerging Growth Company false    
ICFR Auditor Attestation Flag false    
Document Financial Statement Error Correction [Flag] false    
Entity Shell Company false    
Entity Common Stock, Shares Outstanding   138,632,324  
Entity Central Index Key 0000028385    
v3.25.4
Audit Information
 12 Months Ended
Dec. 31, 2025
Auditor [Line Items]  
Auditor Firm ID 238
Auditor Name PricewaterhouseCoopers LLP
Auditor Location Detroit, Michigan
DTE Electric  
Auditor [Line Items]  
Auditor Firm ID 238
Auditor Name PricewaterhouseCoopers LLP
Auditor Location Detroit, Michigan
v3.25.4
Consolidated Statements of Operations - DTE Energy Company - USD ($)
shares in Millions, $ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Operating Revenues      
Utility operations $ 8,849 $ 7,990 $ 7,466
Non-utility operations 6,965 4,467 5,279
Operating Revenues 15,814 12,457 12,745
Operating Expenses      
Fuel, purchased power, and gas — utility 2,213 1,978 1,845
Fuel, purchased power, gas, and other — non-utility 6,426 3,879 4,413
Operation and maintenance 2,382 2,262 2,160
Depreciation and amortization 1,841 1,732 1,606
Taxes other than income 529 487 462
Asset (gains) losses and impairments, net 49 28 16
Operating Expenses 13,440 10,366 10,502
Operating Income 2,374 2,091 2,243
Other (Income) and Deductions      
Interest expense 1,056 951 791
Interest income (103) (136) (57)
Non-operating retirement benefits, net 0 0 9
Other income (230) (167) (102)
Other expenses 101 73 36
Other (Income) and Deductions 824 721 677
Income Before Income Taxes 1,550 1,370 1,566
Income Tax Expense (Benefit) at Effective Tax Rate 88 (34) 169
Net Income Attributable to DTE Energy Company/DTE Electric Company $ 1,462 $ 1,404 $ 1,397
Basic Earnings per Common Share      
Net Income Attributable to DTE Energy Company (in dollars per share) $ 7.04 $ 6.78 $ 6.77
Diluted Earnings per Common Share      
Net Income Attributable to DTE Energy Company (in dollars per share) $ 7.03 $ 6.77 $ 6.76
Weighted Average Common Shares Outstanding      
Basic (in shares) 207 207 206
Diluted (in shares) 207 207 206
v3.25.4
Consolidated Statements of Comprehensive Income - DTE Energy Company - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Statement of Comprehensive Income [Abstract]      
Net Income $ 1,462 $ 1,404 $ 1,397
Other comprehensive income (loss), net of tax:      
Benefit obligations, net of taxes of $(2), $—, and $2, respectively (5) 1 6
Net unrealized gains (losses) on derivatives, net of taxes of $(4), $15, and $(4), respectively (11) 47 (13)
Foreign currency translation 3 (7) 2
Other comprehensive income (loss) (13) 41 (5)
Comprehensive Income (Loss) Attributable to DTE Energy Company/DTE Electric Company $ 1,449 $ 1,445 $ 1,392
v3.25.4
Consolidated Statements of Comprehensive Income - DTE Energy Company (Parenthetical) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Statement of Comprehensive Income [Abstract]      
Benefit obligations, net of taxes $ (2) $ 0 $ 2
Net unrealized gains (losses) on derivatives, net of taxes $ (4) $ 15 $ (4)
v3.25.4
Consolidated Statements of Financial Position - DTE Energy Company - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Current Assets    
Cash and cash equivalents $ 208 $ 24
Restricted cash 42 64
Accounts receivable (less allowance for doubtful accounts of $60 and $70, respectively)    
Customer 2,031 1,690
Other 118 137
Inventories    
Fuel and gas 381 443
Materials, supplies, and other 994 802
Derivative assets 143 162
Regulatory assets 170 50
Other 261 235
Total Current Assets 4,348 3,607
Investments    
Nuclear decommissioning trust funds 2,552 2,256
Investments in equity method investees 122 128
Other 194 176
Total Investments 2,868 2,560
Property    
Property, plant, and equipment 44,623 40,840
Accumulated depreciation and amortization (10,970) (9,947)
Total Property 33,653 30,893
Other Assets    
Goodwill 1,993 1,993
Regulatory assets 7,380 6,771
Securitized regulatory assets 619 690
Intangible assets 188 144
Notes receivable 1,455 898
Derivative assets 89 85
Prepaid postretirement costs 761 705
Operating lease right-of-use assets 271 188
Other 441 312
Total Other Assets 13,197 11,786
Total Assets 54,066 48,846
Current Liabilities    
Accounts payable 1,753 1,387
Accrued interest 273 224
Dividends payable 242 226
Short-term borrowings 882 1,067
Current portion long-term debt, including securitization bonds and finance leases 1,356 1,296
Derivative liabilities 86 118
Regulatory liabilities 107 181
Operating lease liabilities 32 21
Other 678 586
Total Current Liabilities 5,409 5,106
Long-Term Debt (net of current portion)    
Mortgage bonds, notes, and other 21,736 19,153
Securitization bonds 561 635
Junior subordinated debentures 1,474 884
Finance lease obligations 14 18
Total Long-Term Debt (net of current portion) 23,785 20,690
Other Liabilities    
Deferred income taxes 3,400 2,958
Regulatory liabilities 2,881 2,856
Asset retirement obligations 4,469 4,031
Unamortized investment tax credit 402 269
Derivative liabilities 66 57
Accrued pension liability 235 214
Accrued postretirement liability 247 233
Nuclear decommissioning 405 353
Operating lease liabilities 235 167
Other 224 208
Total Other Liabilities 12,564 11,346
Commitments and Contingencies (Notes 9 and 18)
Equity    
Common stock (No par value, 400,000,000 shares authorized, and 207,745,154 and 207,171,582 shares issued and outstanding at December 31, 2025 and December 31, 2024, respectively) 6,858 6,779
Retained earnings 5,484 4,946
Accumulated other comprehensive loss (39) (26)
Total DTE Energy Company/DTE Electric Company Equity 12,303 11,699
Noncontrolling interests 5 5
Total Equity 12,308 11,704
Total Liabilities and Equity $ 54,066 $ 48,846
v3.25.4
Consolidated Statements of Financial Position - DTE Energy Company (Parenthetical) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Current Assets    
Accounts receivable less allowance for doubtful accounts $ 60 $ 70
Equity    
Common stock, shares authorized (in shares) 400,000,000 400,000,000
Common stock, shares issued (in shares) 207,745,154 207,171,582
Common stock, shares outstanding (in shares) 207,745,154 207,171,582
v3.25.4
Consolidated Statements of Cash Flows - DTE Energy Company - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Operating Activities      
Net Income $ 1,462 $ 1,404 $ 1,397
Adjustments to reconcile Net Income to Net cash from operating activities:      
Depreciation and amortization 1,841 1,732 1,606
Nuclear fuel amortization 67 55 59
Allowance for equity funds used during construction (105) (86) (42)
Deferred income taxes 358 194 181
Equity (earnings) losses of equity method investees (47) (15) (3)
Dividends from equity method investees 3 3 3
Asset (gains) losses and impairments, net 49 28 16
Changes in assets and liabilities:      
Accounts receivable, net (316) (40) 398
Inventories (127) (191) (110)
Prepaid postretirement benefit costs (56) (72) (62)
Accounts payable 255 45 (306)
Accrued pension liability 21 (136) (28)
Accrued postretirement liability 14 (68) 14
Derivative assets and liabilities 6 25 (321)
Regulatory assets and liabilities 24 586 594
Other current and noncurrent assets and liabilities (40) 179 (176)
Net cash from operating activities 3,409 3,643 3,220
Investing Activities      
Plant and equipment expenditures — utility (4,343) (4,399) (3,872)
Plant and equipment expenditures — non-utility (86) (68) (62)
Acquisition related to business combination, net of cash acquired (210) 0 0
Proceeds from sale of assets 32 46 3
Proceeds from sale of nuclear decommissioning trust fund assets 717 555 681
Investment in nuclear decommissioning trust funds (719) (559) (678)
Distributions from equity method investees 18 30 25
Contributions to equity method investees (1) (27) (27)
Investment in notes receivable (600) (479) (109)
Principal collections on notes receivable 22 30 23
Investment in time deposits 0 (1,050) 0
Redemption of time deposits 0 1,050 0
Other (134) (80) (79)
Net cash used for investing activities (5,304) (4,951) (4,095)
Financing Activities      
Issuance of long-term debt, net of discount and issuance costs 4,429 4,533 3,167
Redemption of long-term debt (1,291) (2,139) (1,616)
Short-term borrowings, net (185) (216) 121
Dividends paid on common stock (871) (810) (752)
Other (25) (23) (37)
Net cash from financing activities 2,057 1,345 883
Net Increase in Cash, Cash Equivalents, and Restricted Cash 162 37 8
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period 88 51 43
Cash, Cash Equivalents, and Restricted Cash at End of Period 250 88 51
Supplemental disclosure of cash information      
Interest, net of interest capitalized 978 869 751
Supplemental disclosure of non-cash investing and financing activities      
Plant and equipment expenditures in accounts payable $ 570 $ 454 $ 490
v3.25.4
Consolidated Statements of Changes in Equity - DTE Energy Company - USD ($)
$ in Millions
Total
Common Stock
Retained Earnings
Accumulated Other Comprehensive Income (Loss)
Noncontrolling Interests
Beginning balance (in shares) at Dec. 31, 2022   205,632,000      
Beginning balance at Dec. 31, 2022 $ 10,401 $ 6,651 $ 3,808 $ (62) $ 4
Increase (Decrease) in Stockholders' Equity [Roll Forward]          
Net Income 1,397   1,397    
Dividends declared on common stock (800)   (800)    
Issuance of common stock (in shares)   318,000      
Issuance of common stock 35 $ 35      
Other comprehensive income (loss), net of tax (5)     (5)  
Stock-based compensation and other (in shares)   407,000      
Stock-based compensation and other 27 $ 27 (1)   1
Ending balance (in shares) at Dec. 31, 2023   206,357,000      
Ending balance at Dec. 31, 2023 11,055 $ 6,713 4,404 (67) 5
Increase (Decrease) in Stockholders' Equity [Roll Forward]          
Net Income 1,404   1,404    
Dividends declared on common stock (859)   (859)    
Issuance of common stock (in shares)   309,000      
Issuance of common stock 35 $ 35      
Other comprehensive income (loss), net of tax 41     41  
Stock-based compensation and other (in shares)   506,000      
Stock-based compensation and other $ 28 $ 31 (3)    
Ending balance (in shares) at Dec. 31, 2024 207,171,582 207,172,000      
Ending balance at Dec. 31, 2024 $ 11,704 $ 6,779 4,946 (26) 5
Increase (Decrease) in Stockholders' Equity [Roll Forward]          
Net Income 1,462   1,462    
Dividends declared on common stock (921)   (921)    
Issuance of common stock (in shares)   264,000      
Issuance of common stock 34 $ 34      
Other comprehensive income (loss), net of tax (13)     (13)  
Stock-based compensation and other (in shares)   309,000      
Stock-based compensation and other $ 42 $ 45 (3)    
Ending balance (in shares) at Dec. 31, 2025 207,745,154 207,745,000      
Ending balance at Dec. 31, 2025 $ 12,308 $ 6,858 $ 5,484 $ (39) $ 5
v3.25.4
Consolidated Statements of Changes in Equity - DTE Energy Company (Parenthetical) - $ / shares
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Statement of Stockholders' Equity [Abstract]      
Dividends declared on common stock (in dollars per share) $ 4.44 $ 4.15 $ 3.88
v3.25.4
Consolidated Statements of Operations - DTE Electric Company - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Operating Revenues — Utility operations $ 8,849 $ 7,990 $ 7,466
Operating Expenses      
Fuel, purchased power, and gas — utility 2,213 1,978 1,845
Taxes other than income 529 487 462
Asset (gains) losses and impairments, net 49 28 16
Operating Expenses 13,440 10,366 10,502
Operating Income 2,374 2,091 2,243
Other (Income) and Deductions      
Interest expense 1,056 951 791
Interest income (103) (136) (57)
Non-operating retirement benefits, net 0 0 9
Other income (230) (167) (102)
Other expenses 101 73 36
Other (Income) and Deductions 824 721 677
Income Before Income Taxes 1,550 1,370 1,566
Income Tax Expense (Benefit) 88 (34) 169
Net Income Attributable to DTE Energy Company/DTE Electric Company 1,462 1,404 1,397
DTE Electric      
Operating Revenues — Utility operations 6,885 6,277 5,804
Operating Expenses      
Fuel, purchased power, and gas — utility 1,816 1,618 1,492
Operation and maintenance 1,468 1,435 1,421
Depreciation and amortization 1,530 1,432 1,326
Taxes other than income 381 352 338
Asset (gains) losses and impairments, net 46 12 26
Operating Expenses 5,241 4,849 4,603
Operating Income 1,644 1,428 1,201
Other (Income) and Deductions      
Interest expense 550 495 429
Interest income (9) (7) (20)
Non-operating retirement benefits, net (5) (5) (4)
Other income (171) (144) (87)
Other expenses 56 49 33
Other (Income) and Deductions 421 388 351
Income Before Income Taxes 1,223 1,040 850
Income Tax Expense (Benefit) 71 (32) 78
Net Income Attributable to DTE Energy Company/DTE Electric Company $ 1,152 $ 1,072 $ 772
v3.25.4
Consolidated Statements of Comprehensive Income - DTE Electric Company - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Net Income $ 1,462 $ 1,404 $ 1,397
Other comprehensive income (13) 41 (5)
Comprehensive Income (Loss) Attributable to DTE Energy Company/DTE Electric Company 1,449 1,445 1,392
DTE Electric      
Net Income 1,152 1,072 772
Other comprehensive income 0 0 0
Comprehensive Income (Loss) Attributable to DTE Energy Company/DTE Electric Company $ 1,152 $ 1,072 $ 772
v3.25.4
Consolidated Statements of Financial Position - DTE Electric Company - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Current Assets    
Cash and cash equivalents $ 208 $ 24
Restricted cash 42 64
Accounts receivable (less allowance for doubtful accounts of $41 and $46, respectively)    
Customer 2,031 1,690
Other 118 137
Inventories    
Fuel 381 443
Materials and supplies 994 802
Regulatory assets 170 50
Other 261 235
Total Current Assets 4,348 3,607
Investments    
Nuclear decommissioning trust funds 2,552 2,256
Other 194 176
Total Investments 2,868 2,560
Property    
Property, plant, and equipment 44,623 40,840
Accumulated depreciation and amortization (10,970) (9,947)
Total Property 33,653 30,893
Other Assets    
Regulatory assets 7,380 6,771
Securitized regulatory assets 619 690
Prepaid postretirement costs 761 705
Operating lease right-of-use assets 271 188
Other 441 312
Total Other Assets 13,197 11,786
Total Assets 54,066 48,846
Accounts payable    
Accounts payable 1,753 1,387
Accrued interest 273 224
Current portion long-term debt, including securitization bonds and finance leases 1,356 1,296
Regulatory liabilities 107 181
Short-term borrowings    
Short-term borrowings 882 1,067
Operating lease liabilities 32 21
Other 678 586
Total Current Liabilities 5,409 5,106
Long-Term Debt (net of current portion)    
Mortgage bonds, notes, and other 21,736 19,153
Securitization bonds 561 635
Finance lease liabilities 14 18
Total Long-Term Debt (net of current portion) 23,785 20,690
Other Liabilities    
Deferred income taxes 3,400 2,958
Regulatory liabilities 2,881 2,856
Asset retirement obligations 4,469 4,031
Unamortized investment tax credit 402 269
Nuclear decommissioning 405 353
Accrued pension liability — affiliates 235 214
Accrued postretirement liability — affiliates 247 233
Operating lease liabilities 235 167
Other 224 208
Total Other Liabilities 12,564 11,346
Commitments and Contingencies (Notes 9 and 18)
Shareholder's Equity    
Common stock ($10 par value, 400,000,000 shares authorized, and 138,632,324 shares issued and outstanding for both periods) 6,858 6,779
Retained earnings 5,484 4,946
Total DTE Energy Company/DTE Electric Company Equity 12,303 11,699
Total Liabilities and Equity 54,066 48,846
DTE Electric    
Current Assets    
Cash and cash equivalents 81 11
Restricted cash 42 48
Accounts receivable (less allowance for doubtful accounts of $41 and $46, respectively)    
Other 55 58
Inventories    
Fuel 114 193
Materials and supplies 678 537
Regulatory assets 158 39
Other 116 101
Total Current Assets 2,051 1,769
Investments    
Nuclear decommissioning trust funds 2,552 2,256
Other 72 67
Total Investments 2,624 2,323
Property    
Property, plant, and equipment 33,807 30,801
Accumulated depreciation and amortization (8,239) (7,404)
Total Property 25,568 23,397
Other Assets    
Regulatory assets 6,821 6,187
Securitized regulatory assets 619 690
Prepaid postretirement costs 463 428
Operating lease right-of-use assets 237 159
Other 607 268
Total Other Assets 8,747 7,732
Total Assets 38,990 35,221
Accounts payable    
Accrued interest 135 128
Current portion long-term debt, including securitization bonds and finance leases 754 425
Regulatory liabilities 63 156
Short-term borrowings    
Short-term borrowings 652 666
Operating lease liabilities 27 18
Other 228 204
Total Current Liabilities 2,769 2,342
Long-Term Debt (net of current portion)    
Mortgage bonds, notes, and other 11,852 10,825
Securitization bonds 561 635
Finance lease liabilities 6 8
Total Long-Term Debt (net of current portion) 12,419 11,468
Other Liabilities    
Deferred income taxes 3,812 3,393
Regulatory liabilities 1,798 1,753
Asset retirement obligations 4,217 3,791
Unamortized investment tax credit 402 269
Nuclear decommissioning 405 353
Accrued pension liability — affiliates 245 248
Accrued postretirement liability — affiliates 237 225
Operating lease liabilities 206 142
Other 66 83
Total Other Liabilities 11,388 10,257
Commitments and Contingencies (Notes 9 and 18)
Shareholder's Equity    
Common stock ($10 par value, 400,000,000 shares authorized, and 138,632,324 shares issued and outstanding for both periods) 8,949 7,995
Retained earnings 3,465 3,159
Total DTE Energy Company/DTE Electric Company Equity 12,414 11,154
Total Liabilities and Equity 38,990 35,221
DTE Electric | Customer    
Accounts receivable (less allowance for doubtful accounts of $41 and $46, respectively)    
Customer 805 734
Accounts payable    
Accounts payable 839 681
DTE Electric | Affiliates    
Accounts receivable (less allowance for doubtful accounts of $41 and $46, respectively)    
Customer 2 6
Inventories    
Notes receivable 0 42
Accounts payable    
Accounts payable $ 71 $ 64
v3.25.4
Consolidated Statements of Financial Position - DTE Electric Company (Parenthetical) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Current Assets    
Accounts receivable less allowance for doubtful accounts $ 60 $ 70
Equity    
Common stock, shares authorized (in shares) 400,000,000 400,000,000
Common stock, shares issued (in shares) 207,745,154 207,171,582
Common stock, shares outstanding (in shares) 207,745,154 207,171,582
DTE Electric    
Current Assets    
Accounts receivable less allowance for doubtful accounts $ 41 $ 46
Equity    
Common stock, par value (in dollars per share) $ 10 $ 10
Common stock, shares authorized (in shares) 400,000,000 400,000,000
Common stock, shares issued (in shares) 138,632,324 138,632,324
Common stock, shares outstanding (in shares) 138,632,324 138,632,324
v3.25.4
Consolidated Statements of Cash Flows - DTE Electric Company - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Operating Activities      
Net Income $ 1,462 $ 1,404 $ 1,397
Adjustments to reconcile Net Income to Net cash from operating activities:      
Depreciation and amortization 1,841 1,732 1,606
Nuclear fuel amortization 67 55 59
Allowance for equity funds used during construction (105) (86) (42)
Deferred income taxes 358 194 181
Asset (gains) losses and impairments, net 49 28 16
Changes in assets and liabilities:      
Accounts receivable, net (316) (40) 398
Inventories (127) (191) (110)
Accounts payable 255 45 (306)
Regulatory assets and liabilities 24 586 594
Other current and noncurrent assets and liabilities (40) 179 (176)
Net cash from operating activities 3,409 3,643 3,220
Investing Activities      
Proceeds from sale of nuclear decommissioning trust fund assets 717 555 681
Investment in nuclear decommissioning trust funds (719) (559) (678)
Investment in notes receivable (600) (479) (109)
Principal collections on notes receivable 22 30 23
Other (134) (80) (79)
Net cash used for investing activities (5,304) (4,951) (4,095)
Financing Activities      
Issuance of long-term debt, net of discount and issuance costs 4,429 4,533 3,167
Redemption of long-term debt (1,291) (2,139) (1,616)
Short-term borrowings, net (185) (216) 121
Dividends paid on common stock (871) (810) (752)
Other (25) (23) (37)
Net cash from financing activities 2,057 1,345 883
Net Increase in Cash, Cash Equivalents, and Restricted Cash 162 37 8
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period 88 51 43
Cash, Cash Equivalents, and Restricted Cash at End of Period 250 88 51
Supplemental disclosure of cash information      
Interest, net of interest capitalized 978 869 751
Supplemental disclosure of non-cash investing and financing activities      
Plant and equipment expenditures in accounts payable 570 454 490
DTE Electric      
Operating Activities      
Net Income 1,152 1,072 772
Adjustments to reconcile Net Income to Net cash from operating activities:      
Depreciation and amortization 1,530 1,432 1,326
Nuclear fuel amortization 67 55 59
Allowance for equity funds used during construction (103) (84) (40)
Deferred income taxes 339 196 82
Asset (gains) losses and impairments, net 46 12 26
Changes in assets and liabilities:      
Accounts receivable, net (64) 33 (14)
Inventories (62) (130) (99)
Prepaid postretirement benefit costs — affiliates (35) (50) (33)
Accounts payable 57 25 (9)
Accrued pension liability — affiliates (3) (86) (53)
Accrued postretirement liability — affiliates 12 (65) 15
Regulatory assets and liabilities (9) 499 461
Other current and noncurrent assets and liabilities (208) (93) (218)
Net cash from operating activities 2,719 2,816 2,275
Investing Activities      
Plant and equipment expenditures (3,686) (3,636) (3,089)
Proceeds from sale of nuclear decommissioning trust fund assets 717 555 681
Investment in nuclear decommissioning trust funds (719) (559) (678)
Investment in notes receivable (231) (42) (20)
Principal collections on notes receivable 1 14 17
Other (88) (74) (44)
Net cash used for investing activities (4,006) (3,742) (3,133)
Financing Activities      
Issuance of long-term debt, net of discount and issuance costs 1,694 993 1,881
Redemption of long-term debt (421) (164) (541)
Capital contribution by parent company 954 634 759
Dividends paid on common stock (846) (776) (1,002)
Other (16) (15) (21)
Net cash from financing activities 1,351 953 866
Net Increase in Cash, Cash Equivalents, and Restricted Cash 64 27 8
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period 59 32 24
Cash, Cash Equivalents, and Restricted Cash at End of Period 123 59 32
Supplemental disclosure of cash information      
Interest, net of interest capitalized 529 467 409
Supplemental disclosure of non-cash investing and financing activities      
Plant and equipment expenditures in accounts payable 484 369 403
DTE Electric | Affiliates      
Financing Activities      
Short-term borrowings, net 0 0 (27)
DTE Electric | Other      
Financing Activities      
Short-term borrowings, net $ (14) $ 281 $ (183)
v3.25.4
Consolidated Statements of Changes in Shareholder's Equity - DTE Electric Company - USD ($)
$ in Millions
Total
Common Stock
Retained Earnings
DTE Electric
DTE Electric
Common Stock
DTE Electric
Additional Paid-in Capital
DTE Electric
Retained Earnings
Beginning balance (in shares) at Dec. 31, 2022   205,632,000     138,632,000    
Beginning balance at Dec. 31, 2022       $ 9,695 $ 1,386 $ 5,216 $ 3,093
Increase (Decrease) in Stockholders' Equity [Roll Forward]              
Net Income $ 1,397   $ 1,397 772     772
Dividends declared on common stock (800)   (800) (1,002)     (1,002)
Capital contribution by parent company       759   759  
Ending balance (in shares) at Dec. 31, 2023   206,357,000     138,632,000    
Ending balance at Dec. 31, 2023       10,224 $ 1,386 5,975 2,863
Increase (Decrease) in Stockholders' Equity [Roll Forward]              
Net Income 1,404   1,404 1,072     1,072
Dividends declared on common stock $ (859)   (859) (776)     (776)
Capital contribution by parent company       $ 634   634  
Ending balance (in shares) at Dec. 31, 2024 207,171,582 207,172,000   138,632,324 138,632,000    
Ending balance at Dec. 31, 2024 $ 11,699     $ 11,154 $ 1,386 6,609 3,159
Increase (Decrease) in Stockholders' Equity [Roll Forward]              
Net Income 1,462   1,462 1,152     1,152
Dividends declared on common stock $ (921)   $ (921) (846)     (846)
Capital contribution by parent company       $ 954   954  
Ending balance (in shares) at Dec. 31, 2025 207,745,154 207,745,000   138,632,324 138,632,000    
Ending balance at Dec. 31, 2025 $ 12,303     $ 12,414 $ 1,386 $ 7,563 $ 3,465
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
Corporate Structure
DTE Energy owns the following businesses:
•DTE Electric is a public utility engaged in the generation, purchase, distribution, and sale of electricity to approximately 2.3 million customers in southeastern Michigan;
•DTE Gas is a public utility engaged in the purchase, storage, transportation, distribution, and sale of natural gas to approximately 1.4 million customers throughout Michigan and the sale of storage and transportation capacity; and
•Other businesses include 1) DTE Vantage, which is primarily involved in renewable natural gas projects and providing custom energy solutions to industrial, commercial, and institutional customers, and 2) energy marketing and trading operations.
DTE Electric and DTE Gas are regulated by the MPSC. Certain activities of DTE Electric and DTE Gas, as well as various other aspects of businesses under DTE Energy, are regulated by the FERC. In addition, the Registrants are regulated by other federal and state regulatory agencies including the NRC, the EPA, EGLE, and for DTE Energy, the CFTC and CARB.
Basis of Presentation
The accompanying Consolidated Financial Statements of the Registrants are prepared using accounting principles generally accepted in the United States of America. These accounting principles require management to use estimates and assumptions that impact reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results may differ from the Registrants' estimates.
The information in these combined notes relates to each of the Registrants as noted in the Index of Combined Notes to Consolidated Financial Statements. However, DTE Electric does not make any representation as to information related solely to DTE Energy or the subsidiaries of DTE Energy other than itself.
Certain prior year balances for the Registrants were reclassified to match the current year's Consolidated Financial Statements presentation.
Principles of Consolidation
The Registrants consolidate all majority-owned subsidiaries and investments in entities in which they have controlling influence. Non-majority owned investments are accounted for using the equity method when the Registrants are able to significantly influence the operating policies of the investee. When the Registrants do not influence the operating policies of an investee, the equity investment is valued at cost minus any impairments, if applicable. These Consolidated Financial Statements also reflect the Registrants' proportionate interests in certain jointly-owned utility plants. The Registrants eliminate all intercompany balances and transactions.
The Registrants evaluate whether an entity is a VIE whenever reconsideration events occur. The Registrants consolidate VIEs for which they are the primary beneficiary. If a Registrant is not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, a Registrant considers all relevant facts and circumstances, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. The Registrants perform ongoing reassessments of all VIEs to determine if the primary beneficiary status has changed.
Legal entities within the DTE Vantage segment enter into long-term contractual arrangements with customers to supply energy-related products or services. The entities are generally designed to pass-through the commodity risk associated with these contracts to the customers, with DTE Energy retaining operational and customer default risk. These entities generally are VIEs and consolidated when DTE Energy is the primary beneficiary. In addition, DTE Energy has interests in certain VIEs through which control of all significant activities is shared with partners, and therefore are generally accounted for under the equity method.
The Registrants hold ownership interests in certain limited partnerships. The limited partnerships include investment funds which support regional development and economic growth, and an operational business providing energy-related products. These entities are generally VIEs as a result of certain characteristics of the limited partnership voting rights. The ownership interests are accounted for under the equity method as the Registrants are not the primary beneficiaries.
DTE Energy has variable interests in VIEs through certain of its long-term purchase and sale contracts. DTE Electric has variable interests in VIEs through certain of its long-term purchase contracts. As of December 31, 2025, the carrying amount of assets and liabilities in DTE Energy's Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase and sale contracts are predominantly related to working capital accounts and generally represent the amounts owed by or to DTE Energy for the deliveries associated with the current billing cycle under the contracts. As of December 31, 2025, the carrying amount of assets and liabilities in DTE Electric's Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase contracts are predominantly related to working capital accounts and generally represent the amounts owed by DTE Electric for the deliveries associated with the current billing cycle under the contracts. The Registrants have not provided any significant form of financial support associated with these long-term contracts. There is no material potential exposure to loss as a result of DTE Energy's variable interests through these long-term purchase and sale contracts. In addition, there is no material potential exposure to loss as a result of DTE Electric's variable interests through these long-term purchase contracts.
DTE Electric previously financed regulatory assets for deferred costs related to certain retired generation plants and its tree trimming surge program through the sale of bonds by wholly-owned special purpose entities, DTE Securitization I and DTE Securitization II (collectively "the DTE Securitization entities"). The DTE Securitization entities are VIEs. DTE Electric has the power to direct the most significant activities of these entities, including performing servicing activities such as billing and collecting surcharge revenue. Accordingly, DTE Electric is the primary beneficiary and the DTE Securitization entities are consolidated by the Registrants. Securitization bond holders have no recourse to the Registrants' assets, except for those held by the DTE Securitization entities. Surcharges collected by DTE Electric to pay for bond servicing and other qualified costs reflect securitization property solely owned by the DTE Securitization entities. These surcharges are remitted to a trustee and are not available to other creditors of the Registrants.
The maximum risk exposure for consolidated VIEs is reflected on the Registrants' Consolidated Statements of Financial Position. For non-consolidated VIEs, the maximum risk exposure of the Registrants is generally limited to their investment and notes receivable.
The table below summarizes the major Consolidated Statements of Financial Position items for consolidated VIEs as of December 31, 2025 and 2024. All assets and liabilities of a consolidated VIE are presented where it has been determined that a consolidated VIE has either (1) assets that can be used only to settle obligations of the VIE or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary. Assets and liabilities of the DTE Securitization entities have been aggregated due to their similar nature and are separately stated in the table below, comprising the entirety of the DTE Electric amounts. For all other VIEs, assets and liabilities are also aggregated due to their similar nature and presented together with the DTE Securitization entities in the DTE Energy amounts below. VIEs, in which DTE Energy holds a majority voting interest and is the primary beneficiary, that meet the definition of a business and whose assets can be used for purposes other than the settlement of the VIE's obligations have been excluded from the table.
During Q4 2025, a consolidated VIE of DTE Vantage completed a contract that previously restricted certain assets of the VIE to be used only to settle the VIE's obligations. As a result, the assets and liabilities of the VIE, which primarily include receivables and payables, meet the exclusion criteria above. Accordingly, these assets and liabilities have been removed from the DTE Energy amounts for 2025 in the table below.
Amounts for the Registrants' consolidated VIEs are as follows:
December 31,
20252024
DTE EnergyDTE ElectricDTE EnergyDTE Electric
(In millions)
ASSETS
Cash and cash equivalents$5 $— $6 $— 
Restricted cash42 42 64 48 
Accounts receivable10 6 27 6 
Securitized regulatory assets619 619 690 690 
Notes receivable(a)
68 — 657 — 
Other current and long-term assets1 — 1 — 
$745 $667 $1,445 $744 
LIABILITIES
Accounts payable$— — $26 $— 
Accrued interest11 11 12 12 
Regulatory liabilities — current23 23 27 27 
Securitization bonds(b)
636 636 706 706 
Other current and long-term liabilities4 — 20 — 
$674 $670 $791 $745 
_______________________________________
(a)At December 31, 2025 and December 31, 2024, Notes receivable includes $2 million and $14 million, respectively, reported in Current Assets — Other on DTE Energy's Consolidated Statements of Financial Position.
(b)Includes $75 million and $71 million reported in Current portion of long-term debt on the Registrants' Consolidated Statements of Financial Position at December 31, 2025 and December 31, 2024, respectively.
DTE Energy has Investments in equity method investees relating to non-consolidated VIEs of $63 million and $65 million at December 31, 2025 and 2024, respectively.
Equity Method Investments
Investments in non-consolidated affiliates that are not controlled by the Registrants, but over which they have significant influence, are accounted for using the equity method. Certain of the equity method investees are also considered VIEs and disclosed in the non-consolidated VIEs information above.
At December 31, 2025 and 2024, DTE Energy's Investments in equity method investees were $122 million and $128 million, respectively. The balances are primarily comprised of investments in the DTE Vantage segment and Corporate and Other, of which no investment is individually significant. DTE Vantage investments include projects that deliver energy and utility-type products and services to industrial customers, sell electricity and gas from renewable energy projects, and produce and sell metallurgical coke. Corporate and Other holds various ownership interests in limited partnerships that include investment funds supporting regional development and economic growth. For further information by segment, see Note 22 to the Consolidated Financial Statements, "Segment and Related Information."
At December 31, 2025 and 2024, DTE Energy's share of the underlying equity in the net assets of the investees exceeded the carrying amounts of Investments in equity method investees by $96 million and $94 million, respectively. The difference is being amortized over the life of the underlying assets.
v3.25.4
Significant Accounting Policies
 12 Months Ended
Dec. 31, 2025
Accounting Policies [Abstract]  
Significant Accounting Policies SIGNIFICANT ACCOUNTING POLICIES
Other Income
Other income for the Registrants is recognized for non-operating income such as equity earnings of equity method investees, allowance for equity funds used during construction, contract services, and certain investment income, primarily from trading securities held in DTE Energy's rabbi trust.
The following is a summary of DTE Energy's Other income:
Year Ended December 31,
202520242023
(In millions)
Allowance for equity funds used during construction$105 $86 $42 
Equity earnings of equity method investees47 15 3 
Contract services43 34 26 
Investment income(a)
17 17 17 
Other18 15 14 
$230 $167 $102 
_______________________________________
(a)Investment losses are recorded separately to Other expenses on the Consolidated Statements of Operations.
The following is a summary of DTE Electric's Other income:
Year Ended December 31,
202520242023
(In millions)
Allowance for equity funds used during construction$103 $84 $40 
Contract services43 33 25 
Investment income(a)
14 13 11 
Other11 14 11 
$171 $144 $87 
_______________________________________
(a)Investment losses are recorded separately to Other expenses on the Consolidated Statements of Operations.
For information on equity earnings of equity method investees by segment, see Note 22 to the Consolidated Financial Statements, "Segment and Related Information."
Accounting for ISO Transactions
DTE Electric participates in the energy market through MISO. MISO requires that DTE Electric submit hourly day-ahead, real-time, and FTR bids and offers for energy at locations across the MISO region. DTE Electric accounts for MISO transactions on a net hourly basis in each of the day-ahead, real-time, and FTR markets. In any single hour, transactions in each of the MISO energy markets are netted based on MWh to determine if DTE Electric is in a net sale or purchase position. Net purchases are recorded in Fuel, purchased power, and gas — utility and net sales are recorded in Operating Revenues — Utility operations on the Registrants' Consolidated Statements of Operations.
The Energy Trading segment participates in the energy markets through various ISOs and RTOs. These markets require that Energy Trading submits hourly day-ahead, real-time bids and offers for energy at locations across each region. Energy Trading submits bids in the annual and monthly auction revenue rights and FTR auctions to the RTOs. Energy Trading accounts for these transactions on a net hourly basis for the day-ahead, real-time, and FTR markets. These transactions are related to trading contracts which, if derivatives, are presented on a net basis in Operating Revenues — Non-utility operations, and if non-derivatives, the realized gains and losses for sales are recorded in Operating Revenues — Non-utility operations and purchases are recorded in Fuel, purchased power, gas, and other — non-utility in the DTE Energy Consolidated Statements of Operations.
DTE Electric and Energy Trading record accruals for future net purchase adjustments based on historical experience and reconcile accruals to actual costs when invoices are received from MISO and other ISOs and RTOs.
Derivatives
Energy Trading classifies derivative transactions as revenue or expense based on the intent of the transaction (buy or sell). Revenues are recorded on a gross or net basis within the income statement depending upon whether it represents a non-trading activity or trading activity, respectively. Cash flows associated with derivative instruments, including related gains and losses, are presented as Operating Activities within the Registrants' Consolidated Statements of Cash Flows. For additional information, refer to Note 13 to the Consolidated Financial Statements, "Financial and Other Derivative Instruments."
Changes in Accumulated Other Comprehensive Income (Loss)
Comprehensive income (loss) is the change in common shareholders’ equity during a period from transactions and events from non-owner sources, including Net Income. The amounts recorded to Accumulated other comprehensive income (loss) for DTE Energy include changes in benefit obligations, consisting of deferred actuarial losses and prior service costs, unrealized gains and losses from derivatives accounted for as cash flow hedges, and foreign currency translation adjustments, if any. DTE Energy releases income tax effects from accumulated other comprehensive income when the circumstances upon which they are premised cease to exist.
Changes in Accumulated other comprehensive income (loss) are presented in DTE Energy's Consolidated Statements of Changes in Equity and DTE Electric's Consolidated Statements of Changes in Shareholder's Equity, if any. For the years ended December 31, 2025 and 2024, reclassifications out of Accumulated other comprehensive income (loss) were not material.
The following table summarizes the changes in DTE Energy's Accumulated other comprehensive income (loss) by component(a) for the years ended December 31, 2025 and 2024:
Net Unrealized Gain (Loss) on Derivatives
Benefit Obligations(b)
Foreign Currency TranslationTotal
(In millions)
Balance, December 31, 2023$(17)$(52)$2 $(67)
Other comprehensive income (loss) before reclassifications47 (3)(7)37 
Amounts reclassified from Accumulated other comprehensive loss— 4 — 4 
Net current period Other comprehensive income (loss)47 1 (7)41 
Balance, December 31, 2024$30 $(51)$(5)$(26)
Other comprehensive income (loss) before reclassifications(8)(9)3 (14)
Amounts reclassified from Accumulated other comprehensive loss(3)4 — 1 
Net current period Other comprehensive income (loss)(11)(5)3 (13)
Balance, December 31, 2025$19 $(56)$(2)$(39)
______________________________________
(a)All amounts are net of tax, except for foreign currency translation.
(b)Benefit obligations activity includes changes in actuarial (gain) loss and prior service cost in DTE Energy's pension and other postretirement benefit plans. Refer to Note 20 to the Consolidated Financial Statements, "Retirement Benefits and Trusteed Assets," for details regarding this activity.
Cash, Cash Equivalents, and Restricted Cash
Cash and cash equivalents include cash on hand, cash in banks, and temporary investments purchased with maturities of three months or less. Restricted cash includes funds held in separate bank accounts and principally consists of amounts at DTE Securitization I and DTE Securitization II to pay for debt service and other qualified costs. Restricted cash designated for payments within one year is classified as a Current Asset.
Financing Receivables
Financing receivables are primarily composed of trade receivables, notes receivable, and unbilled revenue. The Registrants' financing receivables are stated at net realizable value.
DTE Energy had unbilled revenues of $1.3 billion and $1.0 billion at December 31, 2025 and 2024, respectively, including $322 million and $303 million of DTE Electric unbilled revenues, respectively, included in Customer Accounts receivable.
The Registrants monitor the credit quality of their financing receivables on a regular basis by reviewing credit quality indicators and monitoring for trigger events, such as a credit rating downgrade or bankruptcy. Credit quality indicators include, but are not limited to, ratings by credit agencies where available, collection history, collateral, counterparty financial statements and other internal metrics. Utilizing such data, the Registrants have determined three internal grades of credit quality. Internal grade 1 includes financing receivables for counterparties where credit rating agencies have ranked the counterparty as investment grade. To the extent credit ratings are not available, the Registrants utilize other credit quality indicators to determine the level of risk associated with the financing receivable. Internal grade 1 may include financing receivables for counterparties for which credit rating agencies have ranked the counterparty as below investment grade; however, due to favorable information on other credit quality indicators, the Registrants have determined the risk level to be similar to that of an investment grade counterparty. Internal grade 2 includes financing receivables for counterparties with limited credit information and those with a higher risk profile based upon credit quality indicators. Internal grade 3 reflects financing receivables for which the counterparties have the greatest level of risk, including those in bankruptcy status.
The following represents the Registrants' financing receivables by year of origination as determined by the date the original agreement was executed, classified by internal grade of credit risk, including current year-to-date gross write-offs, if any. The related credit quality indicators and risk ratings utilized to develop the internal grades have been updated through December 31, 2025.
DTE Energy
DTE Electric(a)
Year of Origination
202520242023 and priorTotal2025 and prior
(In millions)
Notes receivable
Internal grade 1$247 $4 $27 $278 $274 
Internal grade 24 923 250 1,177 — 
Total notes receivable(b)
$251 $927 $277 $1,455 $274 
Net investment in leases
Internal grade 1$— $— $34 $34 $— 
Internal grade 2— 2 — 2 — 
Total net investment in leases(b)
$— $2 $34 $36 $— 
_______________________________________
(a)For DTE Electric, $247 million is included in Internal grade 1 with a 2025 year of origination.
(b)For DTE Energy, the current portion is included in Current Assets — Other on the Consolidated Statements of Financial Position. For DTE Electric, the amounts are included in Other Assets — Other on the Consolidated Statements of Financial Position.
The allowance for doubtful accounts on accounts receivable for the utility entities is generally calculated using an aging approach that utilizes rates developed in reserve studies. DTE Electric and DTE Gas establish an allowance for uncollectible accounts based on historical losses and management's assessment of existing and future economic conditions, customer trends and other factors. Customer accounts are generally considered delinquent if the amount billed is not received by the due date, which is typically in 21 days, however, factors such as assistance programs may delay aggressive action. DTE Electric and DTE Gas generally assess late payment fees on trade receivables based on past-due terms with customers. Customer accounts are written off when collection efforts have been exhausted. The time period for write-off is 150 days after service has been terminated.
The customer allowance for doubtful accounts for non-utility businesses and other receivables for both utility and non-utility businesses is generally calculated based on specific review of probable future collections based on receivable balances generally in excess of 30 days. Existing and future economic conditions, customer trends and other factors are also considered. Receivables are written off on a specific identification basis and determined based upon the specific circumstances of the associated receivable.
Notes receivable for DTE Energy are primarily comprised of loans, MISO deposits, and finance lease receivables that are included in Notes Receivable and Other current assets on DTE Energy's Consolidated Statements of Financial Position. Notes receivable for DTE Electric are primarily comprised of MISO deposits and loans that are included in current Notes receivable and Other long-term assets on DTE Electric's Consolidated Statements of Financial Position.
The Registrants establish an allowance for credit loss for principal and interest amounts due that are estimated to be uncollectible in accordance with the contractual terms of the note receivable. In determining the allowance for credit losses for notes receivable, the Registrants consider the historical payment experience and other factors that are expected to have a specific impact on the counterparty's ability to pay including existing and future economic conditions. Notes receivable are typically considered delinquent when payment is not received for periods ranging from 60 to 120 days. If amounts are no longer probable of collection, the Registrants may consider the note receivable impaired, adjust the allowance, and cease accruing interest (nonaccrual status).
Cash payments received on nonaccrual status notes receivable, that do not bring the account contractually current, are first applied to the contractually owed past due interest, with any remainder applied to principal. Accrual of interest is generally resumed when the note receivable becomes contractually current.
The following tables present a roll-forward of the activity for the Registrants' financing receivables credit loss reserves:
DTE EnergyDTE Electric
Trade accounts receivable
Other receivables(a)
TotalTrade and other accounts receivable
(In millions)
Balance at December 31, 2022$78 $1 $79 $49 
Current period provision52 — 52 36 
Write-offs charged against allowance(112)— (112)(72)
Recoveries of amounts previously written off44 — 44 28 
Balance at December 31, 2023$62 $1 $63 $41 
Current period provision74 2 76 49 
Write-offs charged against allowance(108)— (108)(70)
Recoveries of amounts previously written off41 — 41 26 
Balance at December 31, 2024$69 $3 $72 $46 
Current period provision69 — 69 44 
Write-offs charged against allowance(116)— (116)(74)
Recoveries of amounts previously written off37 — 37 25 
Balance at December 31, 2025$59 $3 $62 $41 
____________________________________
(a)Other receivables includes reserves on notes receivable and Accounts receivable — Other.
Uncollectible expense for the Registrants is primarily comprised of the current period provision for allowance for doubtful accounts and is summarized as follows:
Year Ended December 31,
202520242023
(In millions)
DTE Energy$70 $74 $55 
DTE Electric$45 $50 $38 
There are no material amounts of past due financing receivables for the Registrants as of December 31, 2025.
Inventories
Inventory related to utility and non-utility operations is valued at the lower of cost or net realizable value, where cost is generally valued using average cost. Inventory primarily includes fuel, gas, materials, and supplies. Other inventories include RECs, emission allowances, and other environmental products primarily in the Energy Trading segment.
DTE Gas' natural gas inventory includes $43 million and $69 million as of December 31, 2025 and 2024, respectively, that is determined using the last-in, first-out (LIFO) method. The replacement cost of gas in inventory exceeded the LIFO cost by $147 million and $81 million at December 31, 2025 and 2024, respectively.
Property, Retirement and Maintenance, and Depreciation and Amortization
Property is stated at cost and includes construction-related labor, materials, overheads, and AFUDC for utility property. The cost of utility properties retired is charged to accumulated depreciation. Expenditures for maintenance and repairs are charged to expense when incurred.
Utility property at DTE Electric and DTE Gas is depreciated over its estimated useful life using straight-line rates approved by the MPSC. DTE Energy's non-utility property is depreciated over its estimated useful life using the straight-line method. Depreciation and amortization expense also includes the amortization of certain regulatory assets and liabilities for the Registrants.
The cost of nuclear fuel is capitalized. The amortization of nuclear fuel is included within Fuel, purchased power, and gas — utility in the DTE Energy Consolidated Statements of Operations, and Fuel and purchased power in the DTE Electric Consolidated Statements of Operations, and is recorded using the units-of-production method.
See Note 6 to the Consolidated Financial Statements, "Property, Plant, and Equipment."
Long-Lived Assets
Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of an asset may not be recoverable. If the carrying amount of the asset exceeds the expected undiscounted future cash flows generated by the asset, an impairment loss is recognized resulting in the asset being written down to its estimated fair value. Assets to be disposed of are reported at the lower of the carrying amount or fair value, less costs to sell.
Goodwill
DTE Energy has goodwill resulting from business combinations. For each reporting unit, DTE Energy performs an impairment test annually or whenever events or circumstances indicate that the value of goodwill may be impaired. For the years ended December 31, 2025 and 2024, there were no impairments resulting from these tests and there were no other changes in the carrying amount of goodwill.
Intangible Assets
The Registrants have certain Intangible assets as shown below:
December 31, 2025December 31, 2024
Useful LivesGross Carrying ValueAccumulated AmortizationNet Carrying ValueGross Carrying ValueAccumulated AmortizationNet Carrying Value
(In millions)
Intangible assets subject to amortization
Contract intangibles
5 to 39 years
$306 $(137)$169 $246 $(119)$127 
Carbon offsets16 — 16 14 — 14 
Renewable energy credits— — — 1 — 1 
Other3 — 3 2 — 2 
Intangible assets not subject to amortization(a)
19 — 19 17 — 17 
DTE Energy Long-term intangible assets$325 $(137)$188 $263 $(119)$144 
______________________________________
(a)Amounts are charged to expense, using average cost, as they are consumed in the operation of the business. DTE Electric intangible assets include the Renewable energy credits above, which are included in Other Assets — Other on the DTE Electric Consolidated Statements of Financial Position.
The following table summarizes DTE Energy's estimated contract intangible amortization expense expected to be recognized during each year through 2030:
20262027202820292030
(In millions)
Estimated amortization expense$24 $24 $24 $24 $22 
DTE Energy amortizes contract intangible assets on a straight-line basis over the expected period of benefit. DTE Energy's Intangible assets amortization expense was $18 million, $16 million, and $15 million in 2025, 2024, and 2023, respectively.
Cloud Computing Arrangements
The Registrants capitalize implementation costs incurred in a cloud computing arrangement that is a service contract consistent with capitalized implementation costs incurred to develop or obtain internal-use software. Capitalized costs are recorded in Other noncurrent assets on the Consolidated Statements of Financial Position and amortization of the costs is reflected in Operation and maintenance within the Consolidated Statements of Operations. Costs are amortized on a straight-line basis over the life of the contract. Contracts primarily involve the implementation or upgrade of cloud-based solutions for generation and distribution operations and customer service support.
The following balances for cloud computing costs relate to DTE Energy:
Year Ended December 31,
202520242023
(In millions)
Amortization expense of capitalized cloud computing costs$13 $12 $10 
Gross value of capitalized cloud computing costs$94 $64 
Accumulated amortization of capitalized cloud computing costs$40 $27 
The following balances for cloud computing costs relate to DTE Electric:
Year Ended December 31,
202520242023
(In millions)
Amortization expense of capitalized cloud computing costs$10 $10 $8 
Gross value of capitalized cloud computing costs$69 $51 
Accumulated amortization of capitalized cloud computing costs$32 $22 
Excise and Sales Taxes
The Registrants record the billing of excise and sales taxes as a receivable with an offsetting payable to the applicable taxing authority, with no net impact on the Registrants’ Consolidated Statements of Operations.
Deferred Debt Costs
The costs related to the issuance of long-term debt are deferred and amortized over the life of each debt issue. The deferred amounts are included as a direct deduction from the carrying amount of each debt issue in Mortgage bonds, notes, and other and Securitization bonds on the Registrants' Consolidated Statements of Financial Position and in Junior subordinated debentures on DTE Energy's Consolidated Statements of Financial Position. In accordance with MPSC regulations applicable to DTE Energy’s electric and gas utilities, the unamortized discount, premium, and expense related to utility debt redeemed with a refinancing are amortized over the life of the replacement issue. Discounts, premiums, and expense on early redemptions of debt associated with DTE Energy's non-utility operations are charged to earnings.
Investments in Debt and Equity Securities
The Registrants generally record investments in debt and equity securities at market value with unrealized gains or losses included in earnings. Changes in the fair value of Fermi 2 nuclear decommissioning investments are recorded as adjustments to Regulatory assets or liabilities, due to a recovery mechanism from customers. The Registrants' equity investments are reviewed for impairment each reporting period. If the assessment indicates that an impairment exists, a loss is recognized resulting in the equity investment being written down to its estimated fair value. See Note 12 of the Consolidated Financial Statements, "Fair Value."
DTE Energy Foundation
DTE Energy made charitable contributions to the DTE Energy Foundation of $20 million and $10 million for the years ended December 31, 2025 and 2024, respectively. DTE Energy made no such contribution for the year ended December 31, 2023. The DTE Energy Foundation is a non-consolidated not-for-profit private foundation, the purpose of which is to contribute to and assist charitable organizations.
Other Accounting Policies
See the following notes for other accounting policies impacting the Registrants’ Consolidated Financial Statements:
NoteTitle
5Revenue
6Property, Plant, and Equipment
8Asset Retirement Obligations
9Regulatory Matters
10Income Taxes
12Fair Value
13Financial and Other Derivative Instruments
17Leases
20Retirement Benefits and Trusteed Assets
21Stock-Based Compensation
22Segment and Related Information
23Related Party Transactions
v3.25.4
New Accounting Pronouncements
 12 Months Ended
Dec. 31, 2025
Accounting Standards Update and Change in Accounting Principle [Abstract]  
New Accounting Pronouncements NEW ACCOUNTING PRONOUNCEMENTS
Recently Adopted Pronouncements
In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740): Improvements to Income Tax Disclosures. The amendments in this update require enhanced income tax disclosures, particularly related to a reporting entity's effective tax rate reconciliation and income taxes paid. For the rate reconciliation table, the update requires additional categories of information about federal, state, and foreign taxes and details about significant reconciling items, subject to a quantitative threshold. Income taxes paid must be similarly disaggregated by federal, state, and foreign based on a quantitative threshold. The Registrants adopted the ASU effective January 1, 2025 using the retrospective approach, with no impact on the Registrants' financial position or results of operations. Additional required disclosures have been included in Note 10 to the Consolidated Financial Statements, "Income Taxes."
Recently Issued Pronouncements
In November 2024, the FASB issued ASU No. 2024-03, Income Statement-Reporting Comprehensive Income – Expense Disaggregation Disclosures (Subtopic 220-40): Disaggregation of Income Statement Expenses, as amended. The amendments in this update require disaggregated disclosure of income statement expense captions into specified categories in disclosures within the footnotes to the financial statements. The ASU is effective for the Registrants for annual reporting periods beginning after December 15, 2026, and for interim reporting periods beginning after December 15, 2027. The guidance may be applied on a prospective or retrospective basis. Early adoption is permitted. The Registrants will apply the guidance upon the effective date.
In July 2025, the FASB issued ASU No. 2025-05, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses for Accounts Receivable and Contract Assets, which provides a practical expedient related to the estimation of expected credit losses for current accounts receivable and current contract assets arising from transactions accounted for under ASC 606. The ASU is effective for the Registrants for annual and interim periods beginning after December 15, 2025. The guidance should be applied on a prospective basis. Early adoption is permitted. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements.
In September 2025, the FASB issued ASU No. 2025-06, Intangibles – Goodwill and Other – Internal-Use Software (Subtopic 350-40): Targeted Improvements to the Accounting for Internal-Use Software. The amendments in this update modernize the accounting guidance for the costs to develop software for internal use. The amendments remove all references to a sequential software development method (referred to as "project stages") throughout ASC 350-40 and clarifies the threshold entities should apply to begin capitalizing eligible costs. The ASU is effective for the Registrants for annual and interim periods beginning after December 15, 2027. The guidance may be applied on a prospective, retrospective, or modified transition basis. Early adoption is permitted. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements.
v3.25.4
Acquisition
 12 Months Ended
Dec. 31, 2025
Business Combination [Abstract]  
Acquisitions ACQUISITION
Electric Segment Acquisition
Effective August 14, 2025, DTE Sustainable Generation closed on the purchase of a 123 MW cogeneration facility, located in Michigan, from Osaka Gas USA Corporation. The acquisition adds generating capacity to DTE Energy's portfolio. Direct transaction costs, primarily related to advisory fees, were immaterial and were included in Operation and maintenance in DTE Energy's Consolidated Statements of Operations for the period incurred. The fair value of consideration provided for the acquisition was approximately $216 million, including working capital adjustments, which was paid in cash.
The acquisition was accounted for using the acquisition method of accounting for business combinations. Accordingly, the cost was allocated to the underlying net assets based on their respective fair values as shown below:
(In millions)
Cash$6 
Contract intangibles57 
Property, plant, and equipment, net135 
Working capital, other assets and liabilities18 
Total$216 
The intangible assets recorded pertain to existing customer contracts and were estimated by applying the income approach, based on discounted projected cash flows attributable to the existing agreements. The contract intangible assets are amortized on a straight-line basis with remaining useful lives of 5 years in conjunction with the associated contracts' remaining terms. The pro forma financial information has not been presented for DTE Energy because the effects of the acquisition were not material to DTE Energy’s Consolidated Statements of Operations.
The acquired project constitutes non-utility operations and related revenues are classified accordingly as Operating Revenues — Non-utility operations within DTE Energy's Consolidated Statements of Operations and the Electric segment Results of Operations. Refer to Note 22 to the Consolidated Financial Statements, "Segment and Related Information."
v3.25.4
Revenue
 12 Months Ended
Dec. 31, 2025
Revenue from Contract with Customer [Abstract]  
Revenue REVENUE
Significant Accounting Policy
Revenue is measured based upon the consideration specified in a contract with a customer at the time when performance obligations are satisfied. A performance obligation is a promise in a contract to transfer a distinct good or service or a series of distinct goods or services to the customer. The Registrants recognize revenue when performance obligations are satisfied by transferring control over a product or service to a customer. The Registrants have determined control to be transferred when the product is delivered, or the service is provided to the customer.
Rates for DTE Electric and DTE Gas include provisions to adjust billings for fluctuations in fuel and purchased power costs, cost of natural gas, and certain other costs. Revenues are adjusted for differences between actual costs subject to reconciliation and the amounts billed in current rates. Under or over recovered revenues related to these cost recovery mechanisms are included in Regulatory assets or liabilities on the Registrants' Consolidated Statements of Financial Position and are recovered or returned to customers through adjustments to the billing factors.
For discussion of derivative contracts, see Note 13 to the Consolidated Financial Statements, "Financial and Other Derivative Instruments."
Disaggregation of Revenue
The following is a summary of revenues disaggregated by segment for DTE Energy:
Year Ended December 31,
202520242023
(In millions)
Electric(a)
Residential$3,144 $3,045 $2,847 
Commercial2,195 2,263 2,114 
Industrial652 715 732 
Other(b)
944 270 125 
Total Electric operating revenues$6,935 $6,293 $5,818 
Gas
Gas sales$1,521 $1,307 $1,324 
End User Transportation255 246 250 
Intermediate Transportation87 83 85 
Other(b)
189 162 89 
Total Gas operating revenues$2,052 $1,798 $1,748 
Other segment operating revenues
DTE Vantage$696 $753 $809 
Energy Trading$6,477 $3,843 $4,612 
_______________________________________
(a)Revenues generally represent those of DTE Electric, except $50 million, $16 million, and $14 million of Other revenues related to DTE Sustainable Generation for the years ended December 31, 2025, 2024, and 2023, respectively.
(b)Includes revenue adjustments related to various regulatory mechanisms, including the PSCR at the Electric segment and GCR at the Gas segment, and interconnection sales in the Electric segment. Revenues related to these mechanisms may vary based on changes in the cost of fuel, purchased power, and gas.
Revenues included the following which were outside the scope of Topic 606:
Year Ended December 31,
202520242023
(In millions)
Electric — Alternative Revenue Programs$48 $43 $36 
Electric — Other revenues$23 $25 $22 
Gas — Alternative Revenue Programs$8 $21 $16 
Gas — Other revenues$12 $11 $8 
DTE Vantage — Leases$61 $60 $59 
Energy Trading — Derivatives$4,571 $2,540 $3,436 
Nature of Goods and Services
The following is a description of principal activities, separated by reportable segments, from which DTE Energy generates revenue. For more detailed information about reportable segments, see Note 22 to the Consolidated Financial Statements, “Segment and Related Information.”
The Registrants have contracts with customers which may contain more than one performance obligation. When more than one performance obligation exists in a contract, the consideration under the contract is allocated to the performance obligations based on the relative standalone selling price. DTE Energy generally determines standalone selling prices based on the prices charged to customers or the use of the adjusted market assessment approach. The adjusted market assessment approach involves the evaluation of the market in which DTE Energy sells goods or services and estimating the price that a customer in that market would be willing to pay.
Under Topic 606, when a customer simultaneously receives and consumes the product or service provided, revenue is considered to be recognized over time. Alternatively, if it is determined that the criteria for recognition of revenue over time is not met, the revenue is considered to be recognized at a point in time.
Electric segment
The Electric segment consists principally of DTE Electric. Electric revenues are primarily comprised of the supply and delivery of electricity, related capacity, and RECs. Revenues are primarily associated with cancellable contracts, with the exception of certain long-term contracts with commercial and industrial customers. Revenues, including estimated unbilled amounts, are generally recognized over time based upon volumes delivered or through the passage of time ratably based upon providing a stand-ready service. The Registrants have determined that the above methods represent a faithful depiction of the transfer of control to the customer. Unbilled revenues are typically determined utilizing approved tariff rates and estimated meter volumes. Estimated unbilled amounts recognized in revenue are subject to adjustment in the following reporting period as actual volumes by customer class are known. Revenues are typically subject to tariff rates based upon customer class and type of service and are billed and received monthly. Tariff rates are determined by the MPSC on a per unit or monthly basis.
Gas segment
The Gas segment consists principally of DTE Gas. Gas revenues are primarily comprised of the supply and delivery of natural gas, and other services including storage, transportation, and appliance maintenance. Revenues are primarily associated with cancellable contracts, with the exception of certain long-term contracts with commercial and industrial customers. Revenues, including estimated unbilled amounts, are generally recognized over time based upon volumes delivered or through the passage of time ratably based upon providing a stand-ready service. DTE Energy has determined that the above methods represent a faithful depiction of the transfer of control to the customer. Unbilled revenues are typically determined using both estimated meter volumes and estimated usage based upon the number of unbilled days and historical temperatures. Estimated unbilled amounts recognized in revenue are subject to adjustment in the following reporting period as actual volumes by customer class and service type are known. Revenues are typically subject to tariff rates or other rates subject to regulatory oversight and are billed and received monthly. Tariff rates are determined by the MPSC on a per unit or monthly basis.
DTE Vantage segment
The DTE Vantage segment revenues include contracts accounted for as leases which are outside of the scope of Topic 606. For performance obligations within the scope of Topic 606, the timing of revenue recognition is dependent upon when control over the associated product or service is transferred.
Revenues at DTE Vantage, within the scope of Topic 606, generally consist of sales of blast furnace coke, renewable natural gas and related credits, electricity, equipment maintenance services, and other energy related products and services. Revenues for the sale of blast furnace coke, including estimated unbilled amounts, are recognized at a point in time when the product is delivered, which represents the transfer of control to the customer. Other revenues are generally recognized over time based upon volumes delivered or services provided, or through the passage of time ratably based upon providing a stand-ready service. DTE Energy has determined that the above methods represent a faithful depiction of the transfer of control to the customer. Market based pricing structures exist in such contracts including adjustments for consumer price or other indices. Consideration may consist of both fixed and variable components. Generally, uncertainties in the variable consideration components are resolved, and revenues are known at the time of recognition. Billing terms vary and are generally monthly with payment terms typically within 30 days following billing.
Energy Trading segment
The Energy Trading segment revenues consist primarily of derivative contracts outside of the scope of Topic 606. For performance obligations within the scope of Topic 606, the timing of revenue recognition is dependent upon when control over the associated product or service is transferred.
Revenues, including estimated unbilled amounts, within the scope of Topic 606 arising from the sale of natural gas, electricity, power capacity, and other energy related products are generally recognized over time based upon volumes delivered or through the passage of time ratably based upon providing a stand-ready service. DTE Energy has determined that the above methods represent a faithful depiction of the transfer of control to the customer. Revenues are known at the time of recognition. Payment for the aforementioned revenues is generally due from customers in the month following delivery.
Revenues associated with RECs and other environmental products are recognized at a point in time when control is transferred to the customer which is deemed to be when these products are entered for transfer to the customer in the applicable tracking system. Revenues associated with RECs under a wholesale full requirements power contract are deferred until control has been transferred. The deferred revenues represent a contract liability for which payment has been received and the amounts have been estimated using the adjusted market assessment approach. With the exception of RECs, generally all other performance obligations associated with wholesale full requirements power contracts are satisfied over time in conjunction with the delivery of power. At the time power is delivered, DTE Energy may not have control over the RECs as the RECs are not self-generated and may not yet have been procured resulting in deferred revenues.
Deferred Revenue
The following is a summary of deferred revenue activity for DTE Energy:
Year Ended December 31,
20252024
(In millions)
Beginning Balance, January 1$138 $106 
Increases due to cash received or receivable, excluding amounts recognized as revenue during the period166 132 
Revenue recognized that was included in the deferred revenue balance at the beginning of the period(134)(100)
Ending Balance, December 31$170 $138 
Deferred revenues are included in Current Liabilities — Other and Other Liabilities — Other on DTE Energy's Consolidated Statements of Financial Position. Deferred revenues generally represent amounts paid by or receivables from customers for which the associated performance obligation has not yet been satisfied. Deferred revenues include amounts associated with REC performance obligations under certain wholesale full requirements power contracts. Deferred revenues related to RECs are recognized as revenue when control of the RECs has transferred. Other performance obligations associated with deferred revenues include providing products and services related to customer prepayments. Deferred revenues associated with these products and services are recognized when control has transferred to the customer.
The following table represents deferred revenue amounts for DTE Energy that are expected to be recognized as revenue in future periods:
DTE Energy
(In millions)
2026$169 
20271 
2028— 
2029— 
2030— 
2031 and thereafter— 
$170 
Transaction Price Allocated to the Remaining Performance Obligations
In accordance with optional exemptions available under Topic 606, the Registrants did not disclose the value of unsatisfied performance obligations for (1) contracts with an original expected length of one year or less, (2) with the exception of fixed consideration, contracts for which revenue is recognized at the amount to which the Registrants have the right to invoice for goods provided and services performed, and (3) contracts for which variable consideration relates entirely to an unsatisfied performance obligation.
Such contracts consist of varying types of performance obligations across the segments, including the supply and delivery of energy related products and services. Contracts with variable volumes and/or variable pricing, including those with pricing provisions tied to a consumer price or other index, have also been excluded as the related consideration under the contract is variable at inception of the contract. Contract lengths vary from cancellable to multi-year.
The Registrants expect to recognize revenue for the following amounts related to fixed consideration associated with remaining performance obligations in each of the future periods noted:
DTE EnergyDTE Electric
(In millions)
2026$189 $1 
2027168 — 
2028110 — 
202991 — 
203081 — 
2031 and thereafter292 — 
$931 $1 
v3.25.4
Property, Plant, and Equipment
 12 Months Ended
Dec. 31, 2025
Property, Plant and Equipment [Abstract]  
Property, Plant, and Equipment PROPERTY, PLANT, AND EQUIPMENT
The following is a summary of Property, plant, and equipment by classification as of December 31:
20252024
Property, plant, and equipment(In millions)
DTE Electric
Distribution$16,316 $14,995 
Dispatchable generation8,647 8,428 
Renewable generation5,102 3,933 
Other3,742 3,445 
Total DTE Electric33,807 30,801 
DTE Gas
Distribution6,826 6,334 
Transmission1,267 1,212 
Storage589 586 
Other530 500 
Total DTE Gas9,212 8,632 
DTE Vantage1,191 1,135 
Other413 272 
Total DTE Energy$44,623 $40,840 
Accumulated depreciation and amortization
DTE Electric
Distribution$(3,729)$(3,513)
Dispatchable generation(2,584)(2,146)
Renewable generation(760)(615)
Other(1,166)(1,130)
Total DTE Electric(8,239)(7,404)
DTE Gas
Distribution(1,413)(1,319)
Transmission(291)(278)
Storage(140)(138)
Other(228)(210)
Total DTE Gas(2,072)(1,945)
DTE Vantage(564)(520)
Other(95)(78)
Total DTE Energy$(10,970)$(9,947)
Net DTE Energy Property, plant, and equipment$33,653 $30,893 
Net DTE Electric Property, plant, and equipment$25,568 $23,397 
AFUDC and Capitalized Interest
AFUDC represents the cost of financing construction projects for regulated businesses, including the estimated cost of debt and authorized return on equity. The debt component is recorded as a reduction to Interest expense and the equity component is recorded as Other income on the Registrants' Consolidated Statements of Operations. Non-regulated businesses record capitalized interest as a reduction to Interest expense.
The AFUDC and capitalized interest rates were as follows for the years ended December 31:
202520242023
DTE Electric AFUDC6.01 %5.56 %5.53 %
DTE Gas AFUDC5.80 %5.45 %5.41 %
Non-regulated businesses capitalized interest4.50 %4.25 %3.00 %
The following is a summary of AFUDC and interest capitalized for the years ended December 31:
202520242023
DTE Energy(In millions)
Allowance for debt funds used during construction and interest capitalized$47 $36 $20 
Allowance for equity funds used during construction105 86 42 
Total$152 $122 $62 
202520242023
DTE Electric(In millions)
Allowance for debt funds used during construction$45 $34 $15 
Allowance for equity funds used during construction103 84 40 
Total$148 $118 $55 
Depreciation and Amortization
The composite depreciation rate for DTE Electric was approximately 3.6% in 2025, 4.2% in 2024, and 4.4% in 2023. The composite depreciation rate for DTE Gas was 2.8% in 2025 and 2.9% in 2024 and 2023. The average estimated useful life for each major class of utility Property, plant, and equipment as of December 31, 2025 follows:
Estimated Useful Lives in Years
UtilityDistributionGenerationTransmissionStorage
DTE Electric3832N/AN/A
DTE Gas55N/A6760
The estimated useful lives for DTE Electric's Other utility assets range from 3 to 45 years, while the estimated useful lives for DTE Gas' Other utility assets range from 3 to 39 years. The estimated useful lives for major classes of DTE Energy's non-utility assets and facilities range from 3 to 50 years.
The following is a summary of Depreciation and amortization expense for DTE Energy:
Year Ended December 31,
202520242023
(In millions)
Property, plant, and equipment$1,265 $1,316 $1,239 
Regulatory assets and liabilities550 394 344 
Intangible assets18 16 15 
Other8 6 8 
$1,841 $1,732 $1,606 
The following is a summary of Depreciation and amortization expense for DTE Electric:
Year Ended December 31,
202520242023
(In millions)
Property, plant, and equipment$1,039 $1,089 $1,029 
Regulatory assets and liabilities486 338 292 
Other5 5 5 
$1,530 $1,432 $1,326 
Capitalized Software
Capitalized software costs are classified as Property, plant, and equipment and the related amortization is included in Accumulated depreciation and amortization on the Registrants' Consolidated Statements of Financial Position. The Registrants capitalize the costs associated with computer software developed or obtained for use in their businesses. The Registrants amortize capitalized software costs on a straight-line basis over the expected period of benefit, ranging from 3 to 15 years for both DTE Energy and DTE Electric.
The following balances for capitalized software relate to DTE Energy:
Year Ended December 31,
202520242023
(In millions)
Amortization expense of capitalized software$164 $192 $189 
Gross carrying value of capitalized software$1,211 $1,005 
Accumulated amortization of capitalized software$474 $476 
The following balances for capitalized software relate to DTE Electric:
Year Ended December 31,
202520242023
(In millions)
Amortization expense of capitalized software$146 $175 $172 
Gross carrying value of capitalized software$1,084 $910 
Accumulated amortization of capitalized software$399 $414 
v3.25.4
Jointly-Owned Utility Plant
 12 Months Ended
Dec. 31, 2025
Jointly Owned Utility Plant, Net Ownership Amount [Abstract]  
Jointly-Owned Utility Plant JOINTLY-OWNED UTILITY PLANT
DTE Electric has joint ownership interest in two power plants, Belle River and Ludington Hydroelectric Pumped Storage. DTE Electric’s share of direct expenses of the jointly-owned plants are included in Fuel, purchased power, and gas — utility and Operation and maintenance expenses in the DTE Energy Consolidated Statements of Operations and Fuel and purchased power— utility and Operation and maintenance expenses in the DTE Electric Consolidated Statements of Operations.
DTE Electric's ownership information of the two utility plants as of December 31, 2025 was as follows:
Belle RiverLudington
Hydroelectric
Pumped Storage
In-service date1984-19851973
Total plant capacity1,270 MW2,290 MW
Ownership interest81%49%
Investment in Property, plant, and equipment (in millions)$1,961 $676 
Accumulated depreciation (in millions)$1,198 $171 
Belle River
The Michigan Public Power Agency (MPPA) has ownership interests in Belle River Unit No. 1 and other related facilities. The MPPA is entitled to 19% of the total capacity and energy of the plant and is responsible for the same percentage of the plant’s operation, maintenance, and capital improvement costs.
Ludington Hydroelectric Pumped Storage
Consumers Energy Company has an ownership interest in the Ludington Hydroelectric Pumped Storage Plant. Consumers Energy is entitled to 51% of the total capacity and energy of the plant and is responsible for the same percentage of the plant’s operation, maintenance, and capital improvement costs.
For discussion of the ongoing contract dispute related to the Ludington Plant, see Note 18 to the Consolidated Financial Statements, "Commitments and Contingencies."
v3.25.4
Asset Retirement Obligations
 12 Months Ended
Dec. 31, 2025
Asset Retirement Obligation Disclosure [Abstract]  
Asset Retirement Obligations ASSET RETIREMENT OBLIGATIONS
DTE Electric has a legal retirement obligation for the decommissioning costs for its Fermi 1 and Fermi 2 nuclear plants, dismantlement of facilities located on leased property, and various other operations. DTE Electric has conditional retirement obligations for asbestos and PCB removal at certain of its power plants and various distribution equipment. DTE Gas has conditional retirement obligations for gas pipelines, certain service centers, and compressor and gate stations. The Registrants recognize such obligations as liabilities at fair market value when they are incurred, which generally is at the time the associated assets are placed in service. Fair value is measured using expected future cash outflows discounted at the Registrants' credit-adjusted risk-free rate. For its utility operations, the Registrants recognize in the Consolidated Statements of Operations removal costs in accordance with regulatory treatment. Any differences between costs recognized related to asset retirement and those reflected in rates are recognized as either a Regulatory asset or liability on the Consolidated Statements of Financial Position.
If a reasonable estimate of fair value cannot be made in the period in which the retirement obligation is incurred, such as for assets with indeterminate lives, the liability is recognized when a reasonable estimate of fair value can be made. Natural gas storage system and certain other distribution assets for DTE Gas and substations, manholes, and certain other distribution assets for DTE Electric have an indeterminate life. Therefore, no liability has been recorded for these assets.
Changes to Asset retirement obligations for the years ended December 31, 2025, 2024, and 2023 were as follows:
202520242023
DTE Energy(In millions)
Asset retirement obligations at January 1$4,031 $3,556 $3,460 
Accretion239 211 198 
Liabilities incurred32 324 7 
Liabilities settled(10)(14)(96)
Revision in estimated cash flows(a)
177 (46)(13)
Asset retirement obligations at December 31$4,469 $4,031 $3,556 
_______________________________________
(a)Revision in estimated cash flows was primarily due to the impact of the CCR regulations on DTE Electric's coal ash storage facility asset retirement obligations, as well as revision of estimated cash flows related to DTE Electric's Fermi 1 obligations. Refer to Note 18 to the Consolidated Financial Statements, "Commitments and Contingencies," for additional information regarding the CCR regulations.
202520242023
DTE Electric(In millions)
Asset retirement obligations at January 1$3,791 $3,326 $3,221 
Accretion226 199 185 
Liabilities incurred32 323 4 
Liabilities settled(9)(11)(81)
Revision in estimated cash flows(a)
177 (46)(3)
Asset retirement obligations at December 31$4,217 $3,791 $3,326 
_______________________________________
(a)Revision in estimated cash flows was primarily due to the impact of the CCR regulations on DTE Electric's coal ash storage facility asset retirement obligations, as well as revision of estimated cash flows related to DTE Electric's Fermi 1 obligations. Refer to Note 18 to the Consolidated Financial Statements, "Commitments and Contingencies," for additional information regarding the CCR regulations.
Approximately $3.1 billion of the Asset retirement obligations represent nuclear decommissioning liabilities that are funded through a surcharge to electric customers over the life of the Fermi 2 nuclear plant. The NRC has jurisdiction over the decommissioning of nuclear power plants and requires minimum decommissioning funding based upon a formula. The MPSC and FERC regulate the recovery of costs of decommissioning nuclear power plants and both require the use of external trust funds to finance the decommissioning of Fermi 2. Rates approved by the MPSC provide for the recovery of decommissioning costs of Fermi 2 and the disposal of low-level radioactive waste. DTE Electric believes the MPSC collections will be adequate to fund the estimated cost of decommissioning. The decommissioning assets, anticipated earnings thereon, and future revenues from decommissioning collections will be used to decommission Fermi 2. DTE Electric expects the liabilities to be reduced to zero at the conclusion of the decommissioning activities. If amounts remain in the trust funds for Fermi 2 following the completion of the decommissioning activities, those amounts will be disbursed based on rulings by the MPSC and FERC.
A portion of the funds recovered through the Fermi 2 decommissioning surcharge and deposited in external trust accounts is designated for the removal of non-radioactive assets and returning the site to greenfield. This removal and greenfielding is not considered a legal liability. Therefore, it is not included in the asset retirement obligation, but is reflected as the Nuclear decommissioning liability. The decommissioning of Fermi 1 is funded by DTE Electric. Contributions to the Fermi 1 trust are discretionary. For additional discussion of Nuclear decommissioning trust fund assets, see Note 12 to the Consolidated Financial Statements, "Fair Value."
In the third quarter of 2025, DTE Electric initiated preparatory steps to facilitate the license termination of the Fermi 1 facility, as required by the NRC. The NRC mandates license termination by 2032. Following management's reassessment of project timing and estimated cash flows, the Registrants recorded an additional $47 million accrual related to the decommissioning of Fermi 1. The expense is reflected in Asset (gains) losses and impairments, net in the Registrants' Consolidated Statements of Operations. Key risks to successful project completion remain, primarily due to uncertainties around contamination levels in piping and volume of waste material. The estimate may be revised as more site-specific information becomes available.
v3.25.4
Regulatory Matters
 12 Months Ended
Dec. 31, 2025
Regulatory Assets and Liabilities Disclosure [Abstract]  
Regulatory Matters REGULATORY MATTERS
Regulation
DTE Electric and DTE Gas are subject to the regulatory jurisdiction of the MPSC, which issues orders pertaining to rates, recovery of certain costs, including the costs of generating facilities and regulatory assets, conditions of service, accounting, and operating-related matters. The MPSC has authorized a return on equity of 9.9% for DTE Electric and 9.8% for DTE Gas, subject to changes from any pending or future rate case filings. DTE Electric is also regulated by the FERC with respect to financing authorization, wholesale electric market activities, certain affiliate transactions, the acquisition and disposition of certain generation and other facilities, and, in conjunction with the NERC, compliance with mandatory reliability standards. Regulation results in differences in the application of generally accepted accounting principles between regulated and non-regulated businesses.
The Registrants are unable to predict the outcome of any unresolved regulatory matters discussed herein. Resolution of these matters is dependent upon future MPSC and FERC orders and appeals, which may materially impact the Consolidated Financial Statements of the Registrants.
Regulatory Assets and Liabilities
DTE Electric and DTE Gas are required to record Regulatory assets and liabilities for certain transactions that would have been treated as revenue or expense in non-regulated businesses. Continued applicability of regulatory accounting treatment requires that rates be designed to recover specific costs of providing regulated services and be charged to and collected from customers. Future regulatory changes could result in the discontinuance of this accounting treatment for Regulatory assets and liabilities for some or all of the Registrants' businesses and may require the write-off of the portion of any Regulatory asset or liability that was no longer probable of recovery through regulated rates. Management believes that currently available facts support the continued use of Regulatory assets and liabilities and that all Regulatory assets and liabilities are recoverable or refundable in the current regulatory environment.
The following are balances and a brief description of the Registrants' Regulatory assets and liabilities at December 31:
DTE EnergyDTE Electric
2025202420252024
Assets(In millions)
Recoverable undepreciated costs on retiring plants$3,146 $2,986 $3,146 $2,986 
Recoverable pension and other postretirement costs
Pension1,281 1,315 949 971 
Other postretirement costs90 91 — — 
Fermi 2 asset retirement obligation895 951 895 951 
Removal costs asset700 501 700 501 
Enhanced tree trimming program deferred costs340 211 340 211 
Renewable ITC offset207 89 207 89 
Recoverable income taxes related to AFUDC equity148 116 139 107 
Energy Waste Reduction incentive115 102 94 82 
Accrued PSCR/GCR revenue112 — 111 — 
Recoverable Michigan income taxes107 119 89 99 
Ludington contract dispute costs58 31 58 31 
Energy Waste Reduction57 36 52 29 
Deferred environmental costs39 43 — — 
Unamortized loss on reacquired debt33 38 26 29 
Customer360 deferred costs29 34 29 34 
Other193 158 144 106 
7,550 6,821 6,979 6,226 
Less amount included in Current Assets(170)(50)(158)(39)
$7,380 $6,771 $6,821 $6,187 
Securitized regulatory assets$619 $690 $619 $690 
DTE EnergyDTE Electric
2025202420252024
Liabilities(In millions)
Refundable federal income taxes$1,646 $1,733 $1,318 $1,389 
Removal costs liability511 506 — — 
Non-service pension and other postretirement costs271 255 103 94 
Negative other postretirement offset205 214 133 139 
Renewable energy196 90 196 90 
Accrued PSCR/GCR refund43 136 — 111 
Other116 103 111 86 
2,988 3,037 1,861 1,909 
Less amount included in Current Liabilities(107)(181)(63)(156)
$2,881 $2,856 $1,798 $1,753 
As noted below, certain Regulatory assets for which costs have been incurred have been included (or are expected to be included, for costs incurred subsequent to the most recently approved rate case) in DTE Electric's or DTE Gas' rate base, thereby providing a return on invested costs (except as noted). Certain other Regulatory assets are not included in rate base but accrue recoverable carrying charges until surcharges to collect the assets are billed. Certain Regulatory assets do not result from cash expenditures and therefore do not represent investments included in rate base or have offsetting liabilities that reduce rate base.
ASSETS
•Recoverable undepreciated costs on retiring plants — Undepreciated costs at the Belle River and Monroe power plants that will be retired in future periods. These costs were approved for recovery as a result of DTE Electric's Integrated Resource Plan settlement agreement in 2023. One unit of the Belle River power plant was retired in 2025, with the remaining unit expected to be retired in 2026. The Monroe power plant will be retired in 2028 and 2032. As prescribed by the Integrated Resource Plan, DTE Electric will recover $1.05 billion of these plant costs through future securitizations. The remaining amount is being recovered through a regulatory asset with a return on equity of 9.0% and is being amortized over a 15-year period beginning in February 2025.
•Recoverable pension and other postretirement costs — Accounting standards for pension and other postretirement benefit costs require, among other things, the recognition in Other comprehensive income of the actuarial gains or losses and the prior service costs that arise during the period but are not immediately recognized as components of net periodic benefit costs (credits). DTE Electric and DTE Gas record the impact of actuarial gains or losses and prior service costs as Regulatory assets or Regulatory liabilities since the traditional rate setting process allows for the recovery of pension and other postretirement costs. The asset and liability will reverse as the deferred items are amortized and recognized as components of net periodic benefit costs (credits). Refer to Note 20 to the Consolidated Financial Statements, "Retirement Benefits and Trusteed Assets," for additional information regarding the changes in pension and other postretirement costs for the period and the impact on Regulatory assets.(a)
•Fermi 2 asset retirement obligation — Obligation for Fermi 2 decommissioning costs. The asset captures the timing differences between expense recognition and current recovery in rates and will reverse over the remaining life of the related plant.(a)
•Removal costs asset — Receivable for the recovery of asset removal expenditures in excess of amounts collected from customers for DTE Electric.
•Enhanced tree trimming program deferred costs — The MPSC approved the deferral of costs for a tree trimming surge through 2025, aimed at reducing the number and duration of customer interruptions.
•Renewable ITC offset — DTE Electric's accounting policy for ITCs is to use the deferral method where the ITC benefit is deferred and amortized to net income over the book life of the related property. For an ITC that is sold, this regulatory asset is used to adjust net income to reflect the benefit over a period shorter than the book life, as approved by the MPSC.(a)
•Recoverable income taxes related to AFUDC equity — Accounting standards for income taxes require recognition of a deferred tax liability for the equity component of AFUDC.  A Regulatory asset is required for the future increase in taxes payable related to the equity component of AFUDC that will be recovered from customers through future rates over the remaining life of the related plant.
•Energy Waste Reduction incentive — DTE Electric and DTE Gas operate MPSC approved energy waste reduction programs designed to reduce overall energy usage by their customers. The utilities are eligible to earn an incentive by exceeding statutory savings targets. The utilities have consistently exceeded the savings targets and recognize the incentive as a Regulatory asset in the period earned.(a)
•Accrued PSCR/GCR revenue — Receivable for the temporary under-recovery of and carrying costs on fuel and purchased power costs incurred by DTE Electric which are recoverable through the PSCR mechanism and temporary under-recovery of and carrying costs on gas costs incurred by DTE Gas which are recoverable through the GCR mechanism.
•Recoverable Michigan income taxes — The State of Michigan enacted a corporate income tax resulting in the establishment of state deferred tax liabilities for DTE Energy's utilities.  Offsetting Regulatory assets were also recorded as the impacts of the deferred tax liabilities will be reflected in rates as the related taxable temporary differences reverse and flow through current income tax expense.
•Ludington contract dispute costs — The MPSC approved the deferral of costs incurred for repairing or replacing defective work performed by a third party related to the overhaul and upgrade of the Ludington Hydroelectric Pumped Storage Plant while the dispute is in litigation. These costs will be offset by any potential future proceeds received related to the litigation. Upon resolution of the dispute, DTE Electric will have the opportunity to seek recovery through the regulatory process for any remaining costs. Refer to the Ludington Plant Contract Dispute section of Note 18 to the Consolidated Financial Statements, “Commitments and Contingencies,” for additional information regarding the complaint and ongoing legal proceedings.
•Energy Waste Reduction — Receivable for under-recovery of energy waste reduction costs incurred by DTE Electric and DTE Gas which are recoverable through a surcharge.(a)
•Deferred environmental costs — The MPSC approved the deferral of investigation and remediation costs associated with DTE Gas' former MGP sites. Amortization of deferred costs is over a ten-year period beginning in the year after costs were incurred, with recovery (net of any insurance proceeds) through base rate filings.(a)
•Unamortized loss on reacquired debt — The unamortized discount, premium, and expense related to debt redeemed with a refinancing are deferred, amortized, and recovered over the life of the replacement issue.
•Customer360 deferred costs — The MPSC approved the deferral and amortization of certain costs associated with implementing Customer360, an integrated software application that enables improved interface among customer service, billing, meter reading, credit and collections, device management, account management, and retail access. Amortization of deferred costs over a 15-year amortization period began after the billing system was put into operation during the second quarter of 2017. The deferred costs are recorded as Regulatory Assets at DTE Electric and DTE Gas receives an intercompany charge for their proportionate share of amortization expense.
•Securitized regulatory assets — Costs approved for securitization and recovery by the MPSC. Amounts include the undepreciated cost of the River Rouge power plant and tree trim surge costs. Securitization bond surcharges began in 2022 to recover the tree trimming costs over a period not to exceed 5 years and River Rouge costs over a period not to exceed 14 years. Amounts also include the undepreciated costs of the St. Clair and Trenton Channel power plants. Securitization bond surcharges began in 2023 to recover costs over a period not to exceed 15 years.
________________________________________________
(a)Regulatory assets not earning a return or accruing carrying charges.
LIABILITIES
•Refundable federal income taxes — In December 2017, the TCJA was enacted and reduced the corporate income tax rate, effective January 1, 2018. DTE Electric and DTE Gas remeasured deferred taxes, resulting in a reduction to deferred tax liabilities, to reflect the impact of the TCJA on the cumulative temporary differences expected to reverse after the effective date. Regulatory liabilities were also recorded to offset the impact of the deferred tax remeasurement reflected in rates.
•Removal costs liability — The amounts collected from customers to fund future asset removal activities in excess of removal costs incurred for DTE Gas.
•Non-service pension and other postretirement costs — Upon adoption of ASU 2017-07 on January 1, 2018, certain non-service pension and other postretirement cost activity is no longer credited to Property, plant, and equipment. Such costs may be recorded to Regulatory liabilities for ratemaking purposes and refunded through credits to amortization expense based on the composite depreciation rate for plant-in-service.
•Negative other postretirement offset — DTE Electric and DTE Gas' negative other postretirement costs have historically not been included as a reduction to their authorized rates; therefore, DTE Electric and DTE Gas have accrued a Regulatory liability to eliminate the impact on earnings of the negative other postretirement expense accrual. The Regulatory liabilities may reverse to the extent DTE Electric and DTE Gas' other postretirement expense is positive in future years. As a result of MPSC orders, the Regulatory liability balances as of December 31, 2022 began to be amortized over a 7-year period for both DTE Electric and DTE Gas.
•Renewable energy — Amounts collected in excess of renewable energy expenditures, including subscription revenue related to MIGreenPower, DTE Electric's voluntary renewable program providing customers the option to source their energy usage from renewables.
•Accrued PSCR/GCR refund — Liability for the temporary over-recovery of and a return on power supply costs and transmission costs incurred by DTE Electric which are recoverable through the PSCR mechanism and temporary over-recovery of and a return on gas costs primarily incurred by DTE Gas which are recoverable through the GCR mechanism.
2022 Electric PSCR Reconciliation
In March 2023, DTE Electric filed its 2022 PSCR Reconciliation that included the under-recovery of approximately $421 million of power supply costs incurred under reasonable and prudent policies and practices. The request was subsequently reduced to $416 million. On February 27, 2025, the MPSC issued an order approving recovery of $387 million of these costs resulting in a disallowance of approximately $33 million, inclusive of interest. The disallowance was included in Operating Revenues – Utility operations and Interest expense on the Consolidated Statements of Operation in the first quarter of 2025.
2025 Electric Rate Case Filing
DTE Electric filed a rate case with the MPSC on April 24, 2025 requesting an increase in base rates of $574 million based on a projected twelve-month period ending December 31, 2026, and an increase in return on equity from 9.9% to 10.75%. The requested increase in base rates was primarily due to capital investments required to support continued reliability improvements and the ongoing transition to cleaner energy. A final MPSC order in this case is expected in February 2026.
2025 Electric Depreciation Case Filing
DTE Electric filed a depreciation case with the MPSC on December 23, 2025 requesting an increase in depreciation rates of $147 million when compared to current depreciation rates for plant in service balances as of December 31, 2023. While there is no required timing for an MPSC order in a depreciation case, updated depreciation rates will be implemented coinciding with an order in the first DTE Electric general rate case filed following an order in this case.
2025 Gas Rate Case Filing
DTE Gas filed a rate case with the MPSC on November 13, 2025 requesting a net increase in base rates of $163 million based on a projected twelve-month period ending September 30, 2027, and an increase in return on equity from 9.8% to 10.25%. The net increase is based on a total revenue deficiency of $238 million, net of the IRM roll-in of $75 million. The requested net increase in base rates was primarily due to continued infrastructure investment and increasing operations and maintenance costs needed to ensure the continued safe and reliable delivery of natural gas to customers. A final MPSC order in this case is expected in September 2026.
v3.25.4
Income Taxes
 12 Months Ended
Dec. 31, 2025
Income Tax Disclosure [Abstract]  
Income Taxes INCOME TAXES
Income Tax Summary
DTE Energy files a consolidated federal income tax return. DTE Electric is a part of the consolidated federal income tax return of DTE Energy. DTE Energy and its subsidiaries file consolidated and/or separate company income tax returns in various states and localities, including a consolidated return in the State of Michigan. DTE Electric is part of the Michigan consolidated income tax return of DTE Energy. The federal, state and local income tax expense for DTE Electric is determined on an individual company basis with no allocation of tax expenses or benefits from other affiliates of DTE Energy. DTE Electric had federal income tax receivables with DTE Energy of $1 million and $5 million at December 31, 2025 and 2024, respectively. Income tax receivables with DTE Energy are included in Accounts receivable – Affiliates on the DTE Electric Consolidated Statements of Financial Position.
The Registrants' total Income Tax Expense varied from the statutory federal income tax rate for the following reasons:
Year Ended December 31,
202520242023
(In millions)
DTE EnergyAmountPercentageAmountPercentageAmountPercentage
Income tax expense at U.S. Federal Statutory Tax Rate$326 21.0 %$288 21.0 %$329 21.0 %
Tax Credits
Production tax credits(161)(10.4)%(174)(12.7)%(91)(5.8)%
Investment tax credits(94)(6.1)%(128)(9.3)%(44)(2.8)%
Other(5)(0.3)%(4)(0.3)%(5)(0.3)%
Other Adjustments
TCJA regulatory liability amortization(65)(4.2)%(66)(4.8)%(63)(4.0)%
Other(4)(0.1)%4 0.2 %— — %
Nontaxable or Nondeductible Items
AFUDC equity(20)(1.3)%(17)(1.2)%(7)(0.5)%
Other6 0.5 %(3)(0.3)%(4)(0.2)%
Changes in Tax Laws or Rates Enacted in the Current Period16 1.0 %— — %— — %
Changes in Valuation Allowances 7 0.4 %6 0.5 %— — %
Changes in Prior Year Unrecognized Tax Benefits— — %— — %(12)(0.8)%
Foreign Tax Effects
Canada1 — %1 0.1 %— — %
State and Local Income Taxes, Net of Federal Effect (a)
$81 5.2 %$59 4.3 %$66 4.2 %
Income Tax Expense (Benefit) at Effective Tax Rate$88 5.7 %$(34)(2.5)%$169 10.8 %
_______________________________________
(a)State taxes in Michigan made up the majority (greater than 50 percent) of the tax effect in this category for all years presented. State and local income taxes in 2025 includes $14 million expense due to an Illinois tax law change.
Year Ended December 31,
202520242023
(In millions)
DTE ElectricAmountPercentageAmountPercentageAmountPercentage
Income tax expense at U.S. Federal Statutory Tax Rate$257 21.0 %$218 21.0 %$179 21.0 %
Tax Credits
Investment tax credits(95)(7.7)%(70)(6.7)%(1)(0.1)%
Production tax credits(77)(6.3)%(167)(16.0)%(79)(9.3)%
Other(4)(0.4)%(4)(0.4)%(4)(0.5)%
Other Adjustments
TCJA regulatory liability amortization(53)(4.4)%(55)(5.3)%(53)(6.2)%
Other(1)(0.1)%2 0.2 %— — %
Nontaxable or Nondeductible Items
AFUDC equity(20)(1.6)%(16)(1.6)%(7)(0.8)%
Other(2)(0.1)%(2)(0.2)%(2)(0.2)%
Changes in Prior Year Unrecognized Tax Benefits— — %— — %(7)(0.8)%
Changes in Valuation Allowances — — %5 0.4 %— — %
State and Local Income Taxes, Net of Federal Effect (a)
$66 5.4 %$57 5.5 %$52 6.1 %
Income Tax Expense (Benefit) at Effective Tax Rate$71 5.8 %$(32)(3.1)%$78 9.2 %
_______________________________________
(a)State taxes in Michigan made up the majority (greater than 50 percent) of the tax effect in this category for all years presented.
Components of the Registrants' Income Taxes Paid were as follows:
Year Ended December 31,
202520242023
DTE Energy(In millions)
U.S. Federal(a)
$(266)$(230)$2 
U.S. State and Local
Michigan(5)(5)(10)
Pennsylvania1 2 2 
Other1 — 1 
(3)(3)(7)
Foreign2 3 — 
Total$(267)$(230)$(5)
_______________________________________
(a)Includes proceeds on sale of transferrable income tax credits, net of discount, in 2025 and 2024.
Year Ended December 31,
202520242023
DTE Electric(In millions)
U.S. Federal(a)
$(273)$(231)$9 
U.S. State and Local
Michigan$— $— $6 
Total$(273)$(231)$15 
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(a)Includes proceeds on sale of transferrable income tax credits, net of discount, in 2025 and 2024.
Components of the Registrants' Income Tax Expense were as follows:
Year Ended December 31,
202520242023
DTE Energy(In millions)
Income (loss) from continuing operations before income tax expense (benefit)
US$1,543 $1,357 $1,559 
Foreign7 13 7 
Total$1,550 $1,370 $1,566 
Income tax expense (benefit) from continuing operations
Current tax expense (benefit)
US federal$(269)$(229)$(10)
US state and local(3)(2)(2)
Foreign2 3 — 
Total current tax expense (benefit)$(270)$(228)$(12)
Deferred tax expense (benefit)
US federal$253 $116 $103 
US state and local105 77 76 
Foreign— 1 2 
Total deferred tax expense (benefit)$358 $194 $181 
Total tax expense (benefit)
US federal$(16)$(113)$93 
US state and local102 75 74 
Foreign2 4 2 
Total tax expense (benefit)$88 $(34)$169 
Year Ended December 31,
202520242023
DTE Electric(In millions)
Income (loss) from continuing operations before income tax expense (benefit)
US$1,223 $1,040 $850 
Total$1,223 $1,040 $850 
Income tax expense (benefit) from continuing operations
Current tax expense (benefit)
US federal$(268)$(228)$1 
US state and local— — (5)
Total current tax expense (benefit)$(268)$(228)$(4)
Deferred tax expense (benefit)
US federal$256 $124 $19 
US state and local83 72 63 
Total deferred tax expense (benefit)$339 $196 $82 
Total tax expense (benefit)
US federal$(12)$(104)$20 
US state and local83 72 58 
Total tax expense (benefit)$71 $(32)$78 
Deferred tax assets and liabilities are recognized for the estimated future tax effect of temporary differences between the tax basis of assets or liabilities and the reported amounts in the Registrants' Consolidated Financial Statements.
The Registrants' deferred tax assets (liabilities) were comprised of the following at December 31:
DTE EnergyDTE Electric
2025202420252024
(In millions)
Property, plant, and equipment$(3,952)$(3,695)$(2,947)$(2,788)
Regulatory assets and liabilities(1,412)(1,272)(1,636)(1,492)
Tax credit carryforwards1,619 1,604 512 583 
Pension and benefits3 55 2 62 
Federal net operating loss carryforward180 190 24 30 
State and local net operating loss carryforwards51 68 27 42 
Investments in equity method investees(25)(28)(1)(1)
Other182 145 207 176 
(3,354)(2,933)(3,812)(3,388)
Less: Valuation allowance(46)(25)— (5)
Long-term deferred income tax liabilities$(3,400)$(2,958)$(3,812)$(3,393)
Deferred income tax assets$2,575 $2,508 $1,188 $1,209 
Deferred income tax liabilities(5,975)(5,466)(5,000)(4,602)
$(3,400)$(2,958)$(3,812)$(3,393)
Tax credit carryforwards for DTE Energy include $1.6 billion of general business credits that expire from 2034 through 2047. No valuation allowance is required for the tax credit carryforwards deferred tax asset.
DTE Energy has a pre-tax federal net operating loss carryforward of $856 million as of December 31, 2025 which can be carried forward indefinitely. No valuation allowance is required for the federal net operating loss deferred tax asset.
DTE Energy has state and local deferred tax assets related to net operating loss carryforwards of $51 million and $68 million at December 31, 2025 and 2024, respectively. Most of the state and local net operating loss carryforwards expire from 2026 through 2045 with the remainder being carried forward indefinitely.
DTE Energy has recorded valuation allowances of $46 million and $25 million at December 31, 2025 and 2024, respectively. The valuation allowances include $15 million and $16 million related to the state net operating loss carryforwards noted above and $30 million and $3 million related to charitable contribution carryforwards as of the respective periods ended.
Tax credit carryforwards for DTE Electric include $512 million of general business credits that expire from 2036 through 2047. No valuation allowance is required for the tax credit carryforwards deferred tax asset.
DTE Electric has a pre-tax federal net operating loss carryforward of $112 million as of December 31, 2025 which can be carried forward indefinitely. No valuation allowance is required for the federal net operating loss deferred tax asset.
DTE Electric has $27 million and $42 million in state and local deferred tax assets related to net operating loss carryforwards at December 31, 2025 and 2024, respectively, which will expire from 2030 through 2045. No valuation allowance is required for the state and local net operating loss deferred tax assets.
In assessing the realizability of deferred tax assets, DTE Energy considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible.
The above tables exclude unamortized ITCs that are shown separately on the Registrants' Consolidated Statements of Financial Position. DTE Energy's policy election is to follow the flow-through method of accounting for ITCs earned from its non-utility businesses and the deferral method of accounting for its regulated utilities due to different economic profiles of the various entities. The flow-through method used by the non-utility businesses recognizes ITCs in earnings when the related assets are placed in service. The ITCs generated by the regulated utilities are deferred and amortized to earnings over the average life of the related property. ITCs generated and sold by the regulated utilities are offset with a regulatory asset to give the benefit to customers over a period shorter than the book life, as approved by the MPSC. Refer to Note 9 to the Consolidated Financial Statements, "Regulatory Matters" for the regulatory asset balance at December 31, 2025.
The benefit from wind PTCs and solar ITCs generated by DTE Electric are provided to customers through the regulatory construct of the renewable energy program and nuclear PTCs generated by DTE Electric are provided to customers through the regulatory construct of the PSCR mechanism.
Beginning in 2024, DTE Electric sold certain PTCs and ITCs detailed below. Tax credit sales are subject to standard indemnifications up to the cash received. Payments under these indemnifications are considered remote. The following table details the Registrants' tax credit sales, net of discount, by year of sale:
Year Ended December 31,
202520242023
(In millions)
Cash received for tax credit sales$268 $231 $— 
On July 4, 2025, the One Big Beautiful Bill Act (OBBB) was enacted into law. As a result of the OBBB, DTE Energy recorded a valuation allowance of $16 million related to their charitable contribution carryforward in the third quarter.
Uncertain Tax Positions
There were no unrecognized tax benefits at the Registrants for the years ended December 31, 2025 or 2024.
The Registrants recognize interest and penalties pertaining to income taxes in Interest expense and Other expenses, respectively, on the Consolidated Statements of Operations. DTE Energy did not recognize any interest expense related to income taxes in 2025 and 2024 and recognized a nominal amount of interest expense related to income taxes in 2023. DTE Electric did not recognize any interest expense related to income taxes in 2025 and 2024 and recognized a nominal amount of interest expense in 2023. There was no accrued interest or penalties pertaining to income taxes for the Registrants at December 31, 2025, 2024, and 2023.
In 2025, DTE Energy, including DTE Electric, settled a federal tax audit for the 2023 tax year. DTE Energy's federal income tax returns for 2024 and subsequent years remain subject to examination by the IRS. DTE Energy's Michigan Corporate Income Tax returns for the year 2021 and subsequent years remain subject to examination by the State of Michigan. DTE Energy also files tax returns in numerous state and local jurisdictions with varying statutes of limitation.
v3.25.4
Earnings Per Share
 12 Months Ended
Dec. 31, 2025
Earnings Per Share [Abstract]  
Earnings Per Share EARNINGS PER SHARE
Basic earnings per share is calculated by dividing net income, adjusted for income allocated to participating securities, by the weighted average number of common shares outstanding during the period. Diluted earnings per share reflect the dilution that would occur if any potentially dilutive instruments were exercised or converted into common shares. DTE Energy's participating securities are restricted shares under the stock incentive program that contain rights to receive non-forfeitable dividends. Performance shares do not receive cash dividends; as such, these awards are not considered participating securities. For additional information regarding performance shares, see Note 21 to the Consolidated Financial Statements, "Stock-Based Compensation."
The following is a reconciliation of DTE Energy's basic and diluted income per share calculation for the years ended December 31:
202520242023
(In millions, except per share amounts)
Basic Earnings per Share
Net Income Attributable to DTE Energy Company1,462 $1,404 $1,397 
Less: Allocation of earnings to net restricted stock awards3 3 3 
Net income available to common shareholders — basic$1,459 $1,401 $1,394 
Average number of common shares outstanding — basic207 207 206 
Basic Earnings per Common Share$7.04 $6.78 $6.77 
Diluted Earnings per Share
Net Income Attributable to DTE Energy Company$1,462 $1,404 $1,397 
Less: Allocation of earnings to net restricted stock awards3 3 3 
Net income available to common shareholders — diluted$1,459 $1,401 $1,394 
Average number of common shares outstanding — diluted207 207 206 
Diluted Earnings per Common Share
$7.03 $6.77 $6.76 
v3.25.4
Fair Value
 12 Months Ended
Dec. 31, 2025
Fair Value Disclosures [Abstract]  
Fair Value FAIR VALUE
Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable inputs. The Registrants make certain assumptions they believe that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. Credit risk of the Registrants and their counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at December 31, 2025 and 2024. The Registrants believe they use valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.
A fair value hierarchy has been established that prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. All assets and liabilities are required to be classified in their entirety based on the lowest level of input that is significant to the fair value measurement in its entirety. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. The Registrants classify fair value balances based on the fair value hierarchy defined as follows:
•Level 1 — Consists of unadjusted quoted prices in active markets for identical assets or liabilities that the Registrants have the ability to access as of the reporting date.
•Level 2 — Consists of inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.
•Level 3 — Consists of unobservable inputs for assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost-benefit constraints.
The following table presents assets and liabilities for DTE Energy measured and recorded at fair value on a recurring basis:
December 31, 2025December 31, 2024
Level 1Level
 2		Level 3
Other
(a)
Netting
(b)
Net BalanceLevel 1Level
 2		Level 3
Other
(a)
Netting
(b)
Net Balance
(In millions)
Assets
Cash equivalents and Restricted cash(c)
$176 $— $— $— $— $176 $11 $— $— $— $— $11 
Nuclear decommissioning trusts
Equity securities987 — — 201 — 1,188 856 — — 147 — 1,003 
Fixed income securities133 460 — 133 — 726 124 414 — 112 — 650 
Private equity and other— — — 358 — 358 16 — — 333 — 349 
Hedge funds and similar investments228 17 — — — 245 151 16 — 61 — 228 
Cash equivalents35 — — — — 35 26 — — — — 26 
Other investments(d)
Equity securities84 — — — — 84 72 — — — — 72 
Fixed income securities9 2 — — — 11 7 — — — — 7 
Cash equivalents38 — — — — 38 29 — — — — 29 
Derivative assets
Commodity contracts(e)
Natural gas207 56 109 — (235)137 242 81 105 — (285)143 
Electricity127 115 33 — (194)81 67 69 51 — (116)71 
Environmental & Other— 46 11 — (46)11 1 47 10 — (46)12 
Other contracts— 3 — — — 3 — 21 — — — 21 
Total derivative assets334 220 153 — (475)232 310 218 166 — (447)247 
Total$2,024 $699 $153 $692 $(475)$3,093 $1,602 $648 $166 $653 $(447)$2,622 
Liabilities
Derivative liabilities
Commodity contracts(e)
Natural gas$(196)$(51)$(82)$— $227 $(102)$(217)$(70)$(123)$— $272 $(138)
Electricity(124)(59)(52)— 186 (49)(71)(52)(27)— 114 (36)
Environmental & Other(1)(31)— — 32 — (2)(39)(3)— 44 — 
Other contracts— (1)— — — (1)— (1)— — — (1)
Total$(321)$(142)$(134)$— $445 $(152)$(290)$(162)$(153)$— $430 $(175)
Net Assets (Liabilities) at end of period$1,703 $557 $19 $692 $(30)$2,941 $1,312 $486 $13 $653 $(17)$2,447 
Assets
Current$426 $130 $102 $— $(339)$319 $223 $170 $106 $— $(326)$173 
Noncurrent1,598 569 51 692 (136)2,774 1,379 478 60 653 (121)2,449 
Total Assets$2,024 $699 $153 $692 $(475)$3,093 $1,602 $648 $166 $653 $(447)$2,622 
Liabilities
Current$(240)$(106)$(67)$— $327 $(86)$(219)$(129)$(93)$— $323 $(118)
Noncurrent(81)(36)(67)— 118 (66)(71)(33)(60)— 107 (57)
Total Liabilities$(321)$(142)$(134)$— $445 $(152)$(290)$(162)$(153)$— $430 $(175)
Net Assets (Liabilities) at end of period$1,703 $557 $19 $692 $(30)$2,941 $1,312 $486 $13 $653 $(17)$2,447 
_______________________________________
(a)Amounts represent assets valued at NAV as a practical expedient for fair value.
(b)Amounts represent the impact of master netting agreements that allow DTE Energy to net gain and loss positions and cash collateral held or placed with the same counterparties.
(c)Amounts include $10 million and $8 million recorded in Restricted cash on DTE Energy's Consolidated Statements of Financial Position at December 31, 2025 and December 31, 2024, respectively. All other amounts are included in Cash and cash equivalents on DTE Energy's Consolidated Statements of Financial Position.
(d)Excludes cash surrender value of life insurance investments and certain securities classified as held-to-maturity that are recorded at amortized cost and not material to the consolidated financial statements.
(e)For contracts with a clearing agent, DTE Energy nets all activity across commodities. This can result in some individual commodities having a contra balance.
The following table presents assets for DTE Electric measured and recorded at fair value on a recurring basis as of:
December 31, 2025December 31, 2024
Level 1Level 2Level 3
Other(a)
Net Balance Level 1Level 2Level 3
Other(a)
Net Balance
(In millions)
Assets
Cash equivalents and Restricted cash(b)
$83 $— $— $— $83 $8 $— $— $— $8 
Nuclear decommissioning trusts
Equity securities987 — — 201 1,188 856 — — 147 1,003 
Fixed income securities133 460 — 133 726 124 414 — 112 650 
Private equity and other— — — 358 358 16 — — 333 349 
Hedge funds and similar investments228 17 — — 245 151 16 — 61 228 
Cash equivalents35 — — — 35 26 — — — 26 
Other investments
Equity securities33 — — — 33 26 — — — 26 
Fixed income securities— 2 — — 2 — — — — — 
Cash equivalents26 — — — 26 19 — — — 19 
Derivative assets — FTRs— — 11 — 11 — — 9 — 9 
Total$1,525 $479 $11 $692 $2,707 $1,226 $430 $9 $653 $2,318 
Assets
Current$83 $— $11 $— $94 $8 $— $9 $— $17 
Noncurrent1,442 479 — 692 2,613 1,218 430 — 653 2,301 
Total Assets$1,525 $479 $11 $692 $2,707 $1,226 $430 $9 $653 $2,318 
_______________________________________
(a)Amounts represent assets valued at NAV as a practical expedient for fair value.
(b)Amounts include $10 million and $8 million recorded in Restricted cash on DTE Electric's Consolidated Statements of Financial Position at December 31, 2025 and December 31, 2024, respectively. All other amounts are included in Cash and cash equivalents on DTE Electric's Consolidated Statements of Financial Position.
Cash Equivalents
Cash equivalents include investments with maturities of three months or less when purchased. The cash equivalents shown in the fair value table are comprised of short-term investments in money market funds.
Nuclear Decommissioning Trusts and Other Investments
The nuclear decommissioning trusts and other investments hold debt and equity securities directly and indirectly through commingled funds. Exchange-traded debt and equity securities held directly, as well as publicly traded commingled funds, are valued using quoted market prices in actively traded markets. Non-exchange traded fixed income securities are valued based upon quotations available from brokers or pricing services.
Non-publicly traded commingled funds holding exchange-traded equity or debt securities are valued based on stated NAVs. There are no significant restrictions for these funds and investments may be redeemed with 7 to 65 days notice depending on the fund. There is no intention to sell the investment in these commingled funds.
Private equity and other assets include a diversified group of funds that are primarily classified as NAV assets. These funds primarily invest in limited partnerships, including private equity, private real estate and private credit. Distributions are received through the liquidation of the underlying fund assets over the life of the funds. There are generally no redemption rights. The limited partner must hold the fund for its life or find a third-party buyer, which may need to be approved by the general partner. The funds are established with varied contractual durations generally in the range of 7 years to 12 years. The fund life can often be extended by several years by the general partner, and further extended with the approval of the limited partners. Unfunded commitments related to these investments totaled $179 million and $120 million as of December 31, 2025 and 2024, respectively.
Hedge funds and similar investments utilize a diversified group of strategies that attempt to capture uncorrelated sources of return. These investments include publicly traded mutual funds that are valued using quoted prices in actively traded markets, as well as insurance-linked and asset-backed securities and that are valued using quotations from broker or pricing services and limited partnerships that are classified as NAV assets.
For pricing the nuclear decommissioning trusts and other investments, a primary price source is identified by asset type, class, or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary source of a given security if the trustee determines that another price source is considered preferable. The Registrants have obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices.
Derivative Assets and Liabilities
Derivative assets and liabilities are comprised of physical and financial derivative contracts, including futures, forwards, options, and swaps that are both exchange-traded and over-the-counter traded contracts. Various inputs are used to value derivatives depending on the type of contract and availability of market data. Exchange-traded derivative contracts are valued using quoted prices in active markets. The Registrants consider the following criteria in determining whether a market is considered active: frequency in which pricing information is updated, variability in pricing between sources or over time, and the availability of public information. Other derivative contracts are valued based upon a variety of inputs including commodity market prices, broker quotes, interest rates, credit ratings, default rates, market-based seasonality, and basis differential factors. The Registrants monitor the prices that are supplied by brokers and pricing services and may use a supplemental price source or change the primary price source of an index if prices become unavailable or another price source is determined to be more representative of fair value. The Registrants have obtained an understanding of how these prices are derived. Additionally, the Registrants selectively corroborate the fair value of their transactions by comparison of market-based price sources. Mathematical valuation models are used for derivatives for which external market data is not readily observable, such as contracts which extend beyond the actively traded reporting period. The Registrants have established a Risk Management Committee whose responsibilities include directly or indirectly ensuring all valuation methods are applied in accordance with predefined policies. The development and maintenance of the Registrants' forward price curves has been assigned to DTE Energy's Risk Management Department, which is separate and distinct from the trading functions within DTE Energy.
The following table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for DTE Energy:
Year Ended December 31, 2025Year Ended December 31, 2024
Natural GasElectricityOtherTotalNatural GasElectricityOtherTotal
(In millions)
Net Assets (Liabilities) as of January 1$(18)$24 $7 $13 $22 $47 $6 $75 
Transfers into Level 3 from Level 22 — — 2 1 — — 1 
Transfers from Level 3 into Level 2— — 2 2 — 74 — 74 
Total gains (losses)
Included in earnings(a)
(25)329 4 308 16 225 (1)240 
Recorded in Regulatory liabilities— — 19 19 — — 21 21 
Purchases, issuances, and settlements:
Settlements68 (372)(21)(325)(57)(322)(19)(398)
Net Assets (Liabilities) as of December 31$27 $(19)$11 $19 $(18)$24 $7 $13 
Total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31(a)
$23 $(19)$— $4 $(47)$118 $(159)$(88)
Total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31$— $— $11 $11 $— $— $9 $9 
_______________________________________
(a)Amounts are reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, gas, and other — non-utility in DTE Energy's Consolidated Statements of Operations.
The following table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for DTE Electric:
Year Ended December 31,
20252024
(In millions)
Net Assets as of January 1$9 $7 
Total gains recorded in Regulatory liabilities19 21 
Purchases, issuances, and settlements:
Settlements(17)(19)
Net Assets as of December 31$11 $9 
Total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31$11 $9 
Derivatives are transferred between levels primarily due to changes in the source data used to construct price curves as a result of changes in market liquidity. Transfers in and transfers out are reflected as if they had occurred at the beginning of the period. There were no transfers from or into Level 3 for DTE Electric during the years ended December 31, 2025 and 2024.
The following tables present the unobservable inputs related to DTE Energy's Level 3 assets and liabilities:
December 31, 2025
Commodity ContractsDerivative AssetsDerivative LiabilitiesValuation TechniquesUnobservable InputRangeWeighted Average
(In millions)
Natural Gas$109 $(82)Discounted Cash FlowForward basis price (per MMBtu)$(1.35)—$9.33 /MMBtu$(0.13)/MMBtu
Electricity$33 $(52)Discounted Cash FlowForward basis price (per MWh)$(21.82)—$17.79 /MWh$(5.58)/MWh
December 31, 2024
Commodity ContractsDerivative AssetsDerivative LiabilitiesValuation TechniquesUnobservable InputRangeWeighted Average
(In millions)
Natural Gas$105 $(123)Discounted Cash FlowForward basis price (per MMBtu)$(1.24)—$9.96 /MMBtu$(0.05)/MMBtu
Electricity$51 $(27)Discounted Cash FlowForward basis price (per MWh)$(16.34)—$17.28 /MWh$(2.74)/MWh
The unobservable inputs used in the fair value measurement of the electricity and natural gas commodity types consist of inputs that are less observable due in part to lack of available broker quotes, supported by little, if any, market activity at the measurement date or are based on internally developed models. Certain basis prices (i.e., the difference in pricing between two locations) included in the valuation of natural gas and electricity contracts were deemed unobservable. The weighted average price for unobservable inputs was calculated using the average of forward price curves for natural gas and electricity and the absolute value of monthly volumes.
The inputs listed above would have had a direct impact on the fair values of the above security types if they were adjusted. A significant increase (decrease) in the basis price would have resulted in a higher (lower) fair value for long positions, with offsetting impacts to short positions.
Fair Value of Financial Instruments
The following table presents the carrying amount and fair value of financial instruments for DTE Energy:
December 31, 2025December 31, 2024
CarryingFair ValueCarryingFair Value
AmountLevel 1Level 2Level 3AmountLevel 1Level 2Level 3
(In millions)
Notes receivable(a), excluding lessor finance leases
$1,453 $— $— $1,482 $884 $— $— $904 
Short-term borrowings$882 $— $882 $— $1,067 $— $1,067 $— 
Notes payable(b)
$28 $— $— $28 $37 $— $— $37 
Long-term debt(c)
$25,123 $1,285 $21,204 $1,351 $21,963 $725 $18,283 $1,128 
_______________________________________
(a)Current portion included in Current Assets — Other on DTE Energy's Consolidated Statements of Financial Position. Carrying value includes credit loss reserves on Notes receivable.
(b)Included in Current Liabilities — Other and Other Liabilities — Other on DTE Energy's Consolidated Statements of Financial Position.
(c)Includes debt due within one year and excludes finance lease obligations. Carrying value also includes unamortized debt discounts and issuance costs.
The following table presents the carrying amount and fair value of financial instruments for DTE Electric:
December 31, 2025December 31, 2024
CarryingFair ValueCarryingFair Value
AmountLevel 1Level 2Level 3AmountLevel 1Level 2Level 3
(In millions)
Notes receivable — Affiliates
$— $— $— $— $42 $— $— $42 
Notes receivable — Other(a)
274 — — 289 2 — — 2 
Short-term borrowings — Other
$652 $— $652 $— $666 $— $666 $— 
Notes payable(b)
$24 $— $— $24 $35 $— $— $35 
Long-term debt(c)
$13,165 $— $12,048 $131 $11,881 $— $10,449 $127 
_______________________________________
(a)Included in Other Assets — Other on DTE Electric's Consolidated Statements of Financial Position.
(b)Included in Current Liabilities — Other and Other Liabilities — Other on DTE Electric's Consolidated Statements of Financial Position.
(c)Includes debt due within one year and excludes finance lease obligations. Carrying value also includes unamortized debt discounts and issuance costs.
For further fair value information on financial and derivative instruments, see Note 13 to the Consolidated Financial Statements, "Financial and Other Derivative Instruments."
Nuclear Decommissioning Trust Funds
DTE Electric has a legal obligation to decommission its nuclear power plants following the expiration of its operating licenses. This obligation is reflected as an Asset retirement obligation on DTE Electric's Consolidated Statements of Financial Position. Rates approved by the MPSC provide for the recovery of decommissioning costs of Fermi 2 and the disposal of low-level radioactive waste. See Note 8 to the Consolidated Financial Statements, "Asset Retirement Obligations."
The following table summarizes DTE Electric's fair value of the nuclear decommissioning trust fund assets:
December 31,
20252024
(In millions)
Fermi 2$2,523 $2,234 
Fermi 13 3 
Low-level radioactive waste26 19 
$2,552 $2,256 
The costs of securities sold are determined on the basis of specific identification. The following table sets forth DTE Electric's gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds:
Year Ended December 31,
202520242023
(In millions)
Realized gains$50 $47 $36 
Realized losses$(32)$(27)$(42)
Proceeds from sale of securities$717 $555 $681 
Realized gains and losses from the sale of securities and unrealized gains and losses incurred by the Fermi 2 trust are recorded to Regulatory assets and the Nuclear decommissioning liability. Realized gains and losses from the sale of securities and unrealized gains and losses on the low-level radioactive waste funds are recorded to the Nuclear decommissioning liability.
The following table sets forth DTE Electric's fair value and unrealized gains and losses for the nuclear decommissioning trust funds:
December 31, 2025December 31, 2024
Fair
Value		Unrealized
Gains		Unrealized LossesFair
Value		Unrealized
Gains		Unrealized Losses
(In millions)
Equity securities$1,188 $742 $(10)$1,003 $558 $(16)
Fixed income securities726 25 (17)650 16 (29)
Private equity and other358 125 (7)349 106 (8)
Hedge funds and similar investments245 8 (6)228 7 (5)
Cash equivalents35 — — 26 — — 
$2,552 $900 $(40)$2,256 $687 $(58)
The following table summarizes the fair value of the fixed income securities held in nuclear decommissioning trust funds by contractual maturity:
December 31, 2025
(In millions)
Due within one year$20 
Due after one through five years93 
Due after five through ten years127 
Due after ten years353 
$593 
Fixed income securities held in nuclear decommissioning trust funds include $133 million of non-publicly traded commingled funds that do not have a contractual maturity date.
Other Securities
At December 31, 2025 and 2024, DTE Energy's securities included in Other investments on the Consolidated Statements of Financial Position consisted primarily of investments within DTE Energy's rabbi trust. The rabbi trust is comprised primarily of trading securities recorded at fair value, as well as debt securities classified as held-to-maturity and recorded at amortized cost. The trust was established to fund certain non-qualified pension benefits, and therefore changes in market value of the trading securities and interest on the held-to-maturity securities are recognized in earnings. Gains and losses are allocated from DTE Energy to DTE Electric and are included in Other Income or Other Expense, respectively, in the Registrants' Consolidated Statements of Operations. Gains (losses) related to the trading securities were immaterial for the years ended December 31, 2025, 2024, and 2023.
v3.25.4
Financial and Other Derivative Instruments
 12 Months Ended
Dec. 31, 2025
Derivative Instruments and Hedging Activities Disclosure [Abstract]  
Financial and Other Derivative Instruments FINANCIAL AND OTHER DERIVATIVE INSTRUMENTS
The Registrants recognize all derivatives at their fair value as Derivative assets or liabilities on their respective Consolidated Statements of Financial Position unless they qualify for certain scope exceptions, including the normal purchases and normal sales exception. Further, derivatives that qualify and are designated for hedge accounting are classified as either hedges of a forecasted transaction or the variability of cash flows to be received or paid related to a recognized asset or liability (cash flow hedge); or as hedges of the fair value of a recognized asset or liability or of an unrecognized firm commitment (fair value hedge). For cash flow hedges, the derivative gain or loss is deferred in Accumulated other comprehensive income (loss) and later reclassified into earnings when the underlying transaction occurs. For fair value hedges, changes in fair values for the derivative and hedged item are recognized in earnings each period. For derivatives that do not qualify or are not designated for hedge accounting, changes in fair value are recognized in earnings each period.
The Registrants' primary market risk exposure is associated with commodity prices, credit, and interest rates. The Registrants have risk management policies to monitor and manage market risks. The Registrants use derivative instruments to manage some of the exposure. DTE Energy uses derivative instruments for trading purposes in its Energy Trading segment. Contracts classified as derivative instruments include electricity, natural gas, oil, certain environmental contracts, forwards, futures, options, swaps, and foreign currency exchange contracts. Items not classified as derivatives include natural gas and environmental inventory, pipeline transportation contracts, some environmental contracts, and natural gas storage assets.
DTE Electric — DTE Electric generates, purchases, distributes, and sells electricity. DTE Electric uses forward contracts to manage changes in the price of electricity and fuel. Substantially all of these contracts meet the normal purchases and normal sales exception and are therefore accounted for under the accrual method. Other derivative contracts are MTM and recoverable through the PSCR mechanism when settled. This results in the deferral of unrealized gains and losses as Regulatory assets or liabilities until realized.
DTE Gas — DTE Gas purchases, stores, transports, distributes, and sells natural gas, and buys and sells transportation and storage capacity. DTE Gas has fixed-priced contracts for portions of its expected natural gas supply requirements through March 2028. Substantially all of these contracts meet the normal purchases and normal sales exception and are therefore accounted for under the accrual method. Forward transportation and storage contracts are generally not derivatives and are therefore accounted for under the accrual method.
DTE Vantage — DTE Vantage manages and operates renewable gas recovery projects, power generation assets, and other customer specific energy solutions. Long-term contracts and hedging instruments are used in the marketing and management of the segment assets. These contracts and hedging instruments are generally not derivatives and are therefore accounted for under the accrual method.
Energy Trading — Commodity Price Risk — Energy Trading markets and trades electricity, natural gas physical products, and energy financial instruments, and provides energy and asset management services utilizing energy commodity derivative instruments. Forwards, futures, options, and swap agreements are used to manage exposure to the risk of market price and volume fluctuations in its operations. These derivatives are accounted for by recording changes in fair value to earnings unless hedge accounting criteria are met.
Energy Trading — Foreign Currency Exchange Risk — Energy Trading has foreign currency exchange forward contracts to economically hedge fixed Canadian dollar commitments existing under natural gas and power purchase and sale contracts and natural gas transportation contracts. Energy Trading enters into these contracts to mitigate price volatility with respect to fluctuations of the Canadian dollar relative to the U.S. dollar. These derivatives are accounted for by recording changes in fair value to earnings unless hedge accounting criteria are met.
Corporate and Other — Interest Rate Risk — DTE Energy may use interest rate swaps, treasury locks, and other derivatives to hedge the risk associated with interest rate market volatility.
Credit Risk — DTE Energy maintains credit policies that significantly minimize overall credit risk. These policies include an evaluation of potential customers’ and counterparties’ financial condition, including the viability of underlying productive assets, credit rating, collateral requirements, or other credit enhancements such as letters of credit or guarantees. DTE Energy generally uses standardized agreements that allow the netting of positive and negative transactions associated with a single counterparty. DTE Energy maintains a provision for credit losses based on factors surrounding the credit risk of its customers, historical trends, and other information. Based on DTE Energy's credit policies and its December 31, 2025 provision for credit losses, DTE Energy’s exposure to counterparty nonperformance is not expected to have a material adverse effect on DTE Energy's Consolidated Financial Statements.
Derivative Activities
DTE Energy manages its MTM risk on a portfolio basis based upon the delivery period of its contracts and the individual components of the risks within each contract. Accordingly, it records and manages the energy purchase and sale obligations under its contracts in separate components based on the commodity (e.g. electricity or natural gas), the product (e.g. electricity for delivery during peak or off-peak hours), the delivery location (e.g. by region), the risk profile (e.g. forward or option), and the delivery period (e.g. by month and year). The following describes the categories of activities represented by their operating characteristics and key risks:
•Asset Optimization — Represents derivative activity associated with assets owned and contracted by DTE Energy, including forward natural gas purchases and sales, natural gas transportation, and storage capacity. Changes in the value of derivatives in this category typically economically offset changes in the value of underlying non-derivative positions, which do not qualify for fair value accounting. The difference in accounting treatment of derivatives in this category and the underlying non-derivative positions can result in significant earnings volatility.
•Marketing and Origination — Represents derivative activity transacted by originating substantially hedged positions with wholesale energy marketers, producers, end-users, utilities, retail aggregators, and alternative energy suppliers.
•Fundamentals Based Trading — Represents derivative activity transacted with the intent of taking a view, capturing market price changes, or putting capital at risk. This activity is speculative in nature as opposed to hedging an existing exposure.
•Other — Includes derivative activity at DTE Electric related to FTRs. Changes in the value of derivative contracts at DTE Electric are recorded as Derivative assets or liabilities, with an offset to Regulatory assets or liabilities as the settlement value of these contracts will be included in the PSCR mechanism when realized.
The following table presents the fair value of derivative instruments for DTE Energy:
December 31, 2025December 31, 2024
Derivative
Assets		Derivative
Liabilities		Derivative
Assets		Derivative
Liabilities
(In millions)
Derivatives designated as hedging instruments
Interest rate contracts$3 $— $20 $— 
Foreign currency exchange contracts— (1)— (1)
Total derivatives designated as hedging instruments$3 $(1)$20 $(1)
Derivatives not designated as hedging instruments
Commodity contracts
Natural gas$372 $(329)$428 $(410)
Electricity275 (235)187 (150)
Environmental & Other57 (32)58 (44)
Foreign currency exchange contracts— — 1 — 
Total derivatives not designated as hedging instruments$704 $(596)$674 $(604)
Current$482 $(413)$488 $(441)
Noncurrent225 (184)206 (164)
Total derivatives$707 $(597)$694 $(605)
The fair value of derivative instruments at DTE Electric was $11 million and $9 million at December 31, 2025 and 2024, respectively, comprised of FTRs recorded to Current Assets — Other on the Consolidated Statements of Financial Position and not designated as hedging instruments.
Certain of DTE Energy's derivative positions are subject to netting arrangements which provide for offsetting of asset and liability positions as well as related cash collateral. Such netting arrangements generally do not have restrictions. Under such netting arrangements, DTE Energy offsets the fair value of derivative instruments with cash collateral received or paid for those contracts executed with the same counterparty, which reduces DTE Energy's Total Assets and Liabilities. Cash collateral is allocated between the fair value of derivative instruments and customer accounts receivable and payable with the same counterparty on a pro-rata basis to the extent there is exposure. Any cash collateral remaining, after the exposure is netted to zero, is reflected in Accounts receivable and Accounts payable as collateral paid or received, respectively.
DTE Energy also provides and receives collateral in the form of letters of credit which can be offset against net Derivative assets and liabilities as well as Accounts receivable and payable. DTE Energy had letters of credit of $2 million issued and outstanding at December 31, 2025 and $1 million at December 31, 2024, which could be used to offset net Derivative liabilities. Letters of credit received from third parties which could be used to offset net Derivative assets were $17 million at December 31, 2025. There were none for December 31, 2024. Such balances of letters of credit are excluded from the tables below and are not netted with the recognized assets and liabilities in DTE Energy's Consolidated Statements of Financial Position.
For contracts with certain clearing agents, the fair value of derivative instruments is netted against realized positions with the net balance reflected as either 1) a Derivative asset or liability or 2) an Account receivable or payable. Other than certain clearing agents, Accounts receivable and Accounts payable that are subject to netting arrangements have not been offset against the fair value of Derivative assets and liabilities.
The following table presents net cash collateral offsetting arrangements for DTE Energy:
December 31,
20252024
(In millions)
Cash collateral netted against Derivative assets$(35)$(17)
Cash collateral netted against Derivative liabilities5 — 
Cash collateral recorded in Accounts receivable(a)
20 29 
Cash collateral recorded in Accounts payable(a)
(28)(5)
Total net cash collateral posted (received)$(38)$7 
_______________________________________
(a)Amounts are recorded net by counterparty.
The following table presents the netting offsets of Derivative assets and liabilities for DTE Energy:
December 31, 2025December 31, 2024
Gross Amounts of Recognized Assets (Liabilities)Gross Amounts Offset in the Consolidated Statements of Financial PositionNet Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial PositionGross Amounts of Recognized Assets (Liabilities)Gross Amounts Offset in the Consolidated Statements of Financial PositionNet Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position
(In millions)
Derivative assets
Commodity contracts(a)
Natural gas$372 $(235)$137 $428 $(285)$143 
Electricity275 (194)81 187 (116)71 
Environmental & Other57 (46)11 58 (46)12 
Interest rate contracts3 — 3 20 — 20 
Foreign currency exchange contracts— — — 1 — 1 
Total derivative assets$707 $(475)$232 $694 $(447)$247 
Derivative liabilities
Commodity contracts(a)
Natural gas$(329)$227 $(102)$(410)$272 $(138)
Electricity(235)186 (49)(150)114 (36)
Environmental & Other(32)32 — (44)44 — 
Foreign currency exchange contracts(1)— (1)(1)— (1)
Total derivative liabilities$(597)$445 $(152)$(605)$430 $(175)
_______________________________________
(a)For contracts with a clearing agent, DTE Energy nets all activity across commodities. This can result in some individual commodities having a contra balance.
The following table presents the netting offsets of Derivative assets and liabilities showing the reconciliation of derivative instruments to DTE Energy's Consolidated Statements of Financial Position:
December 31, 2025December 31, 2024
Derivative AssetsDerivative LiabilitiesDerivative AssetsDerivative Liabilities
CurrentNoncurrentCurrentNoncurrentCurrentNoncurrentCurrentNoncurrent
(In millions)
Total fair value of derivatives$482 $225 $(413)$(184)$488 $206 $(441)$(164)
Counterparty netting(325)(115)325 115 (323)(107)323 107 
Collateral adjustment(14)(21)2 3 (3)(14)— — 
Total derivatives as reported$143 $89 $(86)$(66)$162 $85 $(118)$(57)
The effect of derivatives not designated as hedging instruments on DTE Energy's Consolidated Statements of Operations is as follows:
Location of Gain (Loss) Recognized in Income on DerivativesGain (Loss) Recognized in Income on Derivatives for Years Ended December 31,
202520242023
(In millions)
Commodity contracts
Natural gasOperating Revenues — Non-utility operations $112 $(169)$153 
Natural gasFuel, purchased power, gas, and other — non-utility(160)233 122 
ElectricityOperating Revenues — Non-utility operations 361 266 105 
Environmental & OtherOperating Revenues — Non-utility operations 61 14 5 
Foreign currency exchange contractsOperating Revenues — Non-utility operations (1)3 (2)
Total$373 $347 $383 
Revenues and energy costs related to trading contracts are presented on a net basis in DTE Energy's Consolidated Statements of Operations. Commodity derivatives used for trading purposes, and financial non-trading commodity derivatives, are accounted for using the MTM method with unrealized and realized gains and losses recorded in Operating Revenues — Non-utility operations. Non-trading physical commodity sale and purchase derivative contracts are generally accounted for using the MTM method with unrealized and realized gains and losses for sales recorded in Operating Revenues — Non-utility operations and purchases recorded in Fuel, purchased power, gas, and other — non-utility.
The following represents the cumulative gross volume of DTE Energy's derivative contracts outstanding as of December 31, 2025:
CommodityNumber of Units
Natural gas (MMBtu)2,451,423,819 
Electricity (MWh)39,287,109 
Foreign currency exchange ($ CAD)67,058,920 
FTR (MWh)82,664 
Renewable Energy Certificates (MWh)11,860,903 
Carbon emissions (Metric Ton)1,113,500 
Interest rate contracts ($ USD)300,000,000 
Various subsidiaries and equity investees of DTE Energy have entered into derivative and non-derivative contracts which contain ratings triggers and are guaranteed by DTE Energy. These contracts contain provisions which allow the counterparties to require that DTE Energy post cash or letters of credit as collateral in the event that DTE Energy’s credit rating is downgraded below investment grade. Certain of these provisions (known as "hard triggers") state specific circumstances under which DTE Energy can be required to post collateral upon the occurrence of a credit downgrade, while other provisions (known as "soft triggers") are not as specific. For contracts with soft triggers, it is difficult to estimate the amount of collateral which may be requested by counterparties and/or which DTE Energy may ultimately be required to post. The amount of such collateral which could be requested fluctuates based on commodity prices (primarily natural gas, power, and environmental) and the provisions and maturities of the underlying transactions. As of December 31, 2025, DTE Energy's contractual obligation to post collateral in the form of cash or letters of credit in the event of a downgrade to below investment grade, under both hard trigger and soft trigger provisions, was $483 million.
As of December 31, 2025, DTE Energy had $491 million of derivatives in net liability positions, for which hard triggers exist. There is $3 million of collateral that has been posted against such liabilities, including cash and letters of credit. Associated derivative net asset positions for which contractual offset exists were $426 million. The net remaining amount of $62 million is derived from the $483 million noted above.
v3.25.4
Long-Term Financings
 12 Months Ended
Dec. 31, 2025
Debt Disclosure [Abstract]  
Long-Term Financings LONG-TERM FINANCINGS
Long-Term Debt
DTE Energy's long-term debt outstanding and interest rates of debt outstanding at December 31 were:
Interest Rate(a)
Maturity Date20252024
(In millions)
Mortgage bonds, notes, and other
DTE Energy debt, unsecured4.7%2026 — 2035$7,479 $6,380 
DTE Electric debt, principally secured4.2%2026 — 205512,620 11,270 
DTE Gas debt, principally secured4.4%2027 — 20553,055 2,865 
23,154 20,515 
Unamortized debt discount(14)(28)
Unamortized debt issuance costs(127)(114)
Long-term debt due within one year(1,277)(1,220)
$21,736 $19,153 
Securitization bonds(b)
DTE Electric securitization bonds5.6%2027 — 2038$642 $713 
Unamortized debt issuance costs(6)(7)
Long-term debt due within one year(75)(71)
$561 $635 
Junior Subordinated Debentures
Subordinated debentures5.4%2077 — 2085$1,510 $910 
Unamortized debt issuance costs(36)(26)
$1,474 $884 
_______________________________________
(a)Weighted average interest rate as of December 31, 2025.
(b)Bonds are held by DTE Securitization I and DTE Securitization II, special purpose entities consolidated by DTE Electric. Refer to Note 1 to the Consolidated Financial Statements, “Organization and Basis of Presentation,” for additional information regarding these entities and restrictions related to the bonds.
DTE Electric's long-term debt outstanding and interest rates of debt outstanding at December 31 were:
Interest Rate(a)
Maturity Date20252024
(In millions)
Mortgage bonds, notes, and other
Long-term debt, principally secured4.2%2026 — 2055$12,620 $11,270 
Unamortized debt discount(11)(22)
Unamortized debt issuance costs(80)(73)
Long-term debt due within one year(677)(350)
$11,852 $10,825 
Securitization bonds(b)
DTE Electric securitization bonds5.6%2027 — 2038$642 $713 
Unamortized debt issuance costs(6)(7)
Long-term debt due within one year(75)(71)
$561 $635 
_______________________________________
(a)Weighted average interest rate as of December 31, 2025.
(b)Bonds are held by DTE Securitization I and DTE Securitization II, special purpose entities consolidated by DTE Electric. Refer to Note 1 to the Consolidated Financial Statements, “Organization and Basis of Presentation,” for additional information regarding these entities and restrictions related to the bonds.
Debt Issuances
Refer to the table below for debt issued in 2025:
CompanyMonthTypeInterest RateMaturity DateAmount
(In millions)
DTE EnergyFebruary
Senior Notes(a)
5.20%2030$1,100 
DTE ElectricMay
Mortgage Bonds(b)
5.25%2035500 
DTE ElectricMay
Mortgage Bonds(b)
5.85%2055500 
DTE ElectricMay
Mortgage Bonds(b)
4.25%2027300 
DTE EnergySeptember
Senior Notes(a)
4.88%2028250 
DTE EnergySeptember
Senior Notes(a)
5.05%2035550 
DTE EnergySeptember
Junior Subordinated Debentures(a)
6.25%2085600 
DTE GasSeptember
Mortgage Bonds(b)
4.71%203150 
DTE GasSeptember
Mortgage Bonds(b)
5.36%203775 
DTE GasSeptember
Mortgage Bonds(b)
5.96%2055135 
DTE ElectricNovember
Mortgage Bonds(b)
5.25%2035200 
DTE ElectricNovember
Mortgage Bonds(b)
5.85%2055200 
$4,460 
_______________________________
(a)Proceeds used for the repayment of short-term borrowings and for general corporate purposes.
(b)Proceeds used for the repayment of short-term borrowings, for capital expenditures, and for other general corporate purposes.
Debt Redemptions
Refer to the table below for debt redeemed in 2025:
CompanyMonthTypeInterest RateMaturity DateAmount
(In millions)
DTE ElectricMarchMortgage Bonds3.38%2025$350 
DTE ElectricMarchSecuritization Bonds5.97%202515
DTE EnergyJuneSenior Notes1.05%2025800
DTE ElectricJuneSecuritization Bonds2.64%202520
DTE ElectricSeptemberSecuritization Bonds5.97%202515
DTE ElectricDecemberSecuritization Bonds2.64%202521
DTE GasDecemberMortgage Bonds3.74%202570
$1,291 
Debt Maturities
The following table shows the Registrants' scheduled debt maturities, excluding any unamortized discount on debt:
202620272028202920302031 and ThereafterTotal
(In millions)
DTE Energy(a)(b)
$1,352 $1,730 $1,987 $1,962 $2,504 $15,771 $25,306 
DTE Electric(b)
$752 $339 $617 $103 $829 $10,622 $13,262 
_______________________________________
(a)Amounts include DTE Electric's scheduled debt maturities.
(b)Amounts include DTE Securitization I and DTE Securitization II scheduled debt maturities.
The following table shows scheduled interest payments related to the Registrants' long-term debt:
202620272028202920302031 and ThereafterTotal
(In millions)
DTE Energy(a)(b)
$1,127 $1,039 $963 $879 $790 $11,465 $16,263 
DTE Electric(b)
$557 $518 $504 $496 $484 $5,637 $8,196 
_______________________________________
(a)Amounts include DTE Electric's scheduled interest payments.
(b)Amounts include DTE Securitization I and DTE Securitization II scheduled interest payments.
Junior Subordinated Debentures
DTE Energy has the right to defer interest payments on the Junior Subordinated Debentures. Should DTE Energy exercise this right, it cannot declare or pay dividends on, or redeem, purchase or acquire, any of its capital stock during the deferral period. Any deferred interest payments will bear additional interest at the rate associated with the related debt issue. As of December 31, 2025, no interest payments have been deferred on the Junior Subordinated Debentures.
Cross Default Provisions
Substantially all of the net utility properties of DTE Electric and DTE Gas are subject to the lien of mortgages. Should DTE Electric or DTE Gas fail to timely pay their indebtedness under these mortgages, such failure may create cross defaults in the indebtedness of DTE Energy.
Equity At-the-Market Program
In December 2025, DTE Energy filed a prospectus supplement and executed an Equity Distribution Agreement, pursuant to which DTE Energy may sell, from time to time, up to an aggregate $1.5 billion of its common stock through an at-the-market program, including an equity forward sales component. There were no issuances under the ATM program for the year ended December 31, 2025.
v3.25.4
Preferred and Preference Securities
 12 Months Ended
Dec. 31, 2025
Preferred Stock, Number of Shares, Par Value and Other Disclosure [Abstract]  
Preferred and Preference Securities PREFERRED AND PREFERENCE SECURITIES
As of December 31, 2025, the amount of authorized and unissued stock is as follows:
CompanyType of StockPar ValueShares Authorized
DTE EnergyPreferred$— 5,000,000 
DTE ElectricPreferred$100 6,747,484 
DTE ElectricPreference$1 30,000,000 
DTE GasPreferred$1 7,000,000 
DTE GasPreference$1 4,000,000 
v3.25.4
Short-Term Credit Arrangements and Borrowings
 12 Months Ended
Dec. 31, 2025
Short-Term Debt [Abstract]  
Short-Term Credit Arrangements and Borrowings SHORT-TERM CREDIT ARRANGEMENTS AND BORROWINGS
DTE Energy, DTE Electric, and DTE Gas have unsecured revolving credit agreements that can be used for general corporate borrowings, but are intended to provide liquidity support for each of the companies’ commercial paper programs. Borrowings under the revolvers are available at prevailing short-term interest rates. Letters of credit of up to $500 million may also be issued under the DTE Energy revolver. DTE Energy and DTE Electric also have other facilities to support letter of credit issuance and increase liquidity.
The unsecured revolving credit agreements require a total funded debt to capitalization ratio of no more than 0.70 to 1 for DTE Energy and 0.65 to 1 for DTE Electric and DTE Gas. In the agreements, "total funded debt" means all indebtedness of each respective company and their consolidated subsidiaries, including finance lease obligations, hedge agreements, and guarantees of third parties’ debt, but excluding contingent obligations, nonrecourse and junior subordinated debt, and certain equity-linked securities and, except for calculations at the end of the second quarter, certain DTE Gas short-term debt. "Capitalization" means the sum of (a) total funded debt plus (b) "consolidated net worth," which is equal to consolidated total equity of each respective company and their consolidated subsidiaries (excluding pension effects under certain FASB statements), as determined in accordance with accounting principles generally accepted in the United States of America. At December 31, 2025, the total funded debt to total capitalization ratios for DTE Energy, DTE Electric, and DTE Gas were 0.66 to 1, 0.52 to 1, and 0.49 to 1, respectively, and were in compliance with this financial covenant.
The availability under the facilities in place at December 31, 2025 is shown in the following table:
DTE EnergyDTE ElectricDTE GasTotal
(In millions)
Unsecured revolving credit facility, expiring October 2030$1,500 $1,000 $300 $2,800 
Unsecured letter of credit facility, expiring June 2026(a)
150 — — 150 
Unsecured letter of credit facility, expiring February 2027200 — — 200 
Unsecured letter of credit facilities, expiring June 2028150 — — 150 
Unsecured letter of credit facility(b)
75 — — 75 
Unsecured letter of credit facilities, expiring December 2026— 150 — 150 
Unsecured letter of credit facility(c)
— 175 — 175 
Unsecured letter of credit facility(d)
— 150 — 150 
2,075 1,475 300 3,850 
Amounts outstanding at December 31, 2025
Commercial paper issuances150 652 80 882 
Letters of credit416 331 — 747 
566 983 80 1,629 
Net availability at December 31, 2025$1,509 $492 $220 $2,221 
_______________________________________
(a)Uncommitted letter of credit facility.
(b)Uncommitted letter of credit facility with automatic renewal provision and therefore no expiration. DTE Electric may also utilize availability under this facility.
(c)Uncommitted letter of credit facility with automatic renewal provision and therefore no expiration. DTE Energy may also utilize availability under this facility.
(d)Uncommitted letter of credit facility with automatic renewal provision and therefore no expiration.
In February 2026, DTE Energy entered into two unsecured term loan agreements for a total of $550 million and borrowed the full amount under each agreement. Both term loans mature in August 2026. The term loans contain terms and conditions consistent with those of DTE Energy's unsecured revolving credit agreements.
For both DTE Energy and DTE Electric, the weighted average interest rate for short-term borrowings was 3.8% and 4.7% at December 31, 2025 and 2024, respectively. For information related to affiliate short-term borrowings, refer to Note 23 of the Consolidated Financial Statements, "Related Party Transactions."
In conjunction with maintaining certain exchange-traded risk management positions, DTE Energy may be required to post collateral with a clearing agent. DTE Energy has a demand financing agreement with its clearing agent which allows the right of setoff with posted collateral. At December 31, 2025, the capacity under the facility was $200 million. The amounts outstanding under demand financing agreements were $94 million and $49 million at December 31, 2025 and 2024, respectively, and were fully offset by posted collateral.
Dividend Restrictions
Certain of DTE Energy’s credit facilities contain a provision requiring DTE Energy to maintain a total funded debt to capitalization ratio, as defined in the agreements, of no more than 0.70 to 1, which has the effect of limiting the amount of dividends DTE Energy can pay in order to maintain compliance with this provision. At December 31, 2025, the effect of this provision was a restriction on dividend payments to no more than $2.1 billion of DTE Energy's Retained earnings of $5.5 billion. There are no other effective limitations with respect to DTE Energy’s ability to pay dividends.
v3.25.4
Leases
 12 Months Ended
Dec. 31, 2025
Leases [Abstract]  
Leases LEASES
Lessee
Leases at DTE Energy and DTE Electric are primarily comprised of various forms of land easements, coal railcars, buildings, equipment, and computer hardware, leases with terms ranging from approximately 2 to 52 years.
A lease is deemed to exist when the Registrants have the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration paid. The right to control is deemed to occur when the Registrants have the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.
In accordance with ASC Subtopic 980-842, Regulated Operations - Leases, DTE Electric recognizes expense for operating leases using the timing that conforms to the regulatory rate treatment as rental payments are recovered from customers.
Lease liabilities are determined utilizing the discount rate implicit in the lease when it is readily determinable. When the rate implicit in the lease is not readily determinable, the incremental borrowing rate is used. The incremental borrowing rates for DTE Electric and DTE Gas have been determined utilizing respective secured borrowing rates for first mortgage bonds with like tenors of remaining lease terms. Incremental borrowing rates for non-utility entities have been determined utilizing an implied secured borrowing rate based upon an unsecured rate for a similar tenor of remaining lease terms, which is then adjusted for the estimated impact of collateral.
The Registrants have certain leases which contain renewal or purchase options. Where the renewal options were deemed reasonably certain to occur, the impacts of such options were included in the determination of the right of use assets and lease liabilities. The Registrants have determined that it is not reasonably certain that purchase options will be utilized and have not included the impact in the determination of right of use assets and lease liabilities for the subject leases.
Certain leases of the Registrants contain escalation clauses whereby the payments are adjusted for consumer price or labor indices, as well as non-index based escalations for percentage increases. The Registrants also have leases with variable payments based upon the usage of the leased assets.
Certain leases contain provisions whereby the Registrants have the option to terminate the lease agreement by giving notice of such termination during the time frames specified in the respective lease. The Registrants have considered such provisions in the determination of the lease term when it is reasonably certain that the lease would be terminated.
The Registrants have agreements with lease and non-lease components, which are generally accounted for separately. Consideration in a lease is allocated between lease and non-lease components based upon the estimated relative standalone prices. The Registrants have certain coal railcar leases for which non-lease and lease components are accounted for as a single lease component, as permitted under Topic 842.
The following is a summary of the components of lease cost for the years ended December 31:
DTE EnergyDTE Electric
202520242023202520242023
(In millions)
Operating lease cost$23 $26 $22 $17 $22 $17 
Finance lease cost:
Amortization of right-of-use assets4 4 7 3 3 6 
Interest of lease liabilities1 1 — — 1 — 
Total finance lease cost5 5 7 3 4 6 
Variable lease cost17 17 13 1 — — 
Short-term lease cost19 18 12 11 10 4 
$64 $66 $54 $32 $36 $27 
The Registrants have elected not to apply the recognition requirements of Topic 842 to leases with a term of 12 months or less. DTE Energy and DTE Electric record operating, variable, and short-term lease costs as Operating Expenses on the Consolidated Statements of Operations, except for certain amounts that may be capitalized to Property, plant, and equipment and Inventories.
The following is a summary of other information related to leases for the years ended December 31:
DTE EnergyDTE Electric
202520242023202520242023
(In millions)
Supplemental Cash Flows Information
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows for finance leases$5 $9 $9 $3 $7 $7 
Operating cash flows for operating leases$27 $19 $19 $21 $15 $15 
Right-of-use assets obtained in exchange for lease obligations:
Operating leases$95 $75 $61 $86 $74 $61 
Finance leases$— $16 $5 $— $14 $5 
Weighted Average Remaining Lease Term (Years)
Operating leases24.523.318.726.324.819.8
Finance leases6.67.48.93.04.04.5
Weighted Average Discount Rate
Operating leases5.1 %4.8 %4.4 %5.2 %4.9 %4.5 %
Finance leases4.5 %4.6 %4.0 %5.8 %5.8 %5.4 %
The Registrants' future minimum lease payments under leases for remaining periods as of December 31, 2025 are as follows:
DTE EnergyDTE Electric
Operating LeasesFinance LeasesOperating LeasesFinance Leases
(In millions)
2026$37 $5 $31 $3 
202735 4 30 3 
202832 4 28 3 
202921 1 17 — 
203013 1 10 — 
2031 and thereafter400 5 379 — 
Total future minimum lease payments538 20 495 9 
Imputed interest(271)(2)(262)— 
Lease liabilities$267 $18 $233 $9 
Finance leases reported on the Consolidated Statements of Financial Position of the Registrants are as follows for the years ended December 31:
DTE EnergyDTE Electric
2025202420252024
(In millions)
Right-of-use assets, within Property, plant, and equipment, net$18 $23 $9 $12 
Current lease liabilities, within Current portion of long-term debt$4 $5 $3 $4 
Long-term lease liabilities$14 $18 $6 $8 
Lessor
DTE Energy leases various assets under operating leases for a pipeline, energy facilities and related equipment. Such leases are comprised of both fixed payments and variable payments which are contingent on volumes, with terms ranging from 10 to 24 years. Generally, the operating leases do not have renewal provisions or options to purchase the assets at the end of the lease. The operating leases generally do not have termination for convenience provisions. Termination may be allowed under specific circumstances stated in the lease contract, such as under an event of default.
Certain of the finance and operating leases have lease terms that extend to the end of the estimated economic life of the leased assets, thereby resulting in no residual value. Any remaining residual values under the finance and operating leases are expected to be recovered through rates, renewals or new lease contracts. Residual values have been determined using the estimated economic life of the leased assets. The finance and operating leases do not contain residual value guarantees.
Certain of the operating leases have both lease and non-lease components. The lease and non-lease components are allocated based upon estimated relative standalone selling prices.
A lease is deemed to exist when the Registrants have provided other parties with the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration received. The right to control is deemed to occur when the Registrants have provided other parties with the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.
DTE Energy’s lease income associated with operating leases was included on the Consolidated Statements of Operations for the years ended December 31:
202520242023
(In millions)
Fixed payments$15 $15 $15 
Variable payments46 45 44 
$61 $60 $59 
DTE Energy’s minimum future rental revenues under operating leases for remaining periods as of December 31, 2025 are as follows:
DTE Energy
(In millions)
2026$11 
202710 
20286 
20296 
20306 
2031 and thereafter23 
$62 
Depreciation expense associated with DTE Energy's property under operating leases was $8 million, $9 million, and $8 million for the years ended December 31, 2025, 2024, and 2023, respectively.
The following is a summary of property under operating leases for DTE Energy as of December 31:
20252024
(In millions)
Gross property under operating leases$228 $227 
Accumulated amortization of property under operating leases$126 $118 
Leases LEASES
Lessee
Leases at DTE Energy and DTE Electric are primarily comprised of various forms of land easements, coal railcars, buildings, equipment, and computer hardware, leases with terms ranging from approximately 2 to 52 years.
A lease is deemed to exist when the Registrants have the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration paid. The right to control is deemed to occur when the Registrants have the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.
In accordance with ASC Subtopic 980-842, Regulated Operations - Leases, DTE Electric recognizes expense for operating leases using the timing that conforms to the regulatory rate treatment as rental payments are recovered from customers.
Lease liabilities are determined utilizing the discount rate implicit in the lease when it is readily determinable. When the rate implicit in the lease is not readily determinable, the incremental borrowing rate is used. The incremental borrowing rates for DTE Electric and DTE Gas have been determined utilizing respective secured borrowing rates for first mortgage bonds with like tenors of remaining lease terms. Incremental borrowing rates for non-utility entities have been determined utilizing an implied secured borrowing rate based upon an unsecured rate for a similar tenor of remaining lease terms, which is then adjusted for the estimated impact of collateral.
The Registrants have certain leases which contain renewal or purchase options. Where the renewal options were deemed reasonably certain to occur, the impacts of such options were included in the determination of the right of use assets and lease liabilities. The Registrants have determined that it is not reasonably certain that purchase options will be utilized and have not included the impact in the determination of right of use assets and lease liabilities for the subject leases.
Certain leases of the Registrants contain escalation clauses whereby the payments are adjusted for consumer price or labor indices, as well as non-index based escalations for percentage increases. The Registrants also have leases with variable payments based upon the usage of the leased assets.
Certain leases contain provisions whereby the Registrants have the option to terminate the lease agreement by giving notice of such termination during the time frames specified in the respective lease. The Registrants have considered such provisions in the determination of the lease term when it is reasonably certain that the lease would be terminated.
The Registrants have agreements with lease and non-lease components, which are generally accounted for separately. Consideration in a lease is allocated between lease and non-lease components based upon the estimated relative standalone prices. The Registrants have certain coal railcar leases for which non-lease and lease components are accounted for as a single lease component, as permitted under Topic 842.
The following is a summary of the components of lease cost for the years ended December 31:
DTE EnergyDTE Electric
202520242023202520242023
(In millions)
Operating lease cost$23 $26 $22 $17 $22 $17 
Finance lease cost:
Amortization of right-of-use assets4 4 7 3 3 6 
Interest of lease liabilities1 1 — — 1 — 
Total finance lease cost5 5 7 3 4 6 
Variable lease cost17 17 13 1 — — 
Short-term lease cost19 18 12 11 10 4 
$64 $66 $54 $32 $36 $27 
The Registrants have elected not to apply the recognition requirements of Topic 842 to leases with a term of 12 months or less. DTE Energy and DTE Electric record operating, variable, and short-term lease costs as Operating Expenses on the Consolidated Statements of Operations, except for certain amounts that may be capitalized to Property, plant, and equipment and Inventories.
The following is a summary of other information related to leases for the years ended December 31:
DTE EnergyDTE Electric
202520242023202520242023
(In millions)
Supplemental Cash Flows Information
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows for finance leases$5 $9 $9 $3 $7 $7 
Operating cash flows for operating leases$27 $19 $19 $21 $15 $15 
Right-of-use assets obtained in exchange for lease obligations:
Operating leases$95 $75 $61 $86 $74 $61 
Finance leases$— $16 $5 $— $14 $5 
Weighted Average Remaining Lease Term (Years)
Operating leases24.523.318.726.324.819.8
Finance leases6.67.48.93.04.04.5
Weighted Average Discount Rate
Operating leases5.1 %4.8 %4.4 %5.2 %4.9 %4.5 %
Finance leases4.5 %4.6 %4.0 %5.8 %5.8 %5.4 %
The Registrants' future minimum lease payments under leases for remaining periods as of December 31, 2025 are as follows:
DTE EnergyDTE Electric
Operating LeasesFinance LeasesOperating LeasesFinance Leases
(In millions)
2026$37 $5 $31 $3 
202735 4 30 3 
202832 4 28 3 
202921 1 17 — 
203013 1 10 — 
2031 and thereafter400 5 379 — 
Total future minimum lease payments538 20 495 9 
Imputed interest(271)(2)(262)— 
Lease liabilities$267 $18 $233 $9 
Finance leases reported on the Consolidated Statements of Financial Position of the Registrants are as follows for the years ended December 31:
DTE EnergyDTE Electric
2025202420252024
(In millions)
Right-of-use assets, within Property, plant, and equipment, net$18 $23 $9 $12 
Current lease liabilities, within Current portion of long-term debt$4 $5 $3 $4 
Long-term lease liabilities$14 $18 $6 $8 
Lessor
DTE Energy leases various assets under operating leases for a pipeline, energy facilities and related equipment. Such leases are comprised of both fixed payments and variable payments which are contingent on volumes, with terms ranging from 10 to 24 years. Generally, the operating leases do not have renewal provisions or options to purchase the assets at the end of the lease. The operating leases generally do not have termination for convenience provisions. Termination may be allowed under specific circumstances stated in the lease contract, such as under an event of default.
Certain of the finance and operating leases have lease terms that extend to the end of the estimated economic life of the leased assets, thereby resulting in no residual value. Any remaining residual values under the finance and operating leases are expected to be recovered through rates, renewals or new lease contracts. Residual values have been determined using the estimated economic life of the leased assets. The finance and operating leases do not contain residual value guarantees.
Certain of the operating leases have both lease and non-lease components. The lease and non-lease components are allocated based upon estimated relative standalone selling prices.
A lease is deemed to exist when the Registrants have provided other parties with the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration received. The right to control is deemed to occur when the Registrants have provided other parties with the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.
DTE Energy’s lease income associated with operating leases was included on the Consolidated Statements of Operations for the years ended December 31:
202520242023
(In millions)
Fixed payments$15 $15 $15 
Variable payments46 45 44 
$61 $60 $59 
DTE Energy’s minimum future rental revenues under operating leases for remaining periods as of December 31, 2025 are as follows:
DTE Energy
(In millions)
2026$11 
202710 
20286 
20296 
20306 
2031 and thereafter23 
$62 
Depreciation expense associated with DTE Energy's property under operating leases was $8 million, $9 million, and $8 million for the years ended December 31, 2025, 2024, and 2023, respectively.
The following is a summary of property under operating leases for DTE Energy as of December 31:
20252024
(In millions)
Gross property under operating leases$228 $227 
Accumulated amortization of property under operating leases$126 $118 
Leases LEASES
Lessee
Leases at DTE Energy and DTE Electric are primarily comprised of various forms of land easements, coal railcars, buildings, equipment, and computer hardware, leases with terms ranging from approximately 2 to 52 years.
A lease is deemed to exist when the Registrants have the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration paid. The right to control is deemed to occur when the Registrants have the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.
In accordance with ASC Subtopic 980-842, Regulated Operations - Leases, DTE Electric recognizes expense for operating leases using the timing that conforms to the regulatory rate treatment as rental payments are recovered from customers.
Lease liabilities are determined utilizing the discount rate implicit in the lease when it is readily determinable. When the rate implicit in the lease is not readily determinable, the incremental borrowing rate is used. The incremental borrowing rates for DTE Electric and DTE Gas have been determined utilizing respective secured borrowing rates for first mortgage bonds with like tenors of remaining lease terms. Incremental borrowing rates for non-utility entities have been determined utilizing an implied secured borrowing rate based upon an unsecured rate for a similar tenor of remaining lease terms, which is then adjusted for the estimated impact of collateral.
The Registrants have certain leases which contain renewal or purchase options. Where the renewal options were deemed reasonably certain to occur, the impacts of such options were included in the determination of the right of use assets and lease liabilities. The Registrants have determined that it is not reasonably certain that purchase options will be utilized and have not included the impact in the determination of right of use assets and lease liabilities for the subject leases.
Certain leases of the Registrants contain escalation clauses whereby the payments are adjusted for consumer price or labor indices, as well as non-index based escalations for percentage increases. The Registrants also have leases with variable payments based upon the usage of the leased assets.
Certain leases contain provisions whereby the Registrants have the option to terminate the lease agreement by giving notice of such termination during the time frames specified in the respective lease. The Registrants have considered such provisions in the determination of the lease term when it is reasonably certain that the lease would be terminated.
The Registrants have agreements with lease and non-lease components, which are generally accounted for separately. Consideration in a lease is allocated between lease and non-lease components based upon the estimated relative standalone prices. The Registrants have certain coal railcar leases for which non-lease and lease components are accounted for as a single lease component, as permitted under Topic 842.
The following is a summary of the components of lease cost for the years ended December 31:
DTE EnergyDTE Electric
202520242023202520242023
(In millions)
Operating lease cost$23 $26 $22 $17 $22 $17 
Finance lease cost:
Amortization of right-of-use assets4 4 7 3 3 6 
Interest of lease liabilities1 1 — — 1 — 
Total finance lease cost5 5 7 3 4 6 
Variable lease cost17 17 13 1 — — 
Short-term lease cost19 18 12 11 10 4 
$64 $66 $54 $32 $36 $27 
The Registrants have elected not to apply the recognition requirements of Topic 842 to leases with a term of 12 months or less. DTE Energy and DTE Electric record operating, variable, and short-term lease costs as Operating Expenses on the Consolidated Statements of Operations, except for certain amounts that may be capitalized to Property, plant, and equipment and Inventories.
The following is a summary of other information related to leases for the years ended December 31:
DTE EnergyDTE Electric
202520242023202520242023
(In millions)
Supplemental Cash Flows Information
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows for finance leases$5 $9 $9 $3 $7 $7 
Operating cash flows for operating leases$27 $19 $19 $21 $15 $15 
Right-of-use assets obtained in exchange for lease obligations:
Operating leases$95 $75 $61 $86 $74 $61 
Finance leases$— $16 $5 $— $14 $5 
Weighted Average Remaining Lease Term (Years)
Operating leases24.523.318.726.324.819.8
Finance leases6.67.48.93.04.04.5
Weighted Average Discount Rate
Operating leases5.1 %4.8 %4.4 %5.2 %4.9 %4.5 %
Finance leases4.5 %4.6 %4.0 %5.8 %5.8 %5.4 %
The Registrants' future minimum lease payments under leases for remaining periods as of December 31, 2025 are as follows:
DTE EnergyDTE Electric
Operating LeasesFinance LeasesOperating LeasesFinance Leases
(In millions)
2026$37 $5 $31 $3 
202735 4 30 3 
202832 4 28 3 
202921 1 17 — 
203013 1 10 — 
2031 and thereafter400 5 379 — 
Total future minimum lease payments538 20 495 9 
Imputed interest(271)(2)(262)— 
Lease liabilities$267 $18 $233 $9 
Finance leases reported on the Consolidated Statements of Financial Position of the Registrants are as follows for the years ended December 31:
DTE EnergyDTE Electric
2025202420252024
(In millions)
Right-of-use assets, within Property, plant, and equipment, net$18 $23 $9 $12 
Current lease liabilities, within Current portion of long-term debt$4 $5 $3 $4 
Long-term lease liabilities$14 $18 $6 $8 
Lessor
DTE Energy leases various assets under operating leases for a pipeline, energy facilities and related equipment. Such leases are comprised of both fixed payments and variable payments which are contingent on volumes, with terms ranging from 10 to 24 years. Generally, the operating leases do not have renewal provisions or options to purchase the assets at the end of the lease. The operating leases generally do not have termination for convenience provisions. Termination may be allowed under specific circumstances stated in the lease contract, such as under an event of default.
Certain of the finance and operating leases have lease terms that extend to the end of the estimated economic life of the leased assets, thereby resulting in no residual value. Any remaining residual values under the finance and operating leases are expected to be recovered through rates, renewals or new lease contracts. Residual values have been determined using the estimated economic life of the leased assets. The finance and operating leases do not contain residual value guarantees.
Certain of the operating leases have both lease and non-lease components. The lease and non-lease components are allocated based upon estimated relative standalone selling prices.
A lease is deemed to exist when the Registrants have provided other parties with the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration received. The right to control is deemed to occur when the Registrants have provided other parties with the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.
DTE Energy’s lease income associated with operating leases was included on the Consolidated Statements of Operations for the years ended December 31:
202520242023
(In millions)
Fixed payments$15 $15 $15 
Variable payments46 45 44 
$61 $60 $59 
DTE Energy’s minimum future rental revenues under operating leases for remaining periods as of December 31, 2025 are as follows:
DTE Energy
(In millions)
2026$11 
202710 
20286 
20296 
20306 
2031 and thereafter23 
$62 
Depreciation expense associated with DTE Energy's property under operating leases was $8 million, $9 million, and $8 million for the years ended December 31, 2025, 2024, and 2023, respectively.
The following is a summary of property under operating leases for DTE Energy as of December 31:
20252024
(In millions)
Gross property under operating leases$228 $227 
Accumulated amortization of property under operating leases$126 $118 
Leases LEASES
Lessee
Leases at DTE Energy and DTE Electric are primarily comprised of various forms of land easements, coal railcars, buildings, equipment, and computer hardware, leases with terms ranging from approximately 2 to 52 years.
A lease is deemed to exist when the Registrants have the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration paid. The right to control is deemed to occur when the Registrants have the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.
In accordance with ASC Subtopic 980-842, Regulated Operations - Leases, DTE Electric recognizes expense for operating leases using the timing that conforms to the regulatory rate treatment as rental payments are recovered from customers.
Lease liabilities are determined utilizing the discount rate implicit in the lease when it is readily determinable. When the rate implicit in the lease is not readily determinable, the incremental borrowing rate is used. The incremental borrowing rates for DTE Electric and DTE Gas have been determined utilizing respective secured borrowing rates for first mortgage bonds with like tenors of remaining lease terms. Incremental borrowing rates for non-utility entities have been determined utilizing an implied secured borrowing rate based upon an unsecured rate for a similar tenor of remaining lease terms, which is then adjusted for the estimated impact of collateral.
The Registrants have certain leases which contain renewal or purchase options. Where the renewal options were deemed reasonably certain to occur, the impacts of such options were included in the determination of the right of use assets and lease liabilities. The Registrants have determined that it is not reasonably certain that purchase options will be utilized and have not included the impact in the determination of right of use assets and lease liabilities for the subject leases.
Certain leases of the Registrants contain escalation clauses whereby the payments are adjusted for consumer price or labor indices, as well as non-index based escalations for percentage increases. The Registrants also have leases with variable payments based upon the usage of the leased assets.
Certain leases contain provisions whereby the Registrants have the option to terminate the lease agreement by giving notice of such termination during the time frames specified in the respective lease. The Registrants have considered such provisions in the determination of the lease term when it is reasonably certain that the lease would be terminated.
The Registrants have agreements with lease and non-lease components, which are generally accounted for separately. Consideration in a lease is allocated between lease and non-lease components based upon the estimated relative standalone prices. The Registrants have certain coal railcar leases for which non-lease and lease components are accounted for as a single lease component, as permitted under Topic 842.
The following is a summary of the components of lease cost for the years ended December 31:
DTE EnergyDTE Electric
202520242023202520242023
(In millions)
Operating lease cost$23 $26 $22 $17 $22 $17 
Finance lease cost:
Amortization of right-of-use assets4 4 7 3 3 6 
Interest of lease liabilities1 1 — — 1 — 
Total finance lease cost5 5 7 3 4 6 
Variable lease cost17 17 13 1 — — 
Short-term lease cost19 18 12 11 10 4 
$64 $66 $54 $32 $36 $27 
The Registrants have elected not to apply the recognition requirements of Topic 842 to leases with a term of 12 months or less. DTE Energy and DTE Electric record operating, variable, and short-term lease costs as Operating Expenses on the Consolidated Statements of Operations, except for certain amounts that may be capitalized to Property, plant, and equipment and Inventories.
The following is a summary of other information related to leases for the years ended December 31:
DTE EnergyDTE Electric
202520242023202520242023
(In millions)
Supplemental Cash Flows Information
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows for finance leases$5 $9 $9 $3 $7 $7 
Operating cash flows for operating leases$27 $19 $19 $21 $15 $15 
Right-of-use assets obtained in exchange for lease obligations:
Operating leases$95 $75 $61 $86 $74 $61 
Finance leases$— $16 $5 $— $14 $5 
Weighted Average Remaining Lease Term (Years)
Operating leases24.523.318.726.324.819.8
Finance leases6.67.48.93.04.04.5
Weighted Average Discount Rate
Operating leases5.1 %4.8 %4.4 %5.2 %4.9 %4.5 %
Finance leases4.5 %4.6 %4.0 %5.8 %5.8 %5.4 %
The Registrants' future minimum lease payments under leases for remaining periods as of December 31, 2025 are as follows:
DTE EnergyDTE Electric
Operating LeasesFinance LeasesOperating LeasesFinance Leases
(In millions)
2026$37 $5 $31 $3 
202735 4 30 3 
202832 4 28 3 
202921 1 17 — 
203013 1 10 — 
2031 and thereafter400 5 379 — 
Total future minimum lease payments538 20 495 9 
Imputed interest(271)(2)(262)— 
Lease liabilities$267 $18 $233 $9 
Finance leases reported on the Consolidated Statements of Financial Position of the Registrants are as follows for the years ended December 31:
DTE EnergyDTE Electric
2025202420252024
(In millions)
Right-of-use assets, within Property, plant, and equipment, net$18 $23 $9 $12 
Current lease liabilities, within Current portion of long-term debt$4 $5 $3 $4 
Long-term lease liabilities$14 $18 $6 $8 
Lessor
DTE Energy leases various assets under operating leases for a pipeline, energy facilities and related equipment. Such leases are comprised of both fixed payments and variable payments which are contingent on volumes, with terms ranging from 10 to 24 years. Generally, the operating leases do not have renewal provisions or options to purchase the assets at the end of the lease. The operating leases generally do not have termination for convenience provisions. Termination may be allowed under specific circumstances stated in the lease contract, such as under an event of default.
Certain of the finance and operating leases have lease terms that extend to the end of the estimated economic life of the leased assets, thereby resulting in no residual value. Any remaining residual values under the finance and operating leases are expected to be recovered through rates, renewals or new lease contracts. Residual values have been determined using the estimated economic life of the leased assets. The finance and operating leases do not contain residual value guarantees.
Certain of the operating leases have both lease and non-lease components. The lease and non-lease components are allocated based upon estimated relative standalone selling prices.
A lease is deemed to exist when the Registrants have provided other parties with the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration received. The right to control is deemed to occur when the Registrants have provided other parties with the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.
DTE Energy’s lease income associated with operating leases was included on the Consolidated Statements of Operations for the years ended December 31:
202520242023
(In millions)
Fixed payments$15 $15 $15 
Variable payments46 45 44 
$61 $60 $59 
DTE Energy’s minimum future rental revenues under operating leases for remaining periods as of December 31, 2025 are as follows:
DTE Energy
(In millions)
2026$11 
202710 
20286 
20296 
20306 
2031 and thereafter23 
$62 
Depreciation expense associated with DTE Energy's property under operating leases was $8 million, $9 million, and $8 million for the years ended December 31, 2025, 2024, and 2023, respectively.
The following is a summary of property under operating leases for DTE Energy as of December 31:
20252024
(In millions)
Gross property under operating leases$228 $227 
Accumulated amortization of property under operating leases$126 $118 
Leases LEASES
Lessee
Leases at DTE Energy and DTE Electric are primarily comprised of various forms of land easements, coal railcars, buildings, equipment, and computer hardware, leases with terms ranging from approximately 2 to 52 years.
A lease is deemed to exist when the Registrants have the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration paid. The right to control is deemed to occur when the Registrants have the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.
In accordance with ASC Subtopic 980-842, Regulated Operations - Leases, DTE Electric recognizes expense for operating leases using the timing that conforms to the regulatory rate treatment as rental payments are recovered from customers.
Lease liabilities are determined utilizing the discount rate implicit in the lease when it is readily determinable. When the rate implicit in the lease is not readily determinable, the incremental borrowing rate is used. The incremental borrowing rates for DTE Electric and DTE Gas have been determined utilizing respective secured borrowing rates for first mortgage bonds with like tenors of remaining lease terms. Incremental borrowing rates for non-utility entities have been determined utilizing an implied secured borrowing rate based upon an unsecured rate for a similar tenor of remaining lease terms, which is then adjusted for the estimated impact of collateral.
The Registrants have certain leases which contain renewal or purchase options. Where the renewal options were deemed reasonably certain to occur, the impacts of such options were included in the determination of the right of use assets and lease liabilities. The Registrants have determined that it is not reasonably certain that purchase options will be utilized and have not included the impact in the determination of right of use assets and lease liabilities for the subject leases.
Certain leases of the Registrants contain escalation clauses whereby the payments are adjusted for consumer price or labor indices, as well as non-index based escalations for percentage increases. The Registrants also have leases with variable payments based upon the usage of the leased assets.
Certain leases contain provisions whereby the Registrants have the option to terminate the lease agreement by giving notice of such termination during the time frames specified in the respective lease. The Registrants have considered such provisions in the determination of the lease term when it is reasonably certain that the lease would be terminated.
The Registrants have agreements with lease and non-lease components, which are generally accounted for separately. Consideration in a lease is allocated between lease and non-lease components based upon the estimated relative standalone prices. The Registrants have certain coal railcar leases for which non-lease and lease components are accounted for as a single lease component, as permitted under Topic 842.
The following is a summary of the components of lease cost for the years ended December 31:
DTE EnergyDTE Electric
202520242023202520242023
(In millions)
Operating lease cost$23 $26 $22 $17 $22 $17 
Finance lease cost:
Amortization of right-of-use assets4 4 7 3 3 6 
Interest of lease liabilities1 1 — — 1 — 
Total finance lease cost5 5 7 3 4 6 
Variable lease cost17 17 13 1 — — 
Short-term lease cost19 18 12 11 10 4 
$64 $66 $54 $32 $36 $27 
The Registrants have elected not to apply the recognition requirements of Topic 842 to leases with a term of 12 months or less. DTE Energy and DTE Electric record operating, variable, and short-term lease costs as Operating Expenses on the Consolidated Statements of Operations, except for certain amounts that may be capitalized to Property, plant, and equipment and Inventories.
The following is a summary of other information related to leases for the years ended December 31:
DTE EnergyDTE Electric
202520242023202520242023
(In millions)
Supplemental Cash Flows Information
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows for finance leases$5 $9 $9 $3 $7 $7 
Operating cash flows for operating leases$27 $19 $19 $21 $15 $15 
Right-of-use assets obtained in exchange for lease obligations:
Operating leases$95 $75 $61 $86 $74 $61 
Finance leases$— $16 $5 $— $14 $5 
Weighted Average Remaining Lease Term (Years)
Operating leases24.523.318.726.324.819.8
Finance leases6.67.48.93.04.04.5
Weighted Average Discount Rate
Operating leases5.1 %4.8 %4.4 %5.2 %4.9 %4.5 %
Finance leases4.5 %4.6 %4.0 %5.8 %5.8 %5.4 %
The Registrants' future minimum lease payments under leases for remaining periods as of December 31, 2025 are as follows:
DTE EnergyDTE Electric
Operating LeasesFinance LeasesOperating LeasesFinance Leases
(In millions)
2026$37 $5 $31 $3 
202735 4 30 3 
202832 4 28 3 
202921 1 17 — 
203013 1 10 — 
2031 and thereafter400 5 379 — 
Total future minimum lease payments538 20 495 9 
Imputed interest(271)(2)(262)— 
Lease liabilities$267 $18 $233 $9 
Finance leases reported on the Consolidated Statements of Financial Position of the Registrants are as follows for the years ended December 31:
DTE EnergyDTE Electric
2025202420252024
(In millions)
Right-of-use assets, within Property, plant, and equipment, net$18 $23 $9 $12 
Current lease liabilities, within Current portion of long-term debt$4 $5 $3 $4 
Long-term lease liabilities$14 $18 $6 $8 
Lessor
DTE Energy leases various assets under operating leases for a pipeline, energy facilities and related equipment. Such leases are comprised of both fixed payments and variable payments which are contingent on volumes, with terms ranging from 10 to 24 years. Generally, the operating leases do not have renewal provisions or options to purchase the assets at the end of the lease. The operating leases generally do not have termination for convenience provisions. Termination may be allowed under specific circumstances stated in the lease contract, such as under an event of default.
Certain of the finance and operating leases have lease terms that extend to the end of the estimated economic life of the leased assets, thereby resulting in no residual value. Any remaining residual values under the finance and operating leases are expected to be recovered through rates, renewals or new lease contracts. Residual values have been determined using the estimated economic life of the leased assets. The finance and operating leases do not contain residual value guarantees.
Certain of the operating leases have both lease and non-lease components. The lease and non-lease components are allocated based upon estimated relative standalone selling prices.
A lease is deemed to exist when the Registrants have provided other parties with the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration received. The right to control is deemed to occur when the Registrants have provided other parties with the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.
DTE Energy’s lease income associated with operating leases was included on the Consolidated Statements of Operations for the years ended December 31:
202520242023
(In millions)
Fixed payments$15 $15 $15 
Variable payments46 45 44 
$61 $60 $59 
DTE Energy’s minimum future rental revenues under operating leases for remaining periods as of December 31, 2025 are as follows:
DTE Energy
(In millions)
2026$11 
202710 
20286 
20296 
20306 
2031 and thereafter23 
$62 
Depreciation expense associated with DTE Energy's property under operating leases was $8 million, $9 million, and $8 million for the years ended December 31, 2025, 2024, and 2023, respectively.
The following is a summary of property under operating leases for DTE Energy as of December 31:
20252024
(In millions)
Gross property under operating leases$228 $227 
Accumulated amortization of property under operating leases$126 $118 
v3.25.4
Commitments and Contingencies
 12 Months Ended
Dec. 31, 2025
Commitments and Contingencies Disclosure [Abstract]  
Commitments and Contingencies COMMITMENTS AND CONTINGENCIES
Environmental
DTE Electric
Air — DTE Electric is subject to the EPA ozone and fine particulate transport and acid rain regulations that limit power plant emissions of SO2 and NOX. The EPA and the state of Michigan have also issued emission reduction regulations relating to ozone, fine particulate, regional haze, mercury, and other air pollution. These rules have led to controls on fossil-fueled power plants to reduce SO2, NOX, mercury, and other emissions. Additional rule making may occur over the next few years which could require additional controls for SO2, NOX, and other hazardous air pollutants.
In March 2024, the EPA finalized the NAAQS for fine particulate matter, particles of pollution with diameters generally 2.5 micrometers and smaller (PM2.5). It is likely that areas of Michigan in which DTE Electric operates will be designated as non-attainment in the future, and the state will be required to develop a SIP for such areas. However, the EPA has announced its intention to review the standard. No impact is expected in the near term, and any long-term financial impacts cannot be assessed at this time.
In April 2024, the EPA finalized new rules to address emissions of GHGs from existing, new, modified, or reconstructed sources in the power sector. In June 2025, the EPA proposed a rule to repeal the GHG standards along with an alternative to eliminate various portions of the standards. The EPA intends to finalize the repeal or alternative in early 2026. The financial impacts of the new rules are still being assessed.
Pending or future legislation or other regulatory actions could have a material impact on DTE Electric's operations and financial position and the rates charged to its customers. Potential impacts include expenditures for environmental equipment beyond what is currently planned, financing costs related to additional capital expenditures, the purchase of emission credits from market sources, higher costs of purchased power, and the retirement of facilities where control equipment is not economical. DTE Electric would seek to recover these incremental costs through increased rates charged to its utility customers, as authorized by the MPSC.
To comply with air pollution requirements, DTE Electric has spent approximately $2.4 billion. DTE Electric does not anticipate additional capital expenditures for air pollution requirements, subject to the results of future rulemakings.
Water — In response to EPA regulations and in accordance with the Clean Water Act section 316(b), DTE Electric was required to examine alternatives for reducing the environmental impacts of the cooling water intake structures at several of its facilities. A final rule became effective in October 2014, which required studies to be completed and submitted as part of the NPDES permit application process to determine the type of technology needed to reduce impacts to fish. DTE Electric has completed the required studies and submitted reports for most of its generation plants, and a final study was submitted to EGLE in April 2025 for the Monroe power plant. Final compliance for the installation of any required technology to reduce the impacts of water intake structures will be determined by the state on a case by case, site specific basis.
As part of the Monroe power plant NPDES permit, EGLE has added an option to evaluate the thermal discharge of the facility as it relates to Clean Water Act section 316(a) regulations in order to establish an appropriate temperature discharge limit. DTE Electric has submitted to EGLE a biological demonstration study plan to evaluate the thermal discharge impacts to an aquatic community. EGLE approved the plan in May 2025. Field sampling has commenced, and data will be processed and compiled into a comprehensive report. At the present time, DTE Electric cannot predict the outcome of this evaluation or financial impact.
Contaminated and Other Sites — Prior to the construction of major interstate natural gas pipelines, gas for heating and other uses was manufactured locally from processes involving coal, coke, or oil. The facilities, which produced gas, have been designated as MGP sites. DTE Electric conducted remedial investigations at contaminated sites, including three former MGP sites. The investigations at the former MGP sites have revealed contamination related to the by-products of gas manufacturing. Cleanup of one of the MGP sites is complete, and that site is closed. DTE Electric has also completed partial closure of one additional site. Cleanup activities associated with the remaining sites will continue over the next several years. In addition to the MGP sites, DTE Electric is also in the process of cleaning up other contaminated sites, including the area surrounding an ash landfill, electrical distribution substations, electric generating power plants, and underground and above ground storage tank locations. The findings of these investigations indicated that the estimated cost to remediate these sites is expected to be incurred over the next several years. At December 31, 2025 and 2024, DTE Electric had $10 million accrued for remediation. These costs are not discounted to their present value. Any change in assumptions, such as remediation techniques, nature and extent of contamination, and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect DTE Electric’s financial position and cash flows. DTE Electric believes the likelihood of a material change to the accrued amount is remote based on current knowledge of the conditions at each site.
Coal Combustion Residuals and Effluent Limitations Guidelines — A final EPA rule for the disposal of coal combustion residuals, commonly known as coal ash, became effective in October 2015 and has continued to be updated in subsequent years. The rule is based on the continued listing of coal ash as a non-hazardous waste and relies on various self-implementation design and performance standards. DTE Electric currently owns and operates multiple coal ash storage facilities to manage coal ash from coal-fired power plants that are subject to federal, state, and local CCR and solid waste regulations. At certain facilities, the rule required ongoing sampling and testing of monitoring wells, compliance with groundwater standards, and closure.
On May 8, 2024, the EPA finalized a new rule to regulate legacy CCR surface impoundments and CCR management units. The rule expands the reach of the CCR rule to inactive electric generation sites and previously unregulated CCR at any active facility. The rule also extends the dewatering and stabilization criteria of the closure in place performance standards to existing CCR landfills. DTE Electric has no legacy CCR surface impoundments, but has other regulated CCR units and is evaluating sites for CCR management units. DTE Electric continues to evaluate the final 2024 rule, which may have significant financial impacts depending on the site-specific characteristics of the units that are regulated by the new rule. Long-term financial impacts cannot be clearly defined at this time and likely will not be clearly defined until the regulated units are identified and fully characterized. Challenges to the rule have been filed, and DTE Electric will continue to monitor for regulatory developments. Recently, at the request of the EPA, the D.C. Circuit Court has held the pending litigation in abeyance to accommodate the EPA's reconsideration of the rule. The EPA recently announced their desire to revise the CCR regulations, but at this time the effective date and extent of any revisions are unknown. The current cost estimate to comply with the revised rule is approximately $430 million as of December 31, 2025, and is recorded to Asset retirement obligations. The estimate was increased by $130 million in the third quarter of 2025 based on findings from more thorough site investigations. The estimate will continue to be updated as necessary when site-specific details are more fully known. These costs are expected to be recoverable under the regulatory construct as part of removal costs.
At the state level, legislation was signed in December 2018 and provides for further regulation of the CCR program in Michigan. Additionally, the statutory revision provides the basis of a CCR program that EGLE has submitted to the EPA for approval to fully regulate the CCR program in Michigan in lieu of a federal permit program. The EPA is currently working with EGLE in reviewing the submitted state program, and DTE Electric will work with EGLE to implement the state program that may be approved in the future.
The EPA updated and revised the ELG in 2015, 2020, and 2024. In each revision, EPA has re-established technology-based standards applicable to wastewaters created at facilities with an electrical generating unit. In each revision, the EPA also established new applicability dates.
The Reconsideration Rule, finalized in 2020, provided additional opportunities by finalizing a group of compliance subcategories that provided cessation of coal as a compliance option. Additionally, the 2020 Reconsideration Rule established the Voluntary Incentives Program (VIP) for FGD wastewater compliance only. If a facility applies for the VIP, they must meet more stringent standards, but are allowed an extended time period to meet the compliance requirements by December 1, 2028. The Reconsideration Rule provided these new opportunities for DTE Electric to evaluate existing ELG compliance strategies and make any necessary adjustments to ensure full compliance with the ELGs in a cost-effective manner.
Compliance schedules for individual facilities and individual waste streams are determined through issuance of new NPDES permits by the state of Michigan. The state of Michigan issued an NPDES permit for the Belle River power plant establishing compliance deadlines based on the 2020 Reconsideration Rule. On October 11, 2021, DTE Electric submitted a Notice of Planned Participation (NOPP) to the state of Michigan that formally announced the intent to pursue compliance subcategories as ELG compliance options: the cessation of coal at the Belle River power plant no later than December 31, 2028 and the VIP for FGD wastewater at Monroe power plant by December 31, 2028.
The EPA also finalized Supplemental ELG Rules on May 9, 2024. This updated the regulations from the 2020 Reconsideration Rule for FGD wastewater, bottom ash transport water (BATW), combustion residual leachate (CRL), and legacy wastewater (LWW). The supplemental rule established new technology-based effluent limitations guidelines and standards applicable to FGD wastewater, BATW, CRL, and LWW. The applicability date for BATW is as soon as possible beginning July 8, 2024 and no later than December 31, 2029. FGD wastewater retrofits must be completed as soon as possible, beginning July 8, 2024 and no later than December, 31 2029 or December 31, 2028 if a permittee is pursuing the VIP subcategory for FGD wastewater. The Cessation of Coal compliance subcategory and VIP from the 2020 Reconsideration Rule were maintained in the 2024 Supplemental Rule and continue to be a fundamental component of DTE Electric's ELG compliance strategy. The EPA recently announced that they will be reviewing and possibly revising the 2024 Supplemental ELG Rule. At this time, DTE Electric cannot predict effective dates for any revisions or their financial impacts.
DTE Electric's compliance strategy includes the conversion of the two generating units at the Belle River power plant to a natural gas peaking resource, expected to be complete in 2026, which was included in the NOPP filed in 2021. DTE Electric also submitted a new NOPP to apply for the cessation of coal compliance subcategory for generating units 3 and 4 at the Monroe power plant. DTE Electric plans to retire Monroe's generating units 1 and 2 in 2032.
DTE Electric continues to evaluate compliance strategies, technologies and system designs to achieve compliance with the EPA rules at the Monroe power plant in accordance with the VIP subcategory for FGD and met new discharge requirements for BATW as of December 31, 2025 for Monroe's generating units 1 and 2. Additionally, DTE Electric is evaluating compliance strategies and options to address new requirement and deadlines for other wastewater streams in the 2024 Supplemental Rule at both Belle River Power Plant and Sibley Quarry.
DTE Electric currently estimates the impact of the CCR and ELG rules to be $424 million of capital expenditures through 2030. This estimate may change in future periods as DTE Electric evaluates the CCR and ELG rules discussed above that have recently been finalized.
DTE Gas
Contaminated and Other Sites — DTE Gas owns or previously owned 14 former MGP sites. Investigations have revealed contamination related to the by-products of gas manufacturing at each site. Cleanup of eight MGP sites is complete and those sites are closed. DTE Gas has also completed partial closure of five additional sites. Cleanup activities associated with the remaining sites will continue over the next several years. The MPSC has established a cost deferral and rate recovery mechanism for investigation and remediation costs incurred at former MGP sites. In addition to the MGP sites, DTE Gas is also in the process of cleaning up other contaminated sites, including gate stations, gas pipeline releases, and underground storage tank locations. As of December 31, 2025 and 2024, DTE Gas had $25 million and $26 million, respectively, accrued for remediation. These costs are not discounted to their present value. Any change in assumptions, such as remediation techniques, nature and extent of contamination, and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect DTE Gas' financial position and cash flows. DTE Gas anticipates the cost amortization methodology approved by the MPSC, which allows for amortization of the MGP costs over a ten-year period beginning with the year subsequent to the year the MGP costs were incurred, will prevent the associated investigation and remediation costs from having a material adverse impact on DTE Gas' results of operations.
Air — In March 2023, the EPA published the Good Neighbor Rule, which includes provisions for compressor engines operated for the transportation of natural gas. In June 2024, the United States Supreme Court issued an opinion granting emergency applications to stay the Good Neighbor Rule. The stay will remain in effect during other litigation. The status of the rule remains uncertain as litigation is ongoing. At this time, DTE Gas does not expect a significant financial impact.
As noted above for DTE Electric, the EPA finalized the NAAQS for fine particulate matter in March 2024. It is likely that areas of Michigan in which DTE Gas operates will be designated as non-attainment in the future and the state will be required to develop a SIP for such areas. However, the EPA has announced its intention to review the standard. No impact is expected in the near term, and any long-term financial impacts cannot be assessed at this time.
Non-utility
DTE Energy's non-utility businesses are subject to a number of environmental laws and regulations dealing with the protection of the environment from various pollutants.
In March 2019, the EPA issued an FOV to EES Coke Battery, LLC ("EES Coke"), the Michigan coke battery facility that is a wholly-owned subsidiary of DTE Energy, alleging that the 2008 and 2014 permits issued by EGLE did not comply with the Clean Air Act. In September 2020, the EPA issued another FOV alleging EES Coke's 2018 and 2019 SO2 emissions exceeded projections and hence violated non-attainment new source review permitting requirements. EES Coke evaluated the EPA's alleged violations and believes that the permits approved by EGLE complied with the Clean Air Act. EES Coke responded to the EPA's September 2020 allegations demonstrating its actual emissions are compliant with non-attainment new source review requirements. On June 1, 2022, the U.S. Department of Justice ("DOJ"), on behalf of the EPA, filed a complaint against EES Coke in the U.S. District Court for the Eastern District of Michigan alleging that EES Coke failed to comply with non-attainment new source review requirements under the Clean Air Act when it applied for the 2014 permit. In November 2022, the Sierra Club and City of River Rouge were granted intervention. On May 20, 2024, the court granted a motion allowing the DOJ to amend their complaint to add EES Coke's parent entities, including DTE Energy, as defendants. The parent entities were added in an attempt to share in any potential liability; there are no additional claims alleged. The EPA filed a motion for partial summary judgment on liability that was granted by the trial court on August 25, 2025. EES Coke sought certification for an interlocutory appeal to the Sixth Circuit Court of Appeals, which was denied on September 12, 2025. Trial was held on remedies and parent liability, and concluded on September 29, 2025. Final briefs were submitted in the case on December 5, 2025. DTE Energy has accrued $8 million as our best estimate of penalties as of December 31, 2025. At the present time, DTE Energy cannot predict the final outcome or financial impact of this matter.
Other
In 2010, the EPA finalized a new one-hour SO2 ambient air quality standard that requires states to submit plans and associated timelines for non-attainment areas that demonstrate attainment with the new SO2 standard in phases. Phase 1 addresses non-attainment areas designated based on ambient monitoring data. Phase 2 addresses non-attainment areas with large sources of SO2 and modeled concentrations exceeding the National Ambient Air Quality Standards for SO2. Phase 3 addresses smaller sources of SO2 with modeled or monitored exceedances of the new SO2 standard.
Michigan's Phase 1 non-attainment area included DTE Energy facilities. However, the EPA published a Federal Implementation Plan (FIP) for the area in June 2022 that did not impact any DTE Energy facilities. It is also not expected that Phase 3 will have any impact on DTE Energy.
Michigan's Phase 2 non-attainment area includes DTE Electric facilities in St. Clair County. The EPA approved a clean data determination request submitted by EGLE. This determination suspends certain planning requirements and sanctions for the non-attainment area for as long as the area continues to attain the 2010 SO2 air quality standards, but this does not automatically redesignate the area to attainment. Until the area is officially redesignated as attainment, DTE Energy is unable to determine the impacts.
REF Guarantees
DTE Energy provided certain guarantees and indemnities in conjunction with the sales of interests in or lease of its previously operated REF facilities. The guarantees cover potential commercial, environmental, and tax-related obligations that will survive until 90 days after expiration of all applicable statutes of limitations. DTE Energy estimates that its maximum potential liability under these guarantees at December 31, 2025 was $201 million. Payments under these guarantees are considered remote.
Other Guarantees
In certain limited circumstances, the Registrants enter into contractual guarantees. The Registrants may guarantee another entity’s obligation in the event it fails to perform and may provide guarantees in certain indemnification agreements. The Registrants may also provide indirect guarantees for the indebtedness of others. DTE Energy’s guarantees are not individually material with maximum potential payments totaling $69 million at December 31, 2025. Payments under these guarantees are considered remote.
The Registrants are periodically required to obtain performance surety bonds in support of obligations to various governmental entities and other companies in connection with its operations. As of December 31, 2025, DTE Energy had $383 million of performance bonds outstanding, including $248 million for DTE Electric. Performance bonds are not individually material, except for $91 million of bonds supporting Energy Trading operations. These bonds are meant to provide counterparties with additional assurance that Energy Trading will meet its contractual obligations for various commercial transactions. The terms of the bonds align with those of the underlying Energy Trading contracts and are estimated to be outstanding approximately 1 to 3 years. In the event that any performance bonds are called for nonperformance, the Registrants would be obligated to reimburse the issuer of the performance bond. The Registrants are released from the performance bonds as the contractual performance is completed and does not believe that a material amount of any currently outstanding performance bonds will be called.
Labor Contracts
There are several bargaining units for DTE Energy subsidiaries' approximately 4,850 represented employees, including DTE Electric's approximately 2,600 represented employees. This represents 50% and 58% of DTE Energy's and DTE Electric's total employees, respectively. Of these represented employees, approximately 16% have contracts expiring within one year for DTE Energy. Approximately 22% of the represented employees have contracts expiring within one year for DTE Electric.
Purchase Commitments
As of December 31, 2025, the Registrants were party to numerous long-term purchase commitments relating to a variety of goods and services required for their businesses. These agreements primarily consist of fuel supply commitments and renewable energy contracts for the Registrants, as well as energy trading contracts for DTE Energy. The Registrants estimate the following commitments from 2026 through 2057, as detailed in the following tables:
202620272028202920302031 and ThereafterTotal
DTE Energy(In millions)
Long-term power purchase agreements(a)
$116 $128 $151 $151 $151 $1,699 $2,396 
Other purchase commitments(b)
3,506 1,441 529 266 249 701 6,692 
Total commitments$3,622 $1,569 $680 $417 $400 $2,400 $9,088 
202620272028202920302031 and ThereafterTotal
DTE Electric(In millions)
Long-term power purchase agreements(a)
$122 $133 $156 $153 $153 $1,704 $2,421 
Other purchase commitments(b)
602 411 147 34 13 117 1,324 
Total commitments$724 $544 $303 $187 $166 $1,821 $3,745 
_______________________________________
(a)The agreements represent the minimum obligations with suppliers for renewable energy and renewable energy credits under existing contract terms which expire from 2030 through 2055. DTE Electric's share of plant output ranges from 28% to 100%. Purchase commitments for DTE Electric include affiliate agreements with DTE Sustainable Generation that are eliminated in consolidation for DTE Energy.
(b)Excludes amounts associated with full requirements contracts where no stated minimum purchase volume is required.
Utility capital expenditures and expenditures for non-utility businesses will be approximately $6.8 billion and $5.2 billion in 2026 for DTE Energy and DTE Electric, respectively. The Registrants have made certain commitments in connection with the estimated 2026 annual capital expenditures.
Ludington Plant Contract Dispute
DTE Electric and Consumers Energy Company ("Consumers"), joint owners of the Ludington Hydroelectric Pumped Storage plant ("Ludington"), entered into a 2010 engineering, procurement, and construction agreement with Toshiba International Corporation ("TIC"), under which TIC contracted to perform a major overhaul and upgrade of Ludington. TIC later assigned the contract and all of its obligations to Toshiba America Energy Systems ("TAES"). TAES' work under the contract was incomplete, defective, and non-conforming. DTE Electric and Consumers repeatedly documented TAES' failures to perform under the contract and demanded that TAES provide a comprehensive plan to resolve those matters, including adherence to its warranty commitments and other contractual obligations. DTE Electric and Consumers engaged in extensive efforts to resolve these issues with TAES, including a formal demand to TAES' parent, Toshiba Corporation ("Toshiba"), under a parent guaranty it provided. TAES did not provide a comprehensive plan or otherwise meet its performance obligations. As a result of TAES' defaults, DTE Electric and Consumers terminated the contract.
In order to enforce their rights under the contract and parent guaranty, and to pursue appropriate damages, DTE Electric and Consumers filed a complaint against TAES and Toshiba in the U.S. District Court for the Eastern District of Michigan in 2022. TAES and Toshiba filed a motion to dismiss the complaint, along with an answer and counterclaims seeking approximately $15 million in damages related to payments allegedly owed under the parties' contract. The motion to dismiss the complaint was denied. The case against TAES went to trial before a jury and in December 2025, a jury returned a verdict in DTE Electric and Consumers' favor finding TAES breached its warranties and other contractual duties in overhauling Ludington. The jury awarded damages for TAES’s breaches of contract, as well as liquidated damages for late completion of work. The jury rejected TAES' affirmative defenses and counterclaim. TAES is pursuing post judgment relief by filing motions for appeal. DTE Electric cannot predict the financial impact or outcome of this matter.
In 2023, the MPSC approved a jointly-filed request by DTE Electric and Consumers for authority to defer as a regulatory asset the costs associated with repairing or replacing the defective work performed by TAES while the litigation with TAES and Toshiba moves forward. DTE Electric currently estimates its share of these repair and replacement costs ranges from $350 million to $400 million. Such costs will be offset by any potential litigation proceeds received from TAES or Toshiba. DTE Electric and Consumers will have the opportunity to seek recovery and ratemaking treatment for amounts recorded as a regulatory asset following resolution of the litigation, including amounts not recovered from TAES or Toshiba.
Other Contingencies
The Registrants are involved in certain other legal, regulatory, administrative, and environmental proceedings before various courts, arbitration panels, and governmental agencies concerning claims arising in the ordinary course of business. These proceedings include certain contract disputes, additional environmental reviews and investigations, audits, inquiries from various regulators, and pending judicial matters. The Registrants cannot predict the final disposition of such proceedings. The Registrants regularly review legal matters and record provisions for claims that they can estimate and are considered probable of loss. The resolution of these pending proceedings is not expected to have a material effect on the Registrants' Consolidated Financial Statements in the periods they are resolved.
For a discussion of contingencies related to regulatory matters and derivatives, see Notes 9 and 13 to the Consolidated Financial Statements, "Regulatory Matters" and "Financial and Other Derivative Instruments," respectively.
v3.25.4
Nuclear Operations
 12 Months Ended
Dec. 31, 2025
Nuclear Operations [Abstract]  
Nuclear Operations NUCLEAR OPERATIONS
Property Insurance
DTE Electric maintains property insurance policies specifically for the Fermi 2 plant. These policies cover such items as replacement power and property damage. NEIL is the primary supplier of the insurance policies.
DTE Electric maintains a policy for extra expenses, including replacement power costs necessitated by Fermi 2’s unavailability due to an insured event. This policy has a 12-week waiting period and provides an aggregate $490 million of coverage over a three-year period.
DTE Electric has $1.5 billion in primary coverage and $1.25 billion of excess coverage for stabilization, decontamination, debris removal, repair and/or replacement of property, and decommissioning. The combined coverage limit for total property damage is $2.75 billion. The total limit for property damage for non-nuclear events is $1.8 billion and an aggregate of $291 million of coverage for extra expenses over a two-year period.
On December 20, 2019, the Terrorism Risk Insurance Program Reauthorization Act of 2019 was signed, extending TRIA through December 31, 2027. For multiple terrorism losses caused by acts of terrorism not covered under the TRIA occurring within one year after the first loss from terrorism, the NEIL policies would make available to all insured entities up to $3.2 billion, plus any amounts recovered from reinsurance, government indemnity, or other sources to cover losses.
Under NEIL policies, DTE Electric could be liable for maximum assessments of up to $39 million per event if the loss associated with any one event at any nuclear plant should exceed the accumulated funds available to NEIL.
Public Liability Insurance
As required by federal law, DTE Electric maintains $500 million of public liability insurance for a nuclear incident. Further, under the Price-Anderson Amendments Act of 2005, deferred premium charges up to $166 million could be levied against each licensed nuclear reactor, but not more than $25 million per year per reactor. Thus, deferred premium charges could be levied against all owners of licensed nuclear reactors in the event of a nuclear incident at any of these facilities.
Nuclear Fuel Disposal Costs
In accordance with the Federal Nuclear Waste Policy Act of 1982, DTE Electric has a contract with the DOE for the future storage and disposal of spent nuclear fuel from Fermi 2 that required DTE Electric to pay the DOE a fee of 1 mill per kWh of Fermi 2 electricity generated and sold. The fee was a component of nuclear fuel expense. The 1 mill per kWh DOE fee was reduced to zero effective May 16, 2014.
The DOE's Yucca Mountain Nuclear Waste Repository program for the acceptance and disposal of spent nuclear fuel was terminated in 2011. DTE Electric is a party in the litigation against the DOE for both past and future costs associated with the DOE's failure to accept spent nuclear fuel under the timetable set forth in the Federal Nuclear Waste Policy Act of 1982. In July 2012, DTE Electric executed a settlement agreement with the federal government for costs associated with the DOE's delay in acceptance of spent nuclear fuel from Fermi 2 for permanent storage. The settlement agreement, including extensions, has provided for a claims process and payment of delay-related costs experienced by DTE Electric through 2025. DTE Electric's claims are being settled and paid on a timely basis. The settlement proceeds reduce the cost of the dry cask storage facility assets and provide reimbursement for related operating expenses.
DTE Electric currently employs a spent nuclear fuel storage strategy utilizing a fuel pool and a dry cask storage facility. The spent nuclear fuel storage strategy is expected to provide sufficient spent fuel storage capability for the life of the plant as defined by DTE Electric's operating license agreement.
The federal government continues to maintain its legal obligation to accept spent nuclear fuel from Fermi 2 for permanent storage. Issues relating to long-term waste disposal policy and to the disposition of funds contributed by DTE Electric ratepayers to the federal waste fund await future governmental action.
v3.25.4
Retirement Benefits and Trusteed Assets
 12 Months Ended
Dec. 31, 2025
Retirement Benefits [Abstract]  
Retirement Benefits and Trusteed Assets RETIREMENT BENEFITS AND TRUSTEED ASSETS
DTE Energy's subsidiary, DTE Energy Corporate Services, LLC, sponsors defined benefit pension plans and other postretirement benefit plans covering certain employees of the Registrants. Plan participants of all plans are solely DTE Energy and affiliate participants.
The table below represents the pension and other postretirement benefit plans of each Registrant at December 31, 2025:
Registrants
DTE EnergyDTE Electric
Qualified Pension Plans
DTE Energy Company Retirement PlanXX
DTE Gas Company Retirement Plan for Employees Covered by Collective Bargaining AgreementsX
Shenango Inc. Pension Plan(a)
X
Non-qualified Pension Plans
DTE Energy Company Supplemental Retirement Plan(b)
XX
DTE Energy Company Executive Supplemental Retirement Plan(b)
XX
DTE Energy Company Supplemental Severance Benefit PlanX
Other Postretirement Benefit Plans
The DTE Energy Company Comprehensive Non-Health Welfare PlanXX
The DTE Energy Company Comprehensive Retiree Group Health Care PlanXX
DTE Supplemental Retiree Benefit PlanXX
DTE Energy Company Retiree Reimbursement Arrangement PlanXX
_____________________________________
(a)Sponsored by Shenango, LLC
(b)Sponsored by DTE Energy Company
DTE Electric participates in various plans that provide pension and other postretirement benefits for DTE Energy and its affiliates. The plans are primarily sponsored by the LLC. DTE Electric accounts for its participation in DTE Energy's qualified and non-qualified pension plans by applying multiemployer accounting. DTE Electric accounts for its participation in other postretirement benefit plans by applying multiple-employer accounting. Within multiemployer and multiple-employer plans, participants pool plan assets for investment purposes and to reduce the cost of plan administration. The primary difference between plan types is that assets contributed in multiemployer plans can be used to provide benefits for all participating employers, while assets contributed within a multiple-employer plan are restricted for use by the contributing employer.
As a result of multiemployer accounting treatment, capitalized costs associated with these plans are reflected in Property, plant, and equipment in DTE Electric's Consolidated Statements of Financial Position. The same capitalized costs are reflected as Regulatory assets and liabilities in DTE Energy's Consolidated Statements of Financial Position. For non-qualified plans, non-service costs recognized in earnings, these costs have historically been presented in Other (Income) and Deductions — Non-operating retirement benefits, net in DTE Energy's Consolidated Statements of Operations and Operation and maintenance in the DTE Electric Consolidated Statements of Operations.
Pension Plan Benefits
DTE Energy has qualified defined benefit retirement plans for eligible represented and non-represented employees. The plans are noncontributory and provide traditional retirement benefits based on the employee's years of benefit service, average final compensation, and age at retirement. In addition, certain represented and non-represented employees are covered under cash balance provisions that determine benefits on annual employer contributions and interest credits. DTE Energy also maintains supplemental non-qualified, noncontributory, retirement benefit plans for certain management employees. These plans provide for benefits that supplement those provided by DTE Energy’s other retirement plans.
Net pension cost (credit) for DTE Energy includes the following components:
Year Ended December 31,
202520242023
(In millions)
Service cost$49 $58 $57 
Interest cost216 208 214 
Expected return on plan assets(291)(341)(352)
Amortization of:
Net actuarial loss87 59 7 
Prior service credit(1)(2)(2)
Settlements— — 7 
Net pension cost (credit)$60 $(18)$(69)
December 31,
20252024
(In millions)
Other changes in plan assets and benefit obligations recognized in Regulatory assets and Other comprehensive income (loss)
Net actuarial (gain) loss$58 $(49)
Amortization of net actuarial loss and settlements(87)(59)
Amortization of prior service credit1 2 
Total recognized in Regulatory assets and Other comprehensive income (loss)$(28)$(106)
Total recognized in net periodic pension credit, Regulatory assets, and Other comprehensive income (loss)$32 $(124)
The following table reconciles the obligations, assets, and funded status of the plans as well as the amounts recognized as a pension liability in DTE Energy's Consolidated Statements of Financial Position at December 31:
DTE Energy
20252024
(In millions)
Accumulated benefit obligation, end of year$3,851 $3,803 
Change in projected benefit obligation
Projected benefit obligation, beginning of year$3,982 $4,318 
Service cost49 58 
Interest cost216 208 
Actuarial (gain) loss111 (254)
Benefits paid(315)(348)
Projected benefit obligation, end of year$4,043 $3,982 
Change in plan assets
Plan assets at fair value, beginning of year$3,758 $3,960 
Actual return on plan assets343 137 
Company contributions9 9 
Benefits paid(315)(348)
Plan assets at fair value, end of year$3,795 $3,758 
Funded status$(248)$(224)
Amount recorded as:
Current liabilities$(13)$(10)
Noncurrent liabilities(235)(214)
$(248)$(224)
Amounts recognized in Accumulated other comprehensive income, pre-tax
Net actuarial loss$82 $76 
$82 $76 
Amounts recognized in Regulatory assets(a)
Net actuarial loss$1,283 $1,318 
Prior service credit(2)(3)
$1,281 $1,315 
______________________________________
(a)See Note 9 to the Consolidated Financial Statements, "Regulatory Matters."
The increase in the pension benefit obligation for the year ended December 31, 2025, was primarily due to an actuarial loss driven by a decrease in discount rates. The decrease in DTE Energy's pension benefit obligation in 2024 was primarily due to an actuarial gain driven by an increase in discount rates.
The Registrants’ policy is to fund pension costs by contributing amounts consistent with the provisions of the Pension Protection Act of 2006, and additional amounts when it deems appropriate. In 2025 and 2024, DTE Energy made a nominal contribution to the qualified pension plans. In 2025 and 2023, DTE Gas transferred $25 million and $50 million, respectively, of qualified pension plan funds to DTE Electric in exchange for cash consideration. In addition, DTE Energy anticipates a transfer of up to $25 million of non-represented qualified pension plan funds from DTE Gas to DTE Electric in 2026, subject to management discretion and any changes in financial market conditions.
DTE Energy's subsidiaries are responsible for their share of qualified and non-qualified pension benefit costs. DTE Electric's allocated portion of pension benefit costs included in regulatory assets and liabilities, operation and maintenance expense and capital expenditures were a cost of $53 million for the year ended December 31, 2025 and credits of $5 million, and $39 million for the years ended December 31, 2024, and 2023, respectively. These amounts may include recognized contractual termination benefit charges, curtailment gains, and settlement charges.
At December 31, 2025, the benefits related to DTE Energy's qualified and non-qualified pension plans expected to be paid in each of the next five years and in the aggregate for the five fiscal years thereafter are as follows:
(In millions)
2026$326 
2027326 
2028330 
2029326 
2030321 
2031-20351,599 
Total$3,228 
Assumptions used in determining the projected benefit obligation and net pension costs of DTE Energy for the years ended December 31, 2025, 2024, and 2023 are:
202520242023
Projected benefit obligation
Discount rate5.43%5.65%5.00%
Rate of compensation increase3.55%3.55%3.80%
Cash balance interest crediting rate3.60%4.50%3.60%
Net pension costs
Discount rate5.65%5.00%5.19%
Rate of compensation increase3.55%3.80%3.80%
Expected long-term rate of return on plan assets7.80%8.00%7.60%
Cash balance interest crediting rate4.50%3.60%3.40%
DTE Energy employs a formal process in determining the long-term rate of return for various asset classes. Management reviews historic financial market risks and returns and long-term historic relationships between the asset classes of equities, fixed income, and other assets, consistent with the widely accepted capital market principle that asset classes with higher volatility generate a greater return over the long-term. Current market factors such as inflation, interest rates, asset class risks, and asset class returns are evaluated and considered before long-term capital market assumptions are determined. The long-term portfolio return is also established employing a consistent formal process, with due consideration of diversification, active investment management, and rebalancing. Peer data is reviewed to check for reasonableness. As a result of this process, the Registrants have a long-term rate of return assumption for the pension plans of 7.80% for 2026. The Registrants believe this rate is a reasonable assumption for the long-term rate of return on plan assets given the current investment strategy.
The DTE Energy Company Affiliates Employee Benefit Plans Master Trust employs a liability driven investment program whereby the characteristics of plan liabilities are considered when determining investment policy. Risk tolerance is established through consideration of future plan cash flows, plan funded status, and corporate financial considerations. The investment portfolio contains a diversified blend of equity, fixed income, and other investments. Furthermore, equity investments are diversified across U.S. and non-U.S. stocks and large and small market capitalizations. Fixed income investments generally include U.S. Treasuries, other governmental debt, diversified corporate bonds, bank loans, and mortgage-backed securities. Other investments are used to enhance long-term returns while improving portfolio diversification. Derivatives may be utilized in a risk controlled manner, to potentially increase the portfolio beyond the market value of invested assets and/or reduce portfolio investment risk. Investment risk is measured and monitored on an ongoing basis through annual liability measurements, periodic asset/liability studies, and quarterly investment portfolio reviews.
Target allocations for DTE Energy's pension plan assets as of December 31, 2025 are listed below:
U.S. Large Capitalization (Cap) Equity Securities8 %
U.S. Small Cap and Mid Cap Equity Securities1 
Non-U.S. Equity Securities6 
Fixed Income Securities57 
Hedge Funds and Similar Investments8 
Private Equity and Other20 
100 %
The following table provides the fair value measurement amounts for DTE Energy's pension plan assets at December 31, 2025 and 2024(a):
December 31, 2025December 31, 2024
Level 1Level 2
Other(b)
TotalLevel 1Level 2
Other(b)
Total
DTE Energy asset category:(In millions)
Short-term Investments(c)
$83 $— $— $83 $97 $— $— $97 
Equity Securities
Domestic(d)
— — 343 343 — — 349 349 
International(e)
34 — 209 243 35 — 188 223 
Fixed Income Securities
Governmental(f)
537 81 — 618 627 76 — 703 
Corporate(g)
— 1,504 — 1,504 — 1,350 — 1,350 
Hedge Funds and Similar Investments(h)
138 14 172 324 137 14 167 318 
Private Equity and Other(i)
— — 680 680 — — 718 718 
DTE Energy Total$792 $1,599 $1,404 $3,795 $896 $1,440 $1,422 $3,758 
_______________________________________
(a)For a description of levels within the fair value hierarchy, see Note 12 to the Consolidated Financial Statements, "Fair Value."
(b)Amounts represent assets valued at NAV as a practical expedient for fair value.
(c)This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category is obtained from quoted prices in actively traded markets.
(d)This category represents portfolios of large, medium and small capitalization domestic equities. Investments in this category include exchange-traded securities held in a commingled fund classified as NAV assets.
(e)This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category include exchange-traded securities for which unadjusted quoted prices can be obtained and exchange-traded securities held in a commingled fund classified as NAV assets.
(f)This category includes U.S. Treasuries, bonds, and other governmental debt. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services.
(g)This category primarily consists of corporate bonds from diversified industries, bank loans, and mortgage-backed securities. Pricing for investments in this category is obtained from quotations from broker or pricing services.
(h)This category utilizes a diversified group of strategies that attempt to capture uncorrelated sources of return and includes publicly traded mutual funds, insurance-linked and asset-backed securities, commingled funds and limited partnership funds. Pricing for mutual funds in this category is obtained from quoted prices in actively traded markets. Pricing for insurance-linked and asset-backed securities is obtained from quotations from broker or pricing services. Commingled funds and limited partnership funds are classified as NAV assets.
(i)This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in private real estate and private debt. All investments in this category are classified as NAV assets.
The pension trust holds debt and equity securities directly and indirectly through commingled funds. Exchange-traded debt and equity securities held directly, as well as publicly traded commingled funds, are valued using quoted market prices in actively traded markets. Non-publicly traded commingled funds hold exchange-traded equity or debt securities and are valued based on stated NAVs. Non-exchange traded fixed income securities are valued by the trustee based upon quotations available from brokers or pricing services. A primary price source is identified by asset type, class, or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustee challenges an assigned price and determines that another price source is considered preferable. DTE Energy has obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices.
Other Postretirement Benefits
The Registrants participate in defined benefit plans sponsored by the LLC that provide certain other postretirement health care and life insurance benefits for employees who are eligible for these benefits. The Registrants' policy is to fund certain trusts to meet its other postretirement benefit obligations. DTE Energy did not make any contributions to these trusts during 2025 and does not anticipate making any contributions to the trusts in 2026.
DTE Energy and DTE Electric offer a defined contribution VEBA for eligible represented and non-represented employees, in lieu of defined benefit post-employment health care benefits. The Registrants allocate a fixed amount per year to an account in a defined contribution VEBA for each employee. These accounts are managed either by the Registrant (for non-represented and certain represented groups) or by the Utility Workers of America for Local 223 employees. The following table provides contributions to the VEBA in:
Year Ended December 31,
202520242023
(In millions)
DTE Energy$15 $15 $16 
DTE Electric$7 $6 $7 
The Registrants also contribute a fixed amount to a Retiree Reimbursement Account for certain non-represented and represented retirees, spouses, and surviving spouses when the youngest of the retiree's covered household becomes eligible for Medicare Part A based on age. The amount of the annual allocation to each participant is determined by the employee's retirement date and increases each year for each eligible participant at the lower of the rate of medical inflation or 2%.
Net other postretirement credit for DTE Energy includes the following components:
Year Ended December 31,
202520242023
(In millions)
Service cost$15 $18 $17 
Interest cost61 62 65 
Expected return on plan assets(117)(120)(111)
Amortization of:
Net actuarial loss2 6 10 
Prior service credit— (10)(19)
Net other postretirement credit$(39)$(44)$(38)
December 31,
20252024
(In millions)
Other changes in plan assets and accumulated postretirement benefit obligation recognized in Regulatory assets and liabilities and Other comprehensive income (loss)
Net actuarial (gain) loss$2 $(103)
Amortization of net actuarial loss(2)(6)
Amortization of prior service credit— 10 
Total recognized in Regulatory assets and liabilities and Other comprehensive income (loss)$— $(99)
Total recognized in net periodic benefit cost, Regulatory assets and liabilities, and Other comprehensive income (loss)$(39)$(143)
Net other postretirement credit for DTE Electric includes the following components:
Year Ended December 31,
202520242023
(In millions)
Service cost$11 $14 $13 
Interest cost46 47 49 
Expected return on plan assets(77)(79)(73)
Amortization of:
Net actuarial (gain) loss(2)1 1 
Prior service credit— (6)(14)
Net other postretirement credit$(22)$(23)$(24)
December 31,
20252024
(In millions)
Other changes in plan assets and accumulated postretirement benefit obligation recognized in Regulatory assets and liabilities
Net actuarial gain$(1)$(98)
Amortization of net actuarial gain/(loss)2 (1)
Amortization of prior service credit— 6 
Total recognized in Regulatory assets and liabilities$1 $(93)
Total recognized in net periodic benefit cost and Regulatory assets and liabilities$(21)$(116)
The following table reconciles the obligations, assets, and funded status of the plans including amounts recorded as Prepaid postretirement costs or Accrued postretirement liability in the Registrants' Consolidated Statements of Financial Position at December 31:
DTE EnergyDTE Electric
2025202420252024
(In millions)
Change in accumulated postretirement benefit obligation
Accumulated postretirement benefit obligation, beginning of year$1,123 $1,283 $849 $982 
Service cost15 18 11 14 
Interest cost61 62 46 47 
Actuarial (gain) loss24 (165)15 (139)
Benefits paid(82)(75)(60)(55)
Accumulated postretirement benefit obligation, end of year$1,141 $1,123 $861 $849 
Change in plan assets
Plan assets at fair value, beginning of year$1,594 $1,614 $1,052 $1,070 
Actual return on plan assets139 58 92 40 
Benefits paid(79)(78)(57)(58)
Plan assets at fair value, end of year$1,654 $1,594 $1,087 $1,052 
Funded status$513 $471 $226 $203 
Amount recorded as:
Noncurrent assets$761 $705 $463 $428 
Current liabilities(1)(1)— — 
Noncurrent liabilities(247)(233)(237)(225)
$513 $471 $226 $203 
Amounts recognized in Accumulated other comprehensive income (loss), pre-tax
Net actuarial gain$(13)$(14)$— $— 
Amounts recognized in Regulatory assets and liabilities(a)
Net actuarial (gain) loss$64 $65 $(25)$(26)
______________________________________
(a)See Note 9 to the Consolidated Financial Statements, "Regulatory Matters."
The Registrants' postretirement benefit obligation increased for the year ended December 31 2025 due to actuarial losses driven by a decrease in discount rates. The Registrants' postretirement benefit obligations decreased for the year ended December 31, 2024 primarily due to actuarial gains driven by an increase in discount rates.
The following table reflects other postretirement benefit plans with accumulated postretirement benefit obligations in excess of plan assets as of December 31:
DTE EnergyDTE Electric
2025202420252024
(In millions)
Accumulated postretirement benefit obligation$541 $530 $510 $501 
Fair value of plan assets293 296 273 276 
Accumulated postretirement benefit obligation in excess of plan assets$248 $234 $237 $225 
At December 31, 2025, the benefits expected to be paid, including prescription drug benefits, in each of the next five years and in the aggregate for the five fiscal years thereafter for the Registrants are as follows:
DTE EnergyDTE Electric
(In millions)
2026$80 $60 
202783 62 
202885 64 
202987 65 
203089 67 
2031-2035456 347 
Total$880 $665 
Assumptions used in determining the accumulated postretirement benefit obligation and net other postretirement benefit costs of the Registrants for the years ended December 31, 2025, 2024, and 2023 are:
202520242023
Accumulated postretirement benefit obligation
Discount rate5.43%5.66%5.00%
Health care trend rate pre- and post- 65
8.25 / 8.75%
8.50 / 9.00%
7.75 / 8.25%
Ultimate health care trend rate4.50%4.50%4.50%
Year in which ultimate reached pre- and post- 65203620352035
Other postretirement benefit costs
Discount rate5.66%5.00%5.19%
Expected long-term rate of return on plan assets7.50%7.60%7.20%
Health care trend rate pre- and post- 65
8.50 / 9.00%
7.75 / 8.25%
6.75 / 7.25%
Ultimate health care trend rate4.50%4.50%4.50%
Year in which ultimate reached pre- and post- 65203520352035
The process used in determining the long-term rate of return on assets for the other postretirement benefit plans is similar to that previously described for the pension plans. As a result of this process, the Registrants have a long-term rate of return assumption for the other postretirement benefit plans of 7.40% for 2026. The Registrants believe this rate is a reasonable assumption for the long-term rate of return on plan assets given the current investment strategy.
The DTE Energy Company Master VEBA Trust employs a liability driven investment program whereby the characteristics of plan liabilities are considered when determining investment policy. Risk tolerance is established through consideration of future plan cash flows, plan funded status, and corporate financial considerations. The investment portfolio contains a diversified blend of equity, fixed income, and other investments. Furthermore, equity investments are diversified across U.S. and non-U.S. stocks and large and small market capitalizations. Fixed income investments generally include U.S. Treasuries, other governmental debt, diversified corporate bonds, bank loans, and mortgage-backed securities. Other investments are used to enhance long-term returns while improving portfolio diversification. Derivatives may be utilized in a risk controlled manner to potentially increase the portfolio beyond the market value of invested assets and/or reduce portfolio investment risk. Investment risk is measured and monitored on an ongoing basis through annual liability measurements, periodic asset/liability studies, and quarterly investment portfolio reviews.
Target allocations for the Registrants' other postretirement benefit plan assets as of December 31, 2025 are listed below:
U.S. Large Cap Equity Securities4 %
Non-U.S. Equity Securities3 
Fixed Income Securities62 
Hedge Funds and Similar Investments9 
Private Equity and Other22 
100 %
The following tables provide the fair value measurement amounts for the Registrants' other postretirement benefit plan assets at December 31, 2025 and 2024(a):
December 31, 2025December 31, 2024
Level 1Level 2
Other(b)
TotalLevel 1Level 2
Other(b)
Total
(In millions)
DTE Energy asset category:
Short-term Investments(c)
$37 $— $— $37 $33 $— $— $33 
Equity Securities
Domestic(d)
— — 61 61 — — 67 67 
International(e)
7 — 42 49 6 — 34 40 
Fixed Income Securities
Governmental(f)
169 37 — 206 210 34 — 244 
Corporate(g)
— 549 222 771 — 492 208 700 
Hedge Funds and Similar Investments(h)
34 3 105 142 27 3 103 133 
Private Equity and Other(i)
— — 388 388 — — 377 377 
DTE Energy Total$247 $589 $818 $1,654 $276 $529 $789 $1,594 
DTE Electric asset category:
Short-term Investments(c)
$24 $— $— $24 $21 $— $— $21 
Equity Securities
Domestic(d)
— — 38 38 — — 42 42 
International(e)
4 — 27 31 4 — 22 26 
Fixed Income Securities
Governmental(f)
110 24 — 134 138 22 — 160 
Corporate(g)
— 359 151 510 — 324 141 465 
Hedge Funds and Similar Investments(h)
21 2 70 93 17 2 69 88 
Private Equity and Other(i)
— — 257 257 — — 250 250 
DTE Electric Total$159 $385 $543 $1,087 $180 $348 $524 $1,052 
_______________________________________
(a)For a description of levels within the fair value hierarchy see Note 12 to the Consolidated Financial Statements, "Fair Value."
(b)Amounts represent assets valued at NAV as a practical expedient for fair value.
(c)This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category is obtained from quoted prices in actively traded markets.
(d)This category represents portfolios of large, medium and small capitalization domestic equities. Investments in this category include exchange-traded securities held in a commingled fund classified as NAV assets.
(e)This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category include exchange-traded securities for which unadjusted quoted prices can be obtained and exchange-traded securities held in a commingled fund classified as NAV assets.
(f)This category includes U.S. Treasuries, bonds and other governmental debt. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services.
(g)This category primarily consists of corporate bonds from diversified industries, bank loans, and mortgage backed securities. Pricing for investments in this category is obtained from quotations from broker or pricing services. Non-exchange traded securities and exchange-traded securities held in commingled funds are classified as NAV assets.
(h)This category utilizes a diversified group of strategies that attempt to capture uncorrelated sources of return and includes publicly traded mutual funds, insurance-linked and asset-backed securities, commingled funds and limited partnership funds. Pricing for mutual funds in this category is obtained from quoted prices in actively traded markets. Pricing for insurance-linked and asset-backed securities is obtained from quotations from broker or pricing services. Commingled funds and limited partnership funds are classified as NAV assets.
(i)This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in private real estate and private debt. All investments in this category are classified as NAV assets.
The DTE Energy Company Master VEBA Trust holds debt and equity securities directly and indirectly through commingled funds. Exchange-traded debt and equity securities held directly, as well as publicly traded commingled funds, are valued using quoted market prices in actively traded markets. Non-publicly traded commingled funds hold exchange-traded equity or debt securities and are valued based on NAVs. Non-exchange traded fixed income securities are valued by the trustee based upon quotations available from brokers or pricing services. A primary price source is identified by asset type, class, or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustee challenges an assigned price and determines that another price source is considered preferable. The Registrants have obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices.
Defined Contribution Plans
The Registrants also sponsor defined contribution retirement savings plans. Participation in one of these plans is available to substantially all represented and non-represented employees. For substantially all employees, the Registrants match employee contributions up to certain predefined limits based upon eligible compensation and the employee’s contribution rate. Additionally, for eligible represented and non-represented employees who do not participate in the Pension Plans, the Registrants contribute amounts equivalent to 4% (8% for certain DTE Gas represented employees) of an employee's eligible compensation to the employee's defined contribution retirement savings plan. For DTE Energy, the cost of these plans was $80 million, $76 million, and $75 million for the years ended December 31, 2025, 2024, and 2023, respectively. For DTE Electric, the cost of these plans was $37 million for the year ended December 31, 2025, and $35 million for the years ended December 31, 2024 and 2023.
v3.25.4
Stock-Based Compensation
 12 Months Ended
Dec. 31, 2025
Share-Based Payment Arrangement, Noncash Expense [Abstract]  
Stock-Based Compensation STOCK-BASED COMPENSATION
In May 2025, DTE Energy's shareholders approved the replacement of the Long-Term Incentive Plan, as amended and restated effective May 20, 2021 ("Prior Plan") with the 2025 Long Term Incentive Plan ("2025 Plan"). No new awards will be granted under the Prior Plan. At December 31, outstanding stock-based incentives were in the form of restricted stock and performance stock units. The 2025 Plan permits the grant of options, stock appreciation rights, restricted stock, restricted stock units, performance stock units, and other stock-based awards. With the exception of incentive stock options, awards may be granted to employees, the Board of Directors, and consultants. As a result of a stock award, a settlement of an award of performance stock units, or by exercise of a participant's stock option, DTE Energy may deliver common stock from its authorized but unissued common stock and/or from outstanding common stock acquired by or on behalf of DTE Energy in the name of the participant. Key provisions of the stock incentive program are:
•Authorized limit is 4,663,434 shares of common stock; and
•Prohibits the grant of a stock option with an exercise price that is less than the fair market value of DTE Energy’s stock on the date of the grant.
DTE Energy records compensation expense at fair value over the vesting period for all awards it grants.
The following table summarizes the components of stock-based compensation for DTE Energy:
Year Ended December 31,
202520242023
(In millions)
Stock-based compensation expense$60 $54 $48 
Tax benefit$10 $10 $9 
Restricted Stock Awards
Stock awards granted under the plan are restricted for varying periods, generally for three years. Participants have all rights of a shareholder with respect to a stock award, including the right to receive dividends and vote the shares. Prior to vesting in stock awards, the participant: (i) may not sell, transfer, pledge, exchange, or otherwise dispose of shares and (ii) shall not retain custody of the share certificates.
The stock awards are recorded at cost that approximates fair value on the date of grant. The cost is amortized to compensation expense over the vesting period.
The fair value of awards vested were not material for the years ended December 31, 2025, 2024, and 2023. Compensation cost charged against income was $17 million for the year ended December 31, 2025 and $14 million for the years ended December 31, 2024 and 2023.
Performance Stock Units
Performance stock units awarded under the plan are for a specified number of shares of DTE Energy common stock that entitle the holder to receive a cash payment, shares of DTE Energy common stock, or a combination thereof. The final value of the award is determined by the achievement of certain performance objectives and market conditions. The awards vest at the end of a specified period, usually three years. Awards granted in 2025, 2024, and 2023 were primarily deemed to be equity awards. The DTE Energy stock price and number of probable shares attributable to market conditions for such equity awards are fair valued only at the grant date. DTE Energy accounts for performance stock unit awards by accruing compensation expense over the vesting period based on: (i) the number of shares expected to be paid which is based on the probable achievement of performance objectives; and (ii) the closing stock price market value. The settlement of the award is based on the closing price at the settlement date.
DTE Energy recorded activity relating to performance stock unit awards as follows:
Year Ended December 31,
202520242023
(In millions, except per share amounts)
Weighted average grant date fair value of awards granted (per share)$123.02 $106.04 $112.73 
Awards settled in cash(a)
$— $— $9 
Awards settled in stock(a)
$39 $63 $59 
Compensation expense$43 $40 $34 
_______________________________________
(a)Sum of awards settled in cash and stock approximates the intrinsic value of the awards.
During the vesting period, the recipient of a performance stock unit award has no shareholder rights. During the period beginning on the date the performance shares are awarded and ending on the certification date of the performance objectives, the number of performance stock units awarded will be increased, assuming full dividend reinvestment at the fair market value on the dividend payment date. The cumulative number of performance stock units will be adjusted to determine the final payment based on the performance objectives achieved. Performance stock unit awards are nontransferable and are subject to risk of forfeiture.
The following table summarizes DTE Energy’s performance stock unit activity for the period ended December 31, 2025:
Performance Stock UnitsWeighted Average
Grant Date
Fair Value
Balance at December 31, 2024976,843 $122.25 
Grants391,290 $123.02 
Forfeitures(58,011)$118.07 
Payouts(301,030)$120.34 
Balance at December 31, 20251,009,092 $123.36 
Unrecognized Compensation Costs
As of December 31, 2025, DTE Energy's total unrecognized compensation cost related to non-vested stock incentive plan arrangements and the weighted average recognition period was as follows:
Unrecognized
Compensation
Cost		Weighted Average
to be Recognized
(In millions)(In years)
Stock awards$23 1.97
Performance stock units44 1.68
$67 1.78
Allocated Stock-Based Compensation
DTE Electric received an allocation of costs from DTE Energy associated with stock-based compensation. DTE Electric's allocation for 2025, 2024, and 2023 for stock-based compensation expense was $41 million, $37 million, and $31 million, respectively.
v3.25.4
Segment and Related Information
 12 Months Ended
Dec. 31, 2025
Segment Reporting [Abstract]  
Segment and Related Information SEGMENT AND RELATED INFORMATION
DTE Energy sets strategic goals, allocates resources, and evaluates performance based on the four reportable segments below. DTE Electric is a standalone registrant with one reportable segment.
Electric segment consists principally of DTE Electric, which is engaged in the generation, purchase, distribution, and sale of electricity to approximately 2.3 million residential, commercial, and industrial customers in southeastern Michigan.
Gas segment consists principally of DTE Gas, which is engaged in the purchase, storage, transportation, distribution, and sale of natural gas to approximately 1.4 million residential, commercial, and industrial customers throughout Michigan and the sale of storage and transportation capacity.
DTE Vantage segment is comprised primarily of renewable energy projects that sell electricity and pipeline-quality gas and projects that deliver custom energy solutions to industrial, commercial, and institutional customers.
Energy Trading segment consists of energy marketing and trading operations.
Corporate and Other includes various holding company activities, holds certain non-utility debt, and holds certain investments, including funds supporting regional development and economic growth.
The chief operating decision maker (CODM) at DTE Energy is the Financial Objectives committee, which is comprised of the Chief Executive Officer, Chief Financial Officer, and other executive leaders of DTE Energy. The CODM at DTE Electric is comprised of the Chief Executive Officer and Chief Financial Officer. The CODMs assess performance for the reportable segments detailed above and decide how to allocate resources based on Net Income (Loss) Attributable to DTE Energy Company and monitoring budget versus actual results. The accounting policies of the segments are the same as those described in the summary of significant accounting policies.
Inter-segment billing for goods and services exchanged between segments is based upon tariffed or market-based prices of the provider. Such billing primarily consists of power sales, sale and transportation of natural gas, and renewable natural gas sales in the segments below, as well as charges from Electric to other segments for use of the shared capital assets of DTE Electric.
Year Ended December 31,
202520242023
(In millions)
Electric segment(a)
$71 $71 $72 
Gas segment22 16 17 
DTE Vantage segment77 43 68 
Energy Trading segment176 100 85 
$346 $230 $242 
_______________________________________
(a)Inter-segment billing for the Electric segment relating to Non-utility operations includes $4 million for the year ended December 31, 2025 and $3 million for the years ended December 31, 2024 and 2023.
All inter-segment transactions and balances are eliminated in consolidation for DTE Energy. Centrally incurred costs such as labor and overheads are assigned directly to DTE Energy's business segments or allocated based on various cost drivers, depending on the nature of service provided.
The federal income tax provisions or benefits of DTE Energy’s subsidiaries are determined on an individual company basis and recognize the tax benefit of tax credits and net operating losses, if applicable. The state and local income tax provisions of the utility subsidiaries are also determined on an individual company basis and recognize the tax benefit of various tax credits and net operating losses, if applicable. The subsidiaries record federal, state, and local income taxes payable to or receivable from DTE Energy based on the federal, state, and local tax provisions of each company. Carryforward items, such as tax credits and charitable contributions, are recorded at their individual company basis and adjusted at Corporate and Other for consolidated tax purposes.
The Reclassifications and Eliminations group below also includes the reclassification of deferred tax assets and prepaid pension assets, which are netted against deferred tax liabilities and accrued pension liabilities, respectively, for presentation on the DTE Energy Consolidated Statements of Financial Position. Refer to Note 10 to the Consolidated Financial Statements, "Income Taxes," for additional information regarding the Registrants' deferred taxes and to Note 20, "Retirement Benefits and Trusteed Assets," for additional information regarding pension plans.
Financial data of DTE Energy's business segments follows:
Electric(a)
Gas
DTE
Vantage
Energy
Trading
Total
Reportable
Segments
Corporate
and
Other
Reclassifications
and
Eliminations
Total
(In millions)
2025 Segment profit (loss)
Operating Revenues — Utility operations$6,885 2,052 — — $8,937 — (88)$8,849 
Operating Revenues — Non-utility operations$50 — 696 6,477 $7,223 — (258)$6,965 
Depreciation and amortization$1,553 225 59 4 $1,841 — — $1,841 
Interest expense$555 132 30 10 $727 409 (80)$1,056 
Interest income$(9)(11)(87)(7)$(114)(69)80 $(103)
Equity earnings of equity method investees$— 1 19 — $20 27 — $47 
Other segment items (pre-tax)(b)
$3,605 1,322 582 6,306 $11,815 (46)(346)$11,423 
Income Tax Expense (Benefit)$73 88 (61)41 $141 (53)— $88 
Net Income (Loss) Attributable to DTE Energy Company$1,158 295 154 123 $1,730 (268)— $1,462 
2025 Other segment financial data
Investment in equity method investees$4 19 77 — $100 22 — $122 
Capital expenditures and acquisitions$3,892 661 80 6 $4,639 — — $4,639 
Goodwill$1,208 743 25 17 $1,993 — — $1,993 
Total Assets$39,370 8,987 2,426 1,313 $52,096 5,145 (3,175)$54,066 
2024 Segment profit (loss)
Operating Revenues — Utility operations$6,277 1,798 — — $8,075 — (85)$7,990 
Operating Revenues — Non-utility operations$16 — 753 3,843 $4,612 — (145)$4,467 
Depreciation and amortization$1,447 221 59 5 $1,732 — — $1,732 
Interest expense$498 118 28 14 $658 351 (58)$951 
Interest income$(7)(10)(76)(15)$(108)(86)58 $(136)
Equity earnings (losses) of equity method investees$— 1 15 — $16 (1)— $15 
Other segment items (pre-tax)(b)
$3,314 1,134 629 3,672 $8,749 6 (230)$8,525 
Income Tax Expense (Benefit)$(31)77 (37)42 $51 (85)— $(34)
Net Income (Loss) Attributable to
DTE Energy Company
$1,072 257 135 125 $1,589 (185)— $1,404 
2024 Other segment financial data
Investment in equity method investees$5 18 82 — $105 23 — $128 
Capital expenditures and acquisitions$3,659 740 65 3 $4,467 — — $4,467 
Goodwill$1,208 743 25 17 $1,993 — — $1,993 
Total Assets$35,400 8,474 2,065 1,159 $47,098 4,723 (2,975)$48,846 
_______________________________________
(a)The Electric segment consists principally of DTE Electric. Refer to the DTE Electric Consolidated Statements of Operations and the DTE Electric Consolidated Statements of Financial Position for the standalone DTE Electric amounts.
(b)Other segment items include Fuel, purchased power, and gas — utility; Fuel, purchased power, gas, and other — non-utility; Operation and maintenance; Taxes other than income; Asset (gains) losses and impairments, net; Non-operating retirement benefits, net; Other income; and Other expenses.
Electric(a)
Gas
DTE
Vantage
Energy
Trading
Total
Reportable
Segments
Corporate
and
Other
Reclassifications
and
Eliminations
Total
(In millions)
2023 Segment profit (loss)
Operating Revenues — Utility operations$5,804 1,748 — — $7,552 — (86)$7,466 
Operating Revenues — Non-utility operations$14 — 809 4,612 $5,435 — (156)$5,279 
Depreciation and amortization$1,340 209 53 4 $1,606 — — $1,606 
Interest expense$432 102 15 18 $567 270 (46)$791 
Interest income$(20)(9)(32)(9)$(70)(33)46 $(57)
Equity earnings (losses) of equity method investees$— 1 7 — $8 (5)— $3 
Other segment items (pre-tax)(b)
$3,216 1,058 635 4,151 $9,060 18 (242)$8,836 
Income Tax Expense (Benefit)$78 93 (22)112 $261 (92)— $169 
Net Income (Loss) Attributable to DTE Energy Company$772 294 153 336 $1,555 (158)— $1,397 
2023 Other segment financial data
Investment in equity method investees$5 16 118 — $139 27 — $166 
Capital expenditures and acquisitions$3,128 746 57 3 $3,934 — — $3,934 
Goodwill$1,208 743 25 17 $1,993 — — $1,993 
Total Assets$32,292 7,722 1,122 1,166 $42,302 4,150 (1,697)$44,755 
_______________________________________
(a)The Electric segment consists principally of DTE Electric. Refer to the DTE Electric Consolidated Statements of Operations and the DTE Electric Consolidated Statements of Financial Position for the standalone DTE Electric amounts.
(b)Other segment items include Fuel, purchased power, and gas — utility; Fuel, purchased power, gas, and other — non-utility; Operation and maintenance; Taxes other than income; Asset (gains) losses and impairments, net; Non-operating retirement benefits, net; Other income; and Other expenses.
v3.25.4
Related Party Transactions
 12 Months Ended
Dec. 31, 2025
Related Party Transactions [Abstract]  
Related Party Transactions RELATED PARTY TRANSACTIONS
DTE Electric has agreements with affiliated companies to buy and sell power, and for the purchase and transportation of fuel for use at its natural gas-fired combined cycle plant and other generation facilities. DTE Electric also has agreements with certain DTE Energy affiliates where it charges the affiliates for their use of the shared capital assets of DTE Electric. Various other corporate support expenses are accumulated by a shared services company and charged to various subsidiaries of DTE Energy, including DTE Electric.
The following is a summary of DTE Electric's transactions with affiliated companies:
Year Ended December 31,
202520242023
(In millions)
Revenues and Other Income
Energy sales$12 $11 $11 
Other services and interest$— $— $3 
Shared capital assets$55 $58 $58 
Costs
Fuel and purchased power$85 $65 $50 
Other services and interest$20 $4 $2 
Corporate expenses$349 $342 $299 
Other
Dividends declared$846 $776 $1,002 
Dividends paid$846 $776 $1,002 
Capital contribution from DTE Energy$954 $634 $759 
DTE Electric's Accounts receivable and Accounts payable related to affiliates are payable upon demand and are generally settled in cash within a monthly business cycle. Notes receivable and Short-term borrowings related to affiliates are subject to a credit agreement with DTE Energy whereby short-term excess cash or cash shortfalls are remitted to or funded by DTE Energy. This credit arrangement involves the charge and payment of interest based on monthly commercial paper rates. The weighted average interest rate for DTE Electric's affiliate borrowings was 3.9% and 4.7% at December 31, 2025 and 2024, respectively. Refer to DTE Electric's Consolidated Statements of Financial Position for affiliate balances at December 31, 2025 and 2024.
DTE Electric records federal, state, and local income taxes payable to or receivable from DTE Energy based on its federal, state, and local tax provisions. Refer to Note 10 to the Consolidated Financial Statements, "Income Taxes," for additional information. For a discussion of other related party transactions impacting DTE Electric, see Notes 20 and 21 to the Consolidated Financial Statements, "Retirement Benefits and Trusteed Assets" and "Stock-Based Compensation," respectively.
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]
DTE Energy maintains cybersecurity measures designed to protect its physical and digital infrastructure in order to provide safe and reliable delivery of energy to customers. These measures serve to maintain compliance with regulations and protect the confidentiality, integrity and availability of confidential and proprietary information, DTE Energy’s computing resources, and the electrical and gas systems. The cybersecurity structure of DTE Electric is overseen in alignment with the enterprise-wide framework established by DTE Energy.
To protect against cybersecurity threats, DTE Energy employs a dedicated cybersecurity team led by the Chief Information Officer. The cybersecurity team is responsible for implementing proper safeguards to mitigate the risk of cyber threats, including but not limited to firewalls, continuous monitoring, and training. DTE Energy also engages with third parties to conduct cybersecurity maturity assessments to provide an independent and objective view of our cybersecurity and assess opportunities for improvement. The National Institute of Standards and Technology (NIST) Cybersecurity Framework (CSF) is the basis for these assessments to manage cyber risks, mature and monitor existing security controls, and communicate security posture coherently. The NIST CSF provides a common language to understand, manage, and express cyber risks internally and externally.
Another component of DTE Energy’s cybersecurity team is the Cybersecurity Defense Center (CSDC), which has the primary responsibility for monitoring and responding to cybersecurity incidents. The CSDC maintains an incident response plan designed to protect against, detect, evaluate, and respond to and recover from a cyber incident. The CSDC may receive incident reports from DTE Energy employees, corporate security, or external sources. The incident response plan is intended to be flexible so it may be adapted to an array of potential scenarios. Depending on the incident, the CSDC may decide to engage external resources for assistance with responding to the incident. DTE Energy regularly conducts exercises to help ensure the plan’s effectiveness and overall preparedness.
DTE Energy engages third-party service providers to assist with managing various aspects of its business. These service providers are subject to due diligence reviews of their information security programs prior to onboarding. DTE Energy also contractually requires service providers with access to its information technology (IT) systems, sensitive business data, or personal information to implement and maintain appropriate security controls and restricts their ability to use such data for purposes other than to provide services to DTE Energy, except as required by law. Third-party service providers are also contractually required to notify DTE Energy promptly of cyber incidents that may affect any systems or data. DTE Energy collaborates with its service providers to help determine whether their information security protocols are sufficient. If a service provider experiences a cyber incident, DTE Energy monitors their compliance with our security requirements; however, DTE Energy may not have the ability in all cases to effectively oversee the implementation of these control measures.
The CSDC monitors and responds to actual and potential compromises from third-party service providers. Access from a potentially compromised third-party is restricted until DTE Energy receives confirmation the compromise has been mitigated.
DTE Energy has experienced, and expects to continue to be subject to, cybersecurity threats and incidents. As of December 31, 2025, cybersecurity risks have not materially affected the Registrants’ business strategy, results of operations, or financial condition. For additional discussion of the risks related to cybersecurity threats and incidents, see Item 1A. "Risk Factors."
Cybersecurity Risk Management Processes Integrated [Flag] true
Cybersecurity Risk Management Processes Integrated [Text Block] To protect against cybersecurity threats, DTE Energy employs a dedicated cybersecurity team led by the Chief Information Officer. The cybersecurity team is responsible for implementing proper safeguards to mitigate the risk of cyber threats, including but not limited to firewalls, continuous monitoring, and training.
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] Members of the Board of Directors serve roles on various committees responsible for their respective oversight and risk management.
Cybersecurity Risk Board Committee or Subcommittee Responsible for Oversight [Text Block]
DTE Energy has an enterprise risk management program to reduce overall risk, including risks related to cybersecurity, through comprehensive risk assessments and execution of corresponding mitigation plans. Risks are reported and managed through various internal committees, which meet regularly and report at least annually to the Board of Directors. These committees include:
•The Risk Management Committee (RMC) is chaired by the Chief Executive Officer and comprised of the Chief Financial Officer, Chief Legal Officer, General Auditor, and other senior officers. The RMC directs the development and maintenance of comprehensive risk management policies and procedures. The RMC also sets, reviews, and monitors risk limits for enterprise-level risk and other exposures
•The Operational Risk and Resilience (ORR) Committee is chaired by and comprised of operational leaders in DTE Energy’s business units. The ORR is responsible for managing operational risks including safety, reliability, and cybersecurity at DTE Energy’s generation plants, substations, and other operating sites
•The Technology Cybersecurity Committee (TCC) is a sub-committee of the ORR that focuses on information and operational technology risks related to cybersecurity, chaired by operational leaders in DTE Energy’s business units and includes the Chief Information Officer
Cybersecurity Risk Process for Informing Board Committee or Subcommittee Responsible for Oversight [Text Block] The Audit Committee reports to the Board of Directors and may include any significant matters involving cybersecurity within its reporting. All members of the Board of Directors, including the Audit Committee, have either managerial knowledge or working knowledge of technology and cybersecurity matters.
Cybersecurity Risk Role of Management [Text Block]
DTE Energy’s Chief Information Officer leads the cybersecurity team and has responsibility for assessing and managing cybersecurity risks. The Chief Information Officer has held this position for over 10 years and has decades of experience in IT, including oversight of information protection security (IPS). The IPS cybersecurity team is also led by two full-time directors with over 40 combined years of industry experience, including (1) the director of cybersecurity operations responsible for the CSDC, security awareness, identity, and access assurance and (2) the IPS director of cybersecurity strategy, risk, and engagement who is also responsible for engagement and outreach to internal and external stakeholders, cloud security, and vulnerability management.
The Chief Information Officer provides regular updates to the Audit Committee and senior leaders regarding DTE Energy’s management of cyber risks, including but not limited to the status of various training metrics to safeguard against phishing, malware, and other cyber threats. The Chief Information Officer also provides an annual cybersecurity update directly to the Board of Directors. If cybersecurity risks arise, the CSDC executes the incident response plan and communicates the appropriate details to executive management, the Board of Directors, or any related committees.
A cybersecurity incident may also require various levels of external reporting. The CSDC coordinates with the legal department and controller’s organization in reporting incidents externally. Depending on the nature of the incident, reporting may be required to various federal and state government agencies. DTE Energy has forged trusted partnerships with such agencies and with other companies and organizations to share best practices, tools, and threat information. This includes partnering with others in the utilities industry to form the Electricity Subsector Coordination Council (ESCC). The ESCC is the principal liaison between the energy sector and the federal government in coordinating efforts to prepare for and respond to any threats to critical infrastructure.
Cybersecurity Risk Management Positions or Committees Responsible [Flag] true
Cybersecurity Risk Management Positions or Committees Responsible [Text Block]
DTE Energy’s Chief Information Officer leads the cybersecurity team and has responsibility for assessing and managing cybersecurity risks. The Chief Information Officer has held this position for over 10 years and has decades of experience in IT, including oversight of information protection security (IPS). The IPS cybersecurity team is also led by two full-time directors with over 40 combined years of industry experience, including (1) the director of cybersecurity operations responsible for the CSDC, security awareness, identity, and access assurance and (2) the IPS director of cybersecurity strategy, risk, and engagement who is also responsible for engagement and outreach to internal and external stakeholders, cloud security, and vulnerability management.
The Chief Information Officer provides regular updates to the Audit Committee and senior leaders regarding DTE Energy’s management of cyber risks, including but not limited to the status of various training metrics to safeguard against phishing, malware, and other cyber threats. The Chief Information Officer also provides an annual cybersecurity update directly to the Board of Directors. If cybersecurity risks arise, the CSDC executes the incident response plan and communicates the appropriate details to executive management, the Board of Directors, or any related committees.
Cybersecurity Risk Management Expertise of Management Responsible [Text Block] The Chief Information Officer has held this position for over 10 years and has decades of experience in IT, including oversight of information protection security (IPS). The IPS cybersecurity team is also led by two full-time directors with over 40 combined years of industry experience, including (1) the director of cybersecurity operations responsible for the CSDC, security awareness, identity, and access assurance and (2) the IPS director of cybersecurity strategy, risk, and engagement who is also responsible for engagement and outreach to internal and external stakeholders, cloud security, and vulnerability management.
Cybersecurity Risk Process for Informing Management or Committees Responsible [Text Block]
The Chief Information Officer provides regular updates to the Audit Committee and senior leaders regarding DTE Energy’s management of cyber risks, including but not limited to the status of various training metrics to safeguard against phishing, malware, and other cyber threats. The Chief Information Officer also provides an annual cybersecurity update directly to the Board of Directors. If cybersecurity risks arise, the CSDC executes the incident response plan and communicates the appropriate details to executive management, the Board of Directors, or any related committees.
Cybersecurity Risk Management Positions or Committees Responsible Report to Board [Flag] true
v3.25.4
Significant Accounting Policies (Policies)
 12 Months Ended
Dec. 31, 2025
Accounting Policies [Abstract]  
Basis of Presentation
Basis of Presentation
The accompanying Consolidated Financial Statements of the Registrants are prepared using accounting principles generally accepted in the United States of America. These accounting principles require management to use estimates and assumptions that impact reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results may differ from the Registrants' estimates.
The information in these combined notes relates to each of the Registrants as noted in the Index of Combined Notes to Consolidated Financial Statements. However, DTE Electric does not make any representation as to information related solely to DTE Energy or the subsidiaries of DTE Energy other than itself.
Certain prior year balances for the Registrants were reclassified to match the current year's Consolidated Financial Statements presentation.
Principles of Consolidation
Principles of Consolidation
The Registrants consolidate all majority-owned subsidiaries and investments in entities in which they have controlling influence. Non-majority owned investments are accounted for using the equity method when the Registrants are able to significantly influence the operating policies of the investee. When the Registrants do not influence the operating policies of an investee, the equity investment is valued at cost minus any impairments, if applicable. These Consolidated Financial Statements also reflect the Registrants' proportionate interests in certain jointly-owned utility plants. The Registrants eliminate all intercompany balances and transactions.
The Registrants evaluate whether an entity is a VIE whenever reconsideration events occur. The Registrants consolidate VIEs for which they are the primary beneficiary. If a Registrant is not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, a Registrant considers all relevant facts and circumstances, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. The Registrants perform ongoing reassessments of all VIEs to determine if the primary beneficiary status has changed.
Legal entities within the DTE Vantage segment enter into long-term contractual arrangements with customers to supply energy-related products or services. The entities are generally designed to pass-through the commodity risk associated with these contracts to the customers, with DTE Energy retaining operational and customer default risk. These entities generally are VIEs and consolidated when DTE Energy is the primary beneficiary. In addition, DTE Energy has interests in certain VIEs through which control of all significant activities is shared with partners, and therefore are generally accounted for under the equity method.
The Registrants hold ownership interests in certain limited partnerships. The limited partnerships include investment funds which support regional development and economic growth, and an operational business providing energy-related products. These entities are generally VIEs as a result of certain characteristics of the limited partnership voting rights. The ownership interests are accounted for under the equity method as the Registrants are not the primary beneficiaries.
DTE Energy has variable interests in VIEs through certain of its long-term purchase and sale contracts. DTE Electric has variable interests in VIEs through certain of its long-term purchase contracts. As of December 31, 2025, the carrying amount of assets and liabilities in DTE Energy's Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase and sale contracts are predominantly related to working capital accounts and generally represent the amounts owed by or to DTE Energy for the deliveries associated with the current billing cycle under the contracts. As of December 31, 2025, the carrying amount of assets and liabilities in DTE Electric's Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase contracts are predominantly related to working capital accounts and generally represent the amounts owed by DTE Electric for the deliveries associated with the current billing cycle under the contracts. The Registrants have not provided any significant form of financial support associated with these long-term contracts. There is no material potential exposure to loss as a result of DTE Energy's variable interests through these long-term purchase and sale contracts. In addition, there is no material potential exposure to loss as a result of DTE Electric's variable interests through these long-term purchase contracts.
DTE Electric previously financed regulatory assets for deferred costs related to certain retired generation plants and its tree trimming surge program through the sale of bonds by wholly-owned special purpose entities, DTE Securitization I and DTE Securitization II (collectively "the DTE Securitization entities"). The DTE Securitization entities are VIEs. DTE Electric has the power to direct the most significant activities of these entities, including performing servicing activities such as billing and collecting surcharge revenue. Accordingly, DTE Electric is the primary beneficiary and the DTE Securitization entities are consolidated by the Registrants. Securitization bond holders have no recourse to the Registrants' assets, except for those held by the DTE Securitization entities. Surcharges collected by DTE Electric to pay for bond servicing and other qualified costs reflect securitization property solely owned by the DTE Securitization entities. These surcharges are remitted to a trustee and are not available to other creditors of the Registrants.
The maximum risk exposure for consolidated VIEs is reflected on the Registrants' Consolidated Statements of Financial Position. For non-consolidated VIEs, the maximum risk exposure of the Registrants is generally limited to their investment and notes receivable.
Other Income
Other Income
Other income for the Registrants is recognized for non-operating income such as equity earnings of equity method investees, allowance for equity funds used during construction, contract services, and certain investment income, primarily from trading securities held in DTE Energy's rabbi trust.
Accounting for ISO Transactions
Accounting for ISO Transactions
DTE Electric participates in the energy market through MISO. MISO requires that DTE Electric submit hourly day-ahead, real-time, and FTR bids and offers for energy at locations across the MISO region. DTE Electric accounts for MISO transactions on a net hourly basis in each of the day-ahead, real-time, and FTR markets. In any single hour, transactions in each of the MISO energy markets are netted based on MWh to determine if DTE Electric is in a net sale or purchase position. Net purchases are recorded in Fuel, purchased power, and gas — utility and net sales are recorded in Operating Revenues — Utility operations on the Registrants' Consolidated Statements of Operations.
The Energy Trading segment participates in the energy markets through various ISOs and RTOs. These markets require that Energy Trading submits hourly day-ahead, real-time bids and offers for energy at locations across each region. Energy Trading submits bids in the annual and monthly auction revenue rights and FTR auctions to the RTOs. Energy Trading accounts for these transactions on a net hourly basis for the day-ahead, real-time, and FTR markets. These transactions are related to trading contracts which, if derivatives, are presented on a net basis in Operating Revenues — Non-utility operations, and if non-derivatives, the realized gains and losses for sales are recorded in Operating Revenues — Non-utility operations and purchases are recorded in Fuel, purchased power, gas, and other — non-utility in the DTE Energy Consolidated Statements of Operations.
DTE Electric and Energy Trading record accruals for future net purchase adjustments based on historical experience and reconcile accruals to actual costs when invoices are received from MISO and other ISOs and RTOs.
Derivatives
Derivatives
Energy Trading classifies derivative transactions as revenue or expense based on the intent of the transaction (buy or sell). Revenues are recorded on a gross or net basis within the income statement depending upon whether it represents a non-trading activity or trading activity, respectively. Cash flows associated with derivative instruments, including related gains and losses, are presented as Operating Activities within the Registrants' Consolidated Statements of Cash Flows.
The Registrants recognize all derivatives at their fair value as Derivative assets or liabilities on their respective Consolidated Statements of Financial Position unless they qualify for certain scope exceptions, including the normal purchases and normal sales exception. Further, derivatives that qualify and are designated for hedge accounting are classified as either hedges of a forecasted transaction or the variability of cash flows to be received or paid related to a recognized asset or liability (cash flow hedge); or as hedges of the fair value of a recognized asset or liability or of an unrecognized firm commitment (fair value hedge). For cash flow hedges, the derivative gain or loss is deferred in Accumulated other comprehensive income (loss) and later reclassified into earnings when the underlying transaction occurs. For fair value hedges, changes in fair values for the derivative and hedged item are recognized in earnings each period. For derivatives that do not qualify or are not designated for hedge accounting, changes in fair value are recognized in earnings each period.
The Registrants' primary market risk exposure is associated with commodity prices, credit, and interest rates. The Registrants have risk management policies to monitor and manage market risks. The Registrants use derivative instruments to manage some of the exposure. DTE Energy uses derivative instruments for trading purposes in its Energy Trading segment. Contracts classified as derivative instruments include electricity, natural gas, oil, certain environmental contracts, forwards, futures, options, swaps, and foreign currency exchange contracts. Items not classified as derivatives include natural gas and environmental inventory, pipeline transportation contracts, some environmental contracts, and natural gas storage assets.
DTE Electric — DTE Electric generates, purchases, distributes, and sells electricity. DTE Electric uses forward contracts to manage changes in the price of electricity and fuel. Substantially all of these contracts meet the normal purchases and normal sales exception and are therefore accounted for under the accrual method. Other derivative contracts are MTM and recoverable through the PSCR mechanism when settled. This results in the deferral of unrealized gains and losses as Regulatory assets or liabilities until realized.
DTE Gas — DTE Gas purchases, stores, transports, distributes, and sells natural gas, and buys and sells transportation and storage capacity. DTE Gas has fixed-priced contracts for portions of its expected natural gas supply requirements through March 2028. Substantially all of these contracts meet the normal purchases and normal sales exception and are therefore accounted for under the accrual method. Forward transportation and storage contracts are generally not derivatives and are therefore accounted for under the accrual method.
DTE Vantage — DTE Vantage manages and operates renewable gas recovery projects, power generation assets, and other customer specific energy solutions. Long-term contracts and hedging instruments are used in the marketing and management of the segment assets. These contracts and hedging instruments are generally not derivatives and are therefore accounted for under the accrual method.
Energy Trading — Commodity Price Risk — Energy Trading markets and trades electricity, natural gas physical products, and energy financial instruments, and provides energy and asset management services utilizing energy commodity derivative instruments. Forwards, futures, options, and swap agreements are used to manage exposure to the risk of market price and volume fluctuations in its operations. These derivatives are accounted for by recording changes in fair value to earnings unless hedge accounting criteria are met.
Energy Trading — Foreign Currency Exchange Risk — Energy Trading has foreign currency exchange forward contracts to economically hedge fixed Canadian dollar commitments existing under natural gas and power purchase and sale contracts and natural gas transportation contracts. Energy Trading enters into these contracts to mitigate price volatility with respect to fluctuations of the Canadian dollar relative to the U.S. dollar. These derivatives are accounted for by recording changes in fair value to earnings unless hedge accounting criteria are met.
Corporate and Other — Interest Rate Risk — DTE Energy may use interest rate swaps, treasury locks, and other derivatives to hedge the risk associated with interest rate market volatility.
Credit Risk — DTE Energy maintains credit policies that significantly minimize overall credit risk. These policies include an evaluation of potential customers’ and counterparties’ financial condition, including the viability of underlying productive assets, credit rating, collateral requirements, or other credit enhancements such as letters of credit or guarantees. DTE Energy generally uses standardized agreements that allow the netting of positive and negative transactions associated with a single counterparty. DTE Energy maintains a provision for credit losses based on factors surrounding the credit risk of its customers, historical trends, and other information. Based on DTE Energy's credit policies and its December 31, 2025 provision for credit losses, DTE Energy’s exposure to counterparty nonperformance is not expected to have a material adverse effect on DTE Energy's Consolidated Financial Statements.
Changes in Accumulated Other Comprehensive Income (Loss)
Changes in Accumulated Other Comprehensive Income (Loss)
Comprehensive income (loss) is the change in common shareholders’ equity during a period from transactions and events from non-owner sources, including Net Income. The amounts recorded to Accumulated other comprehensive income (loss) for DTE Energy include changes in benefit obligations, consisting of deferred actuarial losses and prior service costs, unrealized gains and losses from derivatives accounted for as cash flow hedges, and foreign currency translation adjustments, if any. DTE Energy releases income tax effects from accumulated other comprehensive income when the circumstances upon which they are premised cease to exist.
Changes in Accumulated other comprehensive income (loss) are presented in DTE Energy's Consolidated Statements of Changes in Equity and DTE Electric's Consolidated Statements of Changes in Shareholder's Equity, if any.
Cash, Cash Equivalents, and Restricted Cash
Cash, Cash Equivalents, and Restricted Cash
Cash and cash equivalents include cash on hand, cash in banks, and temporary investments purchased with maturities of three months or less. Restricted cash includes funds held in separate bank accounts and principally consists of amounts at DTE Securitization I and DTE Securitization II to pay for debt service and other qualified costs. Restricted cash designated for payments within one year is classified as a Current Asset.
Financing Receivables
Financing Receivables
Financing receivables are primarily composed of trade receivables, notes receivable, and unbilled revenue. The Registrants' financing receivables are stated at net realizable value.
DTE Energy had unbilled revenues of $1.3 billion and $1.0 billion at December 31, 2025 and 2024, respectively, including $322 million and $303 million of DTE Electric unbilled revenues, respectively, included in Customer Accounts receivable.
The Registrants monitor the credit quality of their financing receivables on a regular basis by reviewing credit quality indicators and monitoring for trigger events, such as a credit rating downgrade or bankruptcy. Credit quality indicators include, but are not limited to, ratings by credit agencies where available, collection history, collateral, counterparty financial statements and other internal metrics. Utilizing such data, the Registrants have determined three internal grades of credit quality. Internal grade 1 includes financing receivables for counterparties where credit rating agencies have ranked the counterparty as investment grade. To the extent credit ratings are not available, the Registrants utilize other credit quality indicators to determine the level of risk associated with the financing receivable. Internal grade 1 may include financing receivables for counterparties for which credit rating agencies have ranked the counterparty as below investment grade; however, due to favorable information on other credit quality indicators, the Registrants have determined the risk level to be similar to that of an investment grade counterparty. Internal grade 2 includes financing receivables for counterparties with limited credit information and those with a higher risk profile based upon credit quality indicators. Internal grade 3 reflects financing receivables for which the counterparties have the greatest level of risk, including those in bankruptcy status.
The following represents the Registrants' financing receivables by year of origination as determined by the date the original agreement was executed, classified by internal grade of credit risk, including current year-to-date gross write-offs, if any. The related credit quality indicators and risk ratings utilized to develop the internal grades have been updated through December 31, 2025.
DTE Energy
DTE Electric(a)
Year of Origination
202520242023 and priorTotal2025 and prior
(In millions)
Notes receivable
Internal grade 1$247 $4 $27 $278 $274 
Internal grade 24 923 250 1,177 — 
Total notes receivable(b)
$251 $927 $277 $1,455 $274 
Net investment in leases
Internal grade 1$— $— $34 $34 $— 
Internal grade 2— 2 — 2 — 
Total net investment in leases(b)
$— $2 $34 $36 $— 
_______________________________________
(a)For DTE Electric, $247 million is included in Internal grade 1 with a 2025 year of origination.
(b)For DTE Energy, the current portion is included in Current Assets — Other on the Consolidated Statements of Financial Position. For DTE Electric, the amounts are included in Other Assets — Other on the Consolidated Statements of Financial Position.
The allowance for doubtful accounts on accounts receivable for the utility entities is generally calculated using an aging approach that utilizes rates developed in reserve studies. DTE Electric and DTE Gas establish an allowance for uncollectible accounts based on historical losses and management's assessment of existing and future economic conditions, customer trends and other factors. Customer accounts are generally considered delinquent if the amount billed is not received by the due date, which is typically in 21 days, however, factors such as assistance programs may delay aggressive action. DTE Electric and DTE Gas generally assess late payment fees on trade receivables based on past-due terms with customers. Customer accounts are written off when collection efforts have been exhausted. The time period for write-off is 150 days after service has been terminated.
The customer allowance for doubtful accounts for non-utility businesses and other receivables for both utility and non-utility businesses is generally calculated based on specific review of probable future collections based on receivable balances generally in excess of 30 days. Existing and future economic conditions, customer trends and other factors are also considered. Receivables are written off on a specific identification basis and determined based upon the specific circumstances of the associated receivable.
Notes receivable for DTE Energy are primarily comprised of loans, MISO deposits, and finance lease receivables that are included in Notes Receivable and Other current assets on DTE Energy's Consolidated Statements of Financial Position. Notes receivable for DTE Electric are primarily comprised of MISO deposits and loans that are included in current Notes receivable and Other long-term assets on DTE Electric's Consolidated Statements of Financial Position.
The Registrants establish an allowance for credit loss for principal and interest amounts due that are estimated to be uncollectible in accordance with the contractual terms of the note receivable. In determining the allowance for credit losses for notes receivable, the Registrants consider the historical payment experience and other factors that are expected to have a specific impact on the counterparty's ability to pay including existing and future economic conditions. Notes receivable are typically considered delinquent when payment is not received for periods ranging from 60 to 120 days. If amounts are no longer probable of collection, the Registrants may consider the note receivable impaired, adjust the allowance, and cease accruing interest (nonaccrual status).
Cash payments received on nonaccrual status notes receivable, that do not bring the account contractually current, are first applied to the contractually owed past due interest, with any remainder applied to principal. Accrual of interest is generally resumed when the note receivable becomes contractually current.
The following tables present a roll-forward of the activity for the Registrants' financing receivables credit loss reserves:
DTE EnergyDTE Electric
Trade accounts receivable
Other receivables(a)
TotalTrade and other accounts receivable
(In millions)
Balance at December 31, 2022$78 $1 $79 $49 
Current period provision52 — 52 36 
Write-offs charged against allowance(112)— (112)(72)
Recoveries of amounts previously written off44 — 44 28 
Balance at December 31, 2023$62 $1 $63 $41 
Current period provision74 2 76 49 
Write-offs charged against allowance(108)— (108)(70)
Recoveries of amounts previously written off41 — 41 26 
Balance at December 31, 2024$69 $3 $72 $46 
Current period provision69 — 69 44 
Write-offs charged against allowance(116)— (116)(74)
Recoveries of amounts previously written off37 — 37 25 
Balance at December 31, 2025$59 $3 $62 $41 
____________________________________
(a)Other receivables includes reserves on notes receivable and Accounts receivable — Other.
Uncollectible expense for the Registrants is primarily comprised of the current period provision for allowance for doubtful accounts and is summarized as follows:
Year Ended December 31,
202520242023
(In millions)
DTE Energy$70 $74 $55 
DTE Electric$45 $50 $38 
There are no material amounts of past due financing receivables for the Registrants as of December 31, 2025.
Inventories
Inventories
Inventory related to utility and non-utility operations is valued at the lower of cost or net realizable value, where cost is generally valued using average cost. Inventory primarily includes fuel, gas, materials, and supplies. Other inventories include RECs, emission allowances, and other environmental products primarily in the Energy Trading segment.
Property, Retirement and Maintenance, and Depreciation and Amortization and Capitalized Software
Property, Retirement and Maintenance, and Depreciation and Amortization
Property is stated at cost and includes construction-related labor, materials, overheads, and AFUDC for utility property. The cost of utility properties retired is charged to accumulated depreciation. Expenditures for maintenance and repairs are charged to expense when incurred.
Utility property at DTE Electric and DTE Gas is depreciated over its estimated useful life using straight-line rates approved by the MPSC. DTE Energy's non-utility property is depreciated over its estimated useful life using the straight-line method. Depreciation and amortization expense also includes the amortization of certain regulatory assets and liabilities for the Registrants.
The cost of nuclear fuel is capitalized. The amortization of nuclear fuel is included within Fuel, purchased power, and gas — utility in the DTE Energy Consolidated Statements of Operations, and Fuel and purchased power in the DTE Electric Consolidated Statements of Operations, and is recorded using the units-of-production method.
Capitalized software costs are classified as Property, plant, and equipment and the related amortization is included in Accumulated depreciation and amortization on the Registrants' Consolidated Statements of Financial Position. The Registrants capitalize the costs associated with computer software developed or obtained for use in their businesses. The Registrants amortize capitalized software costs on a straight-line basis over the expected period of benefit, ranging from 3 to 15 years for both DTE Energy and DTE Electric.
Long-Lived Assets
Long-Lived Assets
Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of an asset may not be recoverable. If the carrying amount of the asset exceeds the expected undiscounted future cash flows generated by the asset, an impairment loss is recognized resulting in the asset being written down to its estimated fair value. Assets to be disposed of are reported at the lower of the carrying amount or fair value, less costs to sell.
Goodwill
Goodwill
DTE Energy has goodwill resulting from business combinations. For each reporting unit, DTE Energy performs an impairment test annually or whenever events or circumstances indicate that the value of goodwill may be impaired.
Intangible Assets DTE Energy amortizes contract intangible assets on a straight-line basis over the expected period of benefit.
Cloud Computing Arrangements
Cloud Computing Arrangements
The Registrants capitalize implementation costs incurred in a cloud computing arrangement that is a service contract consistent with capitalized implementation costs incurred to develop or obtain internal-use software. Capitalized costs are recorded in Other noncurrent assets on the Consolidated Statements of Financial Position and amortization of the costs is reflected in Operation and maintenance within the Consolidated Statements of Operations. Costs are amortized on a straight-line basis over the life of the contract. Contracts primarily involve the implementation or upgrade of cloud-based solutions for generation and distribution operations and customer service support.
Excise and Sales Taxes and Income Taxes
Excise and Sales Taxes
The Registrants record the billing of excise and sales taxes as a receivable with an offsetting payable to the applicable taxing authority, with no net impact on the Registrants’ Consolidated Statements of Operations.
Deferred tax assets and liabilities are recognized for the estimated future tax effect of temporary differences between the tax basis of assets or liabilities and the reported amounts in the Registrants' Consolidated Financial Statements.
Deferred Debt Costs
Deferred Debt Costs
The costs related to the issuance of long-term debt are deferred and amortized over the life of each debt issue. The deferred amounts are included as a direct deduction from the carrying amount of each debt issue in Mortgage bonds, notes, and other and Securitization bonds on the Registrants' Consolidated Statements of Financial Position and in Junior subordinated debentures on DTE Energy's Consolidated Statements of Financial Position. In accordance with MPSC regulations applicable to DTE Energy’s electric and gas utilities, the unamortized discount, premium, and expense related to utility debt redeemed with a refinancing are amortized over the life of the replacement issue. Discounts, premiums, and expense on early redemptions of debt associated with DTE Energy's non-utility operations are charged to earnings.
Investments in Debt and Equity Securities
Investments in Debt and Equity Securities
The Registrants generally record investments in debt and equity securities at market value with unrealized gains or losses included in earnings. Changes in the fair value of Fermi 2 nuclear decommissioning investments are recorded as adjustments to Regulatory assets or liabilities, due to a recovery mechanism from customers. The Registrants' equity investments are reviewed for impairment each reporting period. If the assessment indicates that an impairment exists, a loss is recognized resulting in the equity investment being written down to its estimated fair value.
DTE Energy Foundation
DTE Energy Foundation
DTE Energy made charitable contributions to the DTE Energy Foundation of $20 million and $10 million for the years ended December 31, 2025 and 2024, respectively. DTE Energy made no such contribution for the year ended December 31, 2023. The DTE Energy Foundation is a non-consolidated not-for-profit private foundation, the purpose of which is to contribute to and assist charitable organizations.
Recently Adopted Pronouncements and Recently Issued Pronouncements
Recently Adopted Pronouncements
In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740): Improvements to Income Tax Disclosures. The amendments in this update require enhanced income tax disclosures, particularly related to a reporting entity's effective tax rate reconciliation and income taxes paid. For the rate reconciliation table, the update requires additional categories of information about federal, state, and foreign taxes and details about significant reconciling items, subject to a quantitative threshold. Income taxes paid must be similarly disaggregated by federal, state, and foreign based on a quantitative threshold. The Registrants adopted the ASU effective January 1, 2025 using the retrospective approach, with no impact on the Registrants' financial position or results of operations. Additional required disclosures have been included in Note 10 to the Consolidated Financial Statements, "Income Taxes."
Recently Issued Pronouncements
In November 2024, the FASB issued ASU No. 2024-03, Income Statement-Reporting Comprehensive Income – Expense Disaggregation Disclosures (Subtopic 220-40): Disaggregation of Income Statement Expenses, as amended. The amendments in this update require disaggregated disclosure of income statement expense captions into specified categories in disclosures within the footnotes to the financial statements. The ASU is effective for the Registrants for annual reporting periods beginning after December 15, 2026, and for interim reporting periods beginning after December 15, 2027. The guidance may be applied on a prospective or retrospective basis. Early adoption is permitted. The Registrants will apply the guidance upon the effective date.
In July 2025, the FASB issued ASU No. 2025-05, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses for Accounts Receivable and Contract Assets, which provides a practical expedient related to the estimation of expected credit losses for current accounts receivable and current contract assets arising from transactions accounted for under ASC 606. The ASU is effective for the Registrants for annual and interim periods beginning after December 15, 2025. The guidance should be applied on a prospective basis. Early adoption is permitted. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements.
In September 2025, the FASB issued ASU No. 2025-06, Intangibles – Goodwill and Other – Internal-Use Software (Subtopic 350-40): Targeted Improvements to the Accounting for Internal-Use Software. The amendments in this update modernize the accounting guidance for the costs to develop software for internal use. The amendments remove all references to a sequential software development method (referred to as "project stages") throughout ASC 350-40 and clarifies the threshold entities should apply to begin capitalizing eligible costs. The ASU is effective for the Registrants for annual and interim periods beginning after December 15, 2027. The guidance may be applied on a prospective, retrospective, or modified transition basis. Early adoption is permitted. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements.
Revenue
Revenue is measured based upon the consideration specified in a contract with a customer at the time when performance obligations are satisfied. A performance obligation is a promise in a contract to transfer a distinct good or service or a series of distinct goods or services to the customer. The Registrants recognize revenue when performance obligations are satisfied by transferring control over a product or service to a customer. The Registrants have determined control to be transferred when the product is delivered, or the service is provided to the customer.
Rates for DTE Electric and DTE Gas include provisions to adjust billings for fluctuations in fuel and purchased power costs, cost of natural gas, and certain other costs. Revenues are adjusted for differences between actual costs subject to reconciliation and the amounts billed in current rates. Under or over recovered revenues related to these cost recovery mechanisms are included in Regulatory assets or liabilities on the Registrants' Consolidated Statements of Financial Position and are recovered or returned to customers through adjustments to the billing factors.
Asset Retirement Obligations
DTE Electric has a legal retirement obligation for the decommissioning costs for its Fermi 1 and Fermi 2 nuclear plants, dismantlement of facilities located on leased property, and various other operations. DTE Electric has conditional retirement obligations for asbestos and PCB removal at certain of its power plants and various distribution equipment. DTE Gas has conditional retirement obligations for gas pipelines, certain service centers, and compressor and gate stations. The Registrants recognize such obligations as liabilities at fair market value when they are incurred, which generally is at the time the associated assets are placed in service. Fair value is measured using expected future cash outflows discounted at the Registrants' credit-adjusted risk-free rate. For its utility operations, the Registrants recognize in the Consolidated Statements of Operations removal costs in accordance with regulatory treatment. Any differences between costs recognized related to asset retirement and those reflected in rates are recognized as either a Regulatory asset or liability on the Consolidated Statements of Financial Position.
If a reasonable estimate of fair value cannot be made in the period in which the retirement obligation is incurred, such as for assets with indeterminate lives, the liability is recognized when a reasonable estimate of fair value can be made. Natural gas storage system and certain other distribution assets for DTE Gas and substations, manholes, and certain other distribution assets for DTE Electric have an indeterminate life. Therefore, no liability has been recorded for these assets.
Regulatory Assets and Liabilities
Regulatory Assets and Liabilities
DTE Electric and DTE Gas are required to record Regulatory assets and liabilities for certain transactions that would have been treated as revenue or expense in non-regulated businesses. Continued applicability of regulatory accounting treatment requires that rates be designed to recover specific costs of providing regulated services and be charged to and collected from customers. Future regulatory changes could result in the discontinuance of this accounting treatment for Regulatory assets and liabilities for some or all of the Registrants' businesses and may require the write-off of the portion of any Regulatory asset or liability that was no longer probable of recovery through regulated rates. Management believes that currently available facts support the continued use of Regulatory assets and liabilities and that all Regulatory assets and liabilities are recoverable or refundable in the current regulatory environment.
Fair Value
Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable inputs. The Registrants make certain assumptions they believe that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. Credit risk of the Registrants and their counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at December 31, 2025 and 2024. The Registrants believe they use valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.
A fair value hierarchy has been established that prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. All assets and liabilities are required to be classified in their entirety based on the lowest level of input that is significant to the fair value measurement in its entirety. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. The Registrants classify fair value balances based on the fair value hierarchy defined as follows:
•Level 1 — Consists of unadjusted quoted prices in active markets for identical assets or liabilities that the Registrants have the ability to access as of the reporting date.
•Level 2 — Consists of inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.
•Level 3 — Consists of unobservable inputs for assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost-benefit constraints.
Nuclear Decommissioning Trusts and Other Investments
Nuclear Decommissioning Trusts and Other Investments
The nuclear decommissioning trusts and other investments hold debt and equity securities directly and indirectly through commingled funds. Exchange-traded debt and equity securities held directly, as well as publicly traded commingled funds, are valued using quoted market prices in actively traded markets. Non-exchange traded fixed income securities are valued based upon quotations available from brokers or pricing services.
Non-publicly traded commingled funds holding exchange-traded equity or debt securities are valued based on stated NAVs. There are no significant restrictions for these funds and investments may be redeemed with 7 to 65 days notice depending on the fund. There is no intention to sell the investment in these commingled funds.
Private equity and other assets include a diversified group of funds that are primarily classified as NAV assets. These funds primarily invest in limited partnerships, including private equity, private real estate and private credit. Distributions are received through the liquidation of the underlying fund assets over the life of the funds. There are generally no redemption rights. The limited partner must hold the fund for its life or find a third-party buyer, which may need to be approved by the general partner. The funds are established with varied contractual durations generally in the range of 7 years to 12 years. The fund life can often be extended by several years by the general partner, and further extended with the approval of the limited partners. Unfunded commitments related to these investments totaled $179 million and $120 million as of December 31, 2025 and 2024, respectively.
Hedge funds and similar investments utilize a diversified group of strategies that attempt to capture uncorrelated sources of return. These investments include publicly traded mutual funds that are valued using quoted prices in actively traded markets, as well as insurance-linked and asset-backed securities and that are valued using quotations from broker or pricing services and limited partnerships that are classified as NAV assets.
For pricing the nuclear decommissioning trusts and other investments, a primary price source is identified by asset type, class, or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary source of a given security if the trustee determines that another price source is considered preferable. The Registrants have obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices.
Derivative Assets and Liabilities
Derivative Assets and Liabilities
Derivative assets and liabilities are comprised of physical and financial derivative contracts, including futures, forwards, options, and swaps that are both exchange-traded and over-the-counter traded contracts. Various inputs are used to value derivatives depending on the type of contract and availability of market data. Exchange-traded derivative contracts are valued using quoted prices in active markets. The Registrants consider the following criteria in determining whether a market is considered active: frequency in which pricing information is updated, variability in pricing between sources or over time, and the availability of public information. Other derivative contracts are valued based upon a variety of inputs including commodity market prices, broker quotes, interest rates, credit ratings, default rates, market-based seasonality, and basis differential factors. The Registrants monitor the prices that are supplied by brokers and pricing services and may use a supplemental price source or change the primary price source of an index if prices become unavailable or another price source is determined to be more representative of fair value. The Registrants have obtained an understanding of how these prices are derived. Additionally, the Registrants selectively corroborate the fair value of their transactions by comparison of market-based price sources. Mathematical valuation models are used for derivatives for which external market data is not readily observable, such as contracts which extend beyond the actively traded reporting period. The Registrants have established a Risk Management Committee whose responsibilities include directly or indirectly ensuring all valuation methods are applied in accordance with predefined policies. The development and maintenance of the Registrants' forward price curves has been assigned to DTE Energy's Risk Management Department, which is separate and distinct from the trading functions within DTE Energy.
Fair Value Transfer Derivatives are transferred between levels primarily due to changes in the source data used to construct price curves as a result of changes in market liquidity. Transfers in and transfers out are reflected as if they had occurred at the beginning of the period.
Derivatives, Offsetting Fair Value Amounts
Certain of DTE Energy's derivative positions are subject to netting arrangements which provide for offsetting of asset and liability positions as well as related cash collateral. Such netting arrangements generally do not have restrictions. Under such netting arrangements, DTE Energy offsets the fair value of derivative instruments with cash collateral received or paid for those contracts executed with the same counterparty, which reduces DTE Energy's Total Assets and Liabilities. Cash collateral is allocated between the fair value of derivative instruments and customer accounts receivable and payable with the same counterparty on a pro-rata basis to the extent there is exposure. Any cash collateral remaining, after the exposure is netted to zero, is reflected in Accounts receivable and Accounts payable as collateral paid or received, respectively.
DTE Energy also provides and receives collateral in the form of letters of credit which can be offset against net Derivative assets and liabilities as well as Accounts receivable and payable. DTE Energy had letters of credit of $2 million issued and outstanding at December 31, 2025 and $1 million at December 31, 2024, which could be used to offset net Derivative liabilities. Letters of credit received from third parties which could be used to offset net Derivative assets were $17 million at December 31, 2025. There were none for December 31, 2024. Such balances of letters of credit are excluded from the tables below and are not netted with the recognized assets and liabilities in DTE Energy's Consolidated Statements of Financial Position.
For contracts with certain clearing agents, the fair value of derivative instruments is netted against realized positions with the net balance reflected as either 1) a Derivative asset or liability or 2) an Account receivable or payable. Other than certain clearing agents, Accounts receivable and Accounts payable that are subject to netting arrangements have not been offset against the fair value of Derivative assets and liabilities.
Derivatives, Methods of Accounting
Revenues and energy costs related to trading contracts are presented on a net basis in DTE Energy's Consolidated Statements of Operations. Commodity derivatives used for trading purposes, and financial non-trading commodity derivatives, are accounted for using the MTM method with unrealized and realized gains and losses recorded in Operating Revenues — Non-utility operations. Non-trading physical commodity sale and purchase derivative contracts are generally accounted for using the MTM method with unrealized and realized gains and losses for sales recorded in Operating Revenues — Non-utility operations and purchases recorded in Fuel, purchased power, gas, and other — non-utility.
Lessee
Lessee
Leases at DTE Energy and DTE Electric are primarily comprised of various forms of land easements, coal railcars, buildings, equipment, and computer hardware, leases with terms ranging from approximately 2 to 52 years.
A lease is deemed to exist when the Registrants have the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration paid. The right to control is deemed to occur when the Registrants have the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.
In accordance with ASC Subtopic 980-842, Regulated Operations - Leases, DTE Electric recognizes expense for operating leases using the timing that conforms to the regulatory rate treatment as rental payments are recovered from customers.
Lease liabilities are determined utilizing the discount rate implicit in the lease when it is readily determinable. When the rate implicit in the lease is not readily determinable, the incremental borrowing rate is used. The incremental borrowing rates for DTE Electric and DTE Gas have been determined utilizing respective secured borrowing rates for first mortgage bonds with like tenors of remaining lease terms. Incremental borrowing rates for non-utility entities have been determined utilizing an implied secured borrowing rate based upon an unsecured rate for a similar tenor of remaining lease terms, which is then adjusted for the estimated impact of collateral.
The Registrants have certain leases which contain renewal or purchase options. Where the renewal options were deemed reasonably certain to occur, the impacts of such options were included in the determination of the right of use assets and lease liabilities. The Registrants have determined that it is not reasonably certain that purchase options will be utilized and have not included the impact in the determination of right of use assets and lease liabilities for the subject leases.
Certain leases of the Registrants contain escalation clauses whereby the payments are adjusted for consumer price or labor indices, as well as non-index based escalations for percentage increases. The Registrants also have leases with variable payments based upon the usage of the leased assets.
Certain leases contain provisions whereby the Registrants have the option to terminate the lease agreement by giving notice of such termination during the time frames specified in the respective lease. The Registrants have considered such provisions in the determination of the lease term when it is reasonably certain that the lease would be terminated.
The Registrants have agreements with lease and non-lease components, which are generally accounted for separately. Consideration in a lease is allocated between lease and non-lease components based upon the estimated relative standalone prices. The Registrants have certain coal railcar leases for which non-lease and lease components are accounted for as a single lease component, as permitted under Topic 842.
Lessor
Lessor
DTE Energy leases various assets under operating leases for a pipeline, energy facilities and related equipment. Such leases are comprised of both fixed payments and variable payments which are contingent on volumes, with terms ranging from 10 to 24 years. Generally, the operating leases do not have renewal provisions or options to purchase the assets at the end of the lease. The operating leases generally do not have termination for convenience provisions. Termination may be allowed under specific circumstances stated in the lease contract, such as under an event of default.
Certain of the finance and operating leases have lease terms that extend to the end of the estimated economic life of the leased assets, thereby resulting in no residual value. Any remaining residual values under the finance and operating leases are expected to be recovered through rates, renewals or new lease contracts. Residual values have been determined using the estimated economic life of the leased assets. The finance and operating leases do not contain residual value guarantees.
Certain of the operating leases have both lease and non-lease components. The lease and non-lease components are allocated based upon estimated relative standalone selling prices.
A lease is deemed to exist when the Registrants have provided other parties with the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration received. The right to control is deemed to occur when the Registrants have provided other parties with the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.
Stock-Based Compensation
DTE Energy records compensation expense at fair value over the vesting period for all awards it grants.
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 Variable Interest Entities
The table below summarizes the major Consolidated Statements of Financial Position items for consolidated VIEs as of December 31, 2025 and 2024. All assets and liabilities of a consolidated VIE are presented where it has been determined that a consolidated VIE has either (1) assets that can be used only to settle obligations of the VIE or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary. Assets and liabilities of the DTE Securitization entities have been aggregated due to their similar nature and are separately stated in the table below, comprising the entirety of the DTE Electric amounts. For all other VIEs, assets and liabilities are also aggregated due to their similar nature and presented together with the DTE Securitization entities in the DTE Energy amounts below. VIEs, in which DTE Energy holds a majority voting interest and is the primary beneficiary, that meet the definition of a business and whose assets can be used for purposes other than the settlement of the VIE's obligations have been excluded from the table.
During Q4 2025, a consolidated VIE of DTE Vantage completed a contract that previously restricted certain assets of the VIE to be used only to settle the VIE's obligations. As a result, the assets and liabilities of the VIE, which primarily include receivables and payables, meet the exclusion criteria above. Accordingly, these assets and liabilities have been removed from the DTE Energy amounts for 2025 in the table below.
Amounts for the Registrants' consolidated VIEs are as follows:
December 31,
20252024
DTE EnergyDTE ElectricDTE EnergyDTE Electric
(In millions)
ASSETS
Cash and cash equivalents$5 $— $6 $— 
Restricted cash42 42 64 48 
Accounts receivable10 6 27 6 
Securitized regulatory assets619 619 690 690 
Notes receivable(a)
68 — 657 — 
Other current and long-term assets1 — 1 — 
$745 $667 $1,445 $744 
LIABILITIES
Accounts payable$— — $26 $— 
Accrued interest11 11 12 12 
Regulatory liabilities — current23 23 27 27 
Securitization bonds(b)
636 636 706 706 
Other current and long-term liabilities4 — 20 — 
$674 $670 $791 $745 
_______________________________________
(a)At December 31, 2025 and December 31, 2024, Notes receivable includes $2 million and $14 million, respectively, reported in Current Assets — Other on DTE Energy's Consolidated Statements of Financial Position.
(b)Includes $75 million and $71 million reported in Current portion of long-term debt on the Registrants' Consolidated Statements of Financial Position at December 31, 2025 and December 31, 2024, respectively.
v3.25.4
Significant Accounting Policies (Tables)
 12 Months Ended
Dec. 31, 2025
Accounting Policies [Abstract]  
Schedule of Other Income
The following is a summary of DTE Energy's Other income:
Year Ended December 31,
202520242023
(In millions)
Allowance for equity funds used during construction$105 $86 $42 
Equity earnings of equity method investees47 15 3 
Contract services43 34 26 
Investment income(a)
17 17 17 
Other18 15 14 
$230 $167 $102 
_______________________________________
(a)Investment losses are recorded separately to Other expenses on the Consolidated Statements of Operations.
The following is a summary of DTE Electric's Other income:
Year Ended December 31,
202520242023
(In millions)
Allowance for equity funds used during construction$103 $84 $40 
Contract services43 33 25 
Investment income(a)
14 13 11 
Other11 14 11 
$171 $144 $87 
_______________________________________
(a)Investment losses are recorded separately to Other expenses on the Consolidated Statements of Operations.
Schedule of Accumulated Other Comprehensive Income (Loss)
The following table summarizes the changes in DTE Energy's Accumulated other comprehensive income (loss) by component(a) for the years ended December 31, 2025 and 2024:
Net Unrealized Gain (Loss) on Derivatives
Benefit Obligations(b)
Foreign Currency TranslationTotal
(In millions)
Balance, December 31, 2023$(17)$(52)$2 $(67)
Other comprehensive income (loss) before reclassifications47 (3)(7)37 
Amounts reclassified from Accumulated other comprehensive loss— 4 — 4 
Net current period Other comprehensive income (loss)47 1 (7)41 
Balance, December 31, 2024$30 $(51)$(5)$(26)
Other comprehensive income (loss) before reclassifications(8)(9)3 (14)
Amounts reclassified from Accumulated other comprehensive loss(3)4 — 1 
Net current period Other comprehensive income (loss)(11)(5)3 (13)
Balance, December 31, 2025$19 $(56)$(2)$(39)
______________________________________
(a)All amounts are net of tax, except for foreign currency translation.
(b)Benefit obligations activity includes changes in actuarial (gain) loss and prior service cost in DTE Energy's pension and other postretirement benefit plans. Refer to Note 20 to the Consolidated Financial Statements, "Retirement Benefits and Trusteed Assets," for details regarding this activity.
Schedule of Financing Receivables Classified by Internal Grade of Credit Risk
The following represents the Registrants' financing receivables by year of origination as determined by the date the original agreement was executed, classified by internal grade of credit risk, including current year-to-date gross write-offs, if any. The related credit quality indicators and risk ratings utilized to develop the internal grades have been updated through December 31, 2025.
DTE Energy
DTE Electric(a)
Year of Origination
202520242023 and priorTotal2025 and prior
(In millions)
Notes receivable
Internal grade 1$247 $4 $27 $278 $274 
Internal grade 24 923 250 1,177 — 
Total notes receivable(b)
$251 $927 $277 $1,455 $274 
Net investment in leases
Internal grade 1$— $— $34 $34 $— 
Internal grade 2— 2 — 2 — 
Total net investment in leases(b)
$— $2 $34 $36 $— 
_______________________________________
(a)For DTE Electric, $247 million is included in Internal grade 1 with a 2025 year of origination.
(b)For DTE Energy, the current portion is included in Current Assets — Other on the Consolidated Statements of Financial Position. For DTE Electric, the amounts are included in Other Assets — Other on the Consolidated Statements of Financial Position.
Schedule of Roll-Forward of Activity for Financing Receivables Credit Loss Reserves
The following tables present a roll-forward of the activity for the Registrants' financing receivables credit loss reserves:
DTE EnergyDTE Electric
Trade accounts receivable
Other receivables(a)
TotalTrade and other accounts receivable
(In millions)
Balance at December 31, 2022$78 $1 $79 $49 
Current period provision52 — 52 36 
Write-offs charged against allowance(112)— (112)(72)
Recoveries of amounts previously written off44 — 44 28 
Balance at December 31, 2023$62 $1 $63 $41 
Current period provision74 2 76 49 
Write-offs charged against allowance(108)— (108)(70)
Recoveries of amounts previously written off41 — 41 26 
Balance at December 31, 2024$69 $3 $72 $46 
Current period provision69 — 69 44 
Write-offs charged against allowance(116)— (116)(74)
Recoveries of amounts previously written off37 — 37 25 
Balance at December 31, 2025$59 $3 $62 $41 
____________________________________
(a)Other receivables includes reserves on notes receivable and Accounts receivable — Other.
Schedule of Uncollectible Expense
Uncollectible expense for the Registrants is primarily comprised of the current period provision for allowance for doubtful accounts and is summarized as follows:
Year Ended December 31,
202520242023
(In millions)
DTE Energy$70 $74 $55 
DTE Electric$45 $50 $38 
Schedule of Finite-Lived Intangible Assets
The Registrants have certain Intangible assets as shown below:
December 31, 2025December 31, 2024
Useful LivesGross Carrying ValueAccumulated AmortizationNet Carrying ValueGross Carrying ValueAccumulated AmortizationNet Carrying Value
(In millions)
Intangible assets subject to amortization
Contract intangibles
5 to 39 years
$306 $(137)$169 $246 $(119)$127 
Carbon offsets16 — 16 14 — 14 
Renewable energy credits— — — 1 — 1 
Other3 — 3 2 — 2 
Intangible assets not subject to amortization(a)
19 — 19 17 — 17 
DTE Energy Long-term intangible assets$325 $(137)$188 $263 $(119)$144 
______________________________________
(a)Amounts are charged to expense, using average cost, as they are consumed in the operation of the business. DTE Electric intangible assets include the Renewable energy credits above, which are included in Other Assets — Other on the DTE Electric Consolidated Statements of Financial Position.
Schedule of Indefinite-Lived Intangible Assets
The Registrants have certain Intangible assets as shown below:
December 31, 2025December 31, 2024
Useful LivesGross Carrying ValueAccumulated AmortizationNet Carrying ValueGross Carrying ValueAccumulated AmortizationNet Carrying Value
(In millions)
Intangible assets subject to amortization
Contract intangibles
5 to 39 years
$306 $(137)$169 $246 $(119)$127 
Carbon offsets16 — 16 14 — 14 
Renewable energy credits— — — 1 — 1 
Other3 — 3 2 — 2 
Intangible assets not subject to amortization(a)
19 — 19 17 — 17 
DTE Energy Long-term intangible assets$325 $(137)$188 $263 $(119)$144 
______________________________________
(a)Amounts are charged to expense, using average cost, as they are consumed in the operation of the business. DTE Electric intangible assets include the Renewable energy credits above, which are included in Other Assets — Other on the DTE Electric Consolidated Statements of Financial Position.
Schedule of Estimated Contract Intangible Amortization Expense
The following table summarizes DTE Energy's estimated contract intangible amortization expense expected to be recognized during each year through 2030:
20262027202820292030
(In millions)
Estimated amortization expense$24 $24 $24 $24 $22 
Schedule of Cloud Computing Costs
The following balances for cloud computing costs relate to DTE Energy:
Year Ended December 31,
202520242023
(In millions)
Amortization expense of capitalized cloud computing costs$13 $12 $10 
Gross value of capitalized cloud computing costs$94 $64 
Accumulated amortization of capitalized cloud computing costs$40 $27 
The following balances for cloud computing costs relate to DTE Electric:
Year Ended December 31,
202520242023
(In millions)
Amortization expense of capitalized cloud computing costs$10 $10 $8 
Gross value of capitalized cloud computing costs$69 $51 
Accumulated amortization of capitalized cloud computing costs$32 $22 
Schedule of Other Accounting Policies
See the following notes for other accounting policies impacting the Registrants’ Consolidated Financial Statements:
NoteTitle
5Revenue
6Property, Plant, and Equipment
8Asset Retirement Obligations
9Regulatory Matters
10Income Taxes
12Fair Value
13Financial and Other Derivative Instruments
17Leases
20Retirement Benefits and Trusteed Assets
21Stock-Based Compensation
22Segment and Related Information
23Related Party Transactions
v3.25.4
Acquisition (Tables)
 12 Months Ended
Dec. 31, 2025
Business Combination [Abstract]  
Schedule of Cost Allocated to Underlying Net Assets
The acquisition was accounted for using the acquisition method of accounting for business combinations. Accordingly, the cost was allocated to the underlying net assets based on their respective fair values as shown below:
(In millions)
Cash$6 
Contract intangibles57 
Property, plant, and equipment, net135 
Working capital, other assets and liabilities18 
Total$216 
v3.25.4
Revenue (Tables)
 12 Months Ended
Dec. 31, 2025
Revenue from Contract with Customer [Abstract]  
Schedule of Disaggregation of Revenue By Segment and Revenues Outside the Scope of Topic 606
The following is a summary of revenues disaggregated by segment for DTE Energy:
Year Ended December 31,
202520242023
(In millions)
Electric(a)
Residential$3,144 $3,045 $2,847 
Commercial2,195 2,263 2,114 
Industrial652 715 732 
Other(b)
944 270 125 
Total Electric operating revenues$6,935 $6,293 $5,818 
Gas
Gas sales$1,521 $1,307 $1,324 
End User Transportation255 246 250 
Intermediate Transportation87 83 85 
Other(b)
189 162 89 
Total Gas operating revenues$2,052 $1,798 $1,748 
Other segment operating revenues
DTE Vantage$696 $753 $809 
Energy Trading$6,477 $3,843 $4,612 
_______________________________________
(a)Revenues generally represent those of DTE Electric, except $50 million, $16 million, and $14 million of Other revenues related to DTE Sustainable Generation for the years ended December 31, 2025, 2024, and 2023, respectively.
(b)Includes revenue adjustments related to various regulatory mechanisms, including the PSCR at the Electric segment and GCR at the Gas segment, and interconnection sales in the Electric segment. Revenues related to these mechanisms may vary based on changes in the cost of fuel, purchased power, and gas.
Revenues included the following which were outside the scope of Topic 606:
Year Ended December 31,
202520242023
(In millions)
Electric — Alternative Revenue Programs$48 $43 $36 
Electric — Other revenues$23 $25 $22 
Gas — Alternative Revenue Programs$8 $21 $16 
Gas — Other revenues$12 $11 $8 
DTE Vantage — Leases$61 $60 $59 
Energy Trading — Derivatives$4,571 $2,540 $3,436 
Schedule of Deferred Revenue Activity
The following is a summary of deferred revenue activity for DTE Energy:
Year Ended December 31,
20252024
(In millions)
Beginning Balance, January 1$138 $106 
Increases due to cash received or receivable, excluding amounts recognized as revenue during the period166 132 
Revenue recognized that was included in the deferred revenue balance at the beginning of the period(134)(100)
Ending Balance, December 31$170 $138 
Schedule of Expected Recognition of Deferred Revenue and Expected Timing of Performance Obligation Satisfaction
The following table represents deferred revenue amounts for DTE Energy that are expected to be recognized as revenue in future periods:
DTE Energy
(In millions)
2026$169 
20271 
2028— 
2029— 
2030— 
2031 and thereafter— 
$170 
The Registrants expect to recognize revenue for the following amounts related to fixed consideration associated with remaining performance obligations in each of the future periods noted:
DTE EnergyDTE Electric
(In millions)
2026$189 $1 
2027168 — 
2028110 — 
202991 — 
203081 — 
2031 and thereafter292 — 
$931 $1 
v3.25.4
Property, Plant, and Equipment (Tables)
 12 Months Ended
Dec. 31, 2025
Property, Plant and Equipment [Abstract]  
Schedule of Property, Plant and Equipment by Classification and Depreciation and Amortization Expense
The following is a summary of Property, plant, and equipment by classification as of December 31:
20252024
Property, plant, and equipment(In millions)
DTE Electric
Distribution$16,316 $14,995 
Dispatchable generation8,647 8,428 
Renewable generation5,102 3,933 
Other3,742 3,445 
Total DTE Electric33,807 30,801 
DTE Gas
Distribution6,826 6,334 
Transmission1,267 1,212 
Storage589 586 
Other530 500 
Total DTE Gas9,212 8,632 
DTE Vantage1,191 1,135 
Other413 272 
Total DTE Energy$44,623 $40,840 
Accumulated depreciation and amortization
DTE Electric
Distribution$(3,729)$(3,513)
Dispatchable generation(2,584)(2,146)
Renewable generation(760)(615)
Other(1,166)(1,130)
Total DTE Electric(8,239)(7,404)
DTE Gas
Distribution(1,413)(1,319)
Transmission(291)(278)
Storage(140)(138)
Other(228)(210)
Total DTE Gas(2,072)(1,945)
DTE Vantage(564)(520)
Other(95)(78)
Total DTE Energy$(10,970)$(9,947)
Net DTE Energy Property, plant, and equipment$33,653 $30,893 
Net DTE Electric Property, plant, and equipment$25,568 $23,397 
The following is a summary of Depreciation and amortization expense for DTE Energy:
Year Ended December 31,
202520242023
(In millions)
Property, plant, and equipment$1,265 $1,316 $1,239 
Regulatory assets and liabilities550 394 344 
Intangible assets18 16 15 
Other8 6 8 
$1,841 $1,732 $1,606 
The following is a summary of Depreciation and amortization expense for DTE Electric:
Year Ended December 31,
202520242023
(In millions)
Property, plant, and equipment$1,039 $1,089 $1,029 
Regulatory assets and liabilities486 338 292 
Other5 5 5 
$1,530 $1,432 $1,326 
Schedule of AFUDC and Capitalized Interest Rates
The AFUDC and capitalized interest rates were as follows for the years ended December 31:
202520242023
DTE Electric AFUDC6.01 %5.56 %5.53 %
DTE Gas AFUDC5.80 %5.45 %5.41 %
Non-regulated businesses capitalized interest4.50 %4.25 %3.00 %
Schedule of AFUDC and Interest Capitalized
The following is a summary of AFUDC and interest capitalized for the years ended December 31:
202520242023
DTE Energy(In millions)
Allowance for debt funds used during construction and interest capitalized$47 $36 $20 
Allowance for equity funds used during construction105 86 42 
Total$152 $122 $62 
202520242023
DTE Electric(In millions)
Allowance for debt funds used during construction$45 $34 $15 
Allowance for equity funds used during construction103 84 40 
Total$148 $118 $55 
Schedule of Utility Property, Plant, and Equipment The average estimated useful life for each major class of utility Property, plant, and equipment as of December 31, 2025 follows:
Estimated Useful Lives in Years
UtilityDistributionGenerationTransmissionStorage
DTE Electric3832N/AN/A
DTE Gas55N/A6760
Schedule of Capitalized Software
The following balances for capitalized software relate to DTE Energy:
Year Ended December 31,
202520242023
(In millions)
Amortization expense of capitalized software$164 $192 $189 
Gross carrying value of capitalized software$1,211 $1,005 
Accumulated amortization of capitalized software$474 $476 
The following balances for capitalized software relate to DTE Electric:
Year Ended December 31,
202520242023
(In millions)
Amortization expense of capitalized software$146 $175 $172 
Gross carrying value of capitalized software$1,084 $910 
Accumulated amortization of capitalized software$399 $414 
v3.25.4
Jointly-Owned Utility Plant (Tables)
 12 Months Ended
Dec. 31, 2025
Jointly Owned Utility Plant, Net Ownership Amount [Abstract]  
Schedule of Jointly-Owned Utility Plants
DTE Electric's ownership information of the two utility plants as of December 31, 2025 was as follows:
Belle RiverLudington
Hydroelectric
Pumped Storage
In-service date1984-19851973
Total plant capacity1,270 MW2,290 MW
Ownership interest81%49%
Investment in Property, plant, and equipment (in millions)$1,961 $676 
Accumulated depreciation (in millions)$1,198 $171 
v3.25.4
Asset Retirement Obligations (Tables)
 12 Months Ended
Dec. 31, 2025
Asset Retirement Obligation Disclosure [Abstract]  
Schedule of Changes to Asset Retirement Obligations
Changes to Asset retirement obligations for the years ended December 31, 2025, 2024, and 2023 were as follows:
202520242023
DTE Energy(In millions)
Asset retirement obligations at January 1$4,031 $3,556 $3,460 
Accretion239 211 198 
Liabilities incurred32 324 7 
Liabilities settled(10)(14)(96)
Revision in estimated cash flows(a)
177 (46)(13)
Asset retirement obligations at December 31$4,469 $4,031 $3,556 
_______________________________________
(a)Revision in estimated cash flows was primarily due to the impact of the CCR regulations on DTE Electric's coal ash storage facility asset retirement obligations, as well as revision of estimated cash flows related to DTE Electric's Fermi 1 obligations. Refer to Note 18 to the Consolidated Financial Statements, "Commitments and Contingencies," for additional information regarding the CCR regulations.
202520242023
DTE Electric(In millions)
Asset retirement obligations at January 1$3,791 $3,326 $3,221 
Accretion226 199 185 
Liabilities incurred32 323 4 
Liabilities settled(9)(11)(81)
Revision in estimated cash flows(a)
177 (46)(3)
Asset retirement obligations at December 31$4,217 $3,791 $3,326 
_______________________________________
(a)Revision in estimated cash flows was primarily due to the impact of the CCR regulations on DTE Electric's coal ash storage facility asset retirement obligations, as well as revision of estimated cash flows related to DTE Electric's Fermi 1 obligations. Refer to Note 18 to the Consolidated Financial Statements, "Commitments and Contingencies," for additional information regarding the CCR regulations.
v3.25.4
Regulatory Matters (Tables)
 12 Months Ended
Dec. 31, 2025
Regulatory Assets and Liabilities Disclosure [Abstract]  
Schedule of Regulatory Assets
The following are balances and a brief description of the Registrants' Regulatory assets and liabilities at December 31:
DTE EnergyDTE Electric
2025202420252024
Assets(In millions)
Recoverable undepreciated costs on retiring plants$3,146 $2,986 $3,146 $2,986 
Recoverable pension and other postretirement costs
Pension1,281 1,315 949 971 
Other postretirement costs90 91 — — 
Fermi 2 asset retirement obligation895 951 895 951 
Removal costs asset700 501 700 501 
Enhanced tree trimming program deferred costs340 211 340 211 
Renewable ITC offset207 89 207 89 
Recoverable income taxes related to AFUDC equity148 116 139 107 
Energy Waste Reduction incentive115 102 94 82 
Accrued PSCR/GCR revenue112 — 111 — 
Recoverable Michigan income taxes107 119 89 99 
Ludington contract dispute costs58 31 58 31 
Energy Waste Reduction57 36 52 29 
Deferred environmental costs39 43 — — 
Unamortized loss on reacquired debt33 38 26 29 
Customer360 deferred costs29 34 29 34 
Other193 158 144 106 
7,550 6,821 6,979 6,226 
Less amount included in Current Assets(170)(50)(158)(39)
$7,380 $6,771 $6,821 $6,187 
Securitized regulatory assets$619 $690 $619 $690 
Schedule of Regulatory Liabilities
DTE EnergyDTE Electric
2025202420252024
Liabilities(In millions)
Refundable federal income taxes$1,646 $1,733 $1,318 $1,389 
Removal costs liability511 506 — — 
Non-service pension and other postretirement costs271 255 103 94 
Negative other postretirement offset205 214 133 139 
Renewable energy196 90 196 90 
Accrued PSCR/GCR refund43 136 — 111 
Other116 103 111 86 
2,988 3,037 1,861 1,909 
Less amount included in Current Liabilities(107)(181)(63)(156)
$2,881 $2,856 $1,798 $1,753 
v3.25.4
Income Taxes (Tables)
 12 Months Ended
Dec. 31, 2025
Income Tax Disclosure [Abstract]  
Schedule of Income Tax Expense Varied from Statutory Federal Income Tax Rate
The Registrants' total Income Tax Expense varied from the statutory federal income tax rate for the following reasons:
Year Ended December 31,
202520242023
(In millions)
DTE EnergyAmountPercentageAmountPercentageAmountPercentage
Income tax expense at U.S. Federal Statutory Tax Rate$326 21.0 %$288 21.0 %$329 21.0 %
Tax Credits
Production tax credits(161)(10.4)%(174)(12.7)%(91)(5.8)%
Investment tax credits(94)(6.1)%(128)(9.3)%(44)(2.8)%
Other(5)(0.3)%(4)(0.3)%(5)(0.3)%
Other Adjustments
TCJA regulatory liability amortization(65)(4.2)%(66)(4.8)%(63)(4.0)%
Other(4)(0.1)%4 0.2 %— — %
Nontaxable or Nondeductible Items
AFUDC equity(20)(1.3)%(17)(1.2)%(7)(0.5)%
Other6 0.5 %(3)(0.3)%(4)(0.2)%
Changes in Tax Laws or Rates Enacted in the Current Period16 1.0 %— — %— — %
Changes in Valuation Allowances 7 0.4 %6 0.5 %— — %
Changes in Prior Year Unrecognized Tax Benefits— — %— — %(12)(0.8)%
Foreign Tax Effects
Canada1 — %1 0.1 %— — %
State and Local Income Taxes, Net of Federal Effect (a)
$81 5.2 %$59 4.3 %$66 4.2 %
Income Tax Expense (Benefit) at Effective Tax Rate$88 5.7 %$(34)(2.5)%$169 10.8 %
_______________________________________
(a)State taxes in Michigan made up the majority (greater than 50 percent) of the tax effect in this category for all years presented. State and local income taxes in 2025 includes $14 million expense due to an Illinois tax law change.
Year Ended December 31,
202520242023
(In millions)
DTE ElectricAmountPercentageAmountPercentageAmountPercentage
Income tax expense at U.S. Federal Statutory Tax Rate$257 21.0 %$218 21.0 %$179 21.0 %
Tax Credits
Investment tax credits(95)(7.7)%(70)(6.7)%(1)(0.1)%
Production tax credits(77)(6.3)%(167)(16.0)%(79)(9.3)%
Other(4)(0.4)%(4)(0.4)%(4)(0.5)%
Other Adjustments
TCJA regulatory liability amortization(53)(4.4)%(55)(5.3)%(53)(6.2)%
Other(1)(0.1)%2 0.2 %— — %
Nontaxable or Nondeductible Items
AFUDC equity(20)(1.6)%(16)(1.6)%(7)(0.8)%
Other(2)(0.1)%(2)(0.2)%(2)(0.2)%
Changes in Prior Year Unrecognized Tax Benefits— — %— — %(7)(0.8)%
Changes in Valuation Allowances — — %5 0.4 %— — %
State and Local Income Taxes, Net of Federal Effect (a)
$66 5.4 %$57 5.5 %$52 6.1 %
Income Tax Expense (Benefit) at Effective Tax Rate$71 5.8 %$(32)(3.1)%$78 9.2 %
_______________________________________
(a)State taxes in Michigan made up the majority (greater than 50 percent) of the tax effect in this category for all years presented.
Schedule of Income Taxes Paid
Components of the Registrants' Income Taxes Paid were as follows:
Year Ended December 31,
202520242023
DTE Energy(In millions)
U.S. Federal(a)
$(266)$(230)$2 
U.S. State and Local
Michigan(5)(5)(10)
Pennsylvania1 2 2 
Other1 — 1 
(3)(3)(7)
Foreign2 3 — 
Total$(267)$(230)$(5)
_______________________________________
(a)Includes proceeds on sale of transferrable income tax credits, net of discount, in 2025 and 2024.
Year Ended December 31,
202520242023
DTE Electric(In millions)
U.S. Federal(a)
$(273)$(231)$9 
U.S. State and Local
Michigan$— $— $6 
Total$(273)$(231)$15 
_______________________________________
(a)Includes proceeds on sale of transferrable income tax credits, net of discount, in 2025 and 2024.
Schedule of Components of Income Tax Expense
Components of the Registrants' Income Tax Expense were as follows:
Year Ended December 31,
202520242023
DTE Energy(In millions)
Income (loss) from continuing operations before income tax expense (benefit)
US$1,543 $1,357 $1,559 
Foreign7 13 7 
Total$1,550 $1,370 $1,566 
Income tax expense (benefit) from continuing operations
Current tax expense (benefit)
US federal$(269)$(229)$(10)
US state and local(3)(2)(2)
Foreign2 3 — 
Total current tax expense (benefit)$(270)$(228)$(12)
Deferred tax expense (benefit)
US federal$253 $116 $103 
US state and local105 77 76 
Foreign— 1 2 
Total deferred tax expense (benefit)$358 $194 $181 
Total tax expense (benefit)
US federal$(16)$(113)$93 
US state and local102 75 74 
Foreign2 4 2 
Total tax expense (benefit)$88 $(34)$169 
Year Ended December 31,
202520242023
DTE Electric(In millions)
Income (loss) from continuing operations before income tax expense (benefit)
US$1,223 $1,040 $850 
Total$1,223 $1,040 $850 
Income tax expense (benefit) from continuing operations
Current tax expense (benefit)
US federal$(268)$(228)$1 
US state and local— — (5)
Total current tax expense (benefit)$(268)$(228)$(4)
Deferred tax expense (benefit)
US federal$256 $124 $19 
US state and local83 72 63 
Total deferred tax expense (benefit)$339 $196 $82 
Total tax expense (benefit)
US federal$(12)$(104)$20 
US state and local83 72 58 
Total tax expense (benefit)$71 $(32)$78 
Schedule of Deferred Tax Assets and Liabilities
The Registrants' deferred tax assets (liabilities) were comprised of the following at December 31:
DTE EnergyDTE Electric
2025202420252024
(In millions)
Property, plant, and equipment$(3,952)$(3,695)$(2,947)$(2,788)
Regulatory assets and liabilities(1,412)(1,272)(1,636)(1,492)
Tax credit carryforwards1,619 1,604 512 583 
Pension and benefits3 55 2 62 
Federal net operating loss carryforward180 190 24 30 
State and local net operating loss carryforwards51 68 27 42 
Investments in equity method investees(25)(28)(1)(1)
Other182 145 207 176 
(3,354)(2,933)(3,812)(3,388)
Less: Valuation allowance(46)(25)— (5)
Long-term deferred income tax liabilities$(3,400)$(2,958)$(3,812)$(3,393)
Deferred income tax assets$2,575 $2,508 $1,188 $1,209 
Deferred income tax liabilities(5,975)(5,466)(5,000)(4,602)
$(3,400)$(2,958)$(3,812)$(3,393)
Schedule of Tax Credit Sales Year of Sale The following table details the Registrants' tax credit sales, net of discount, by year of sale:
Year Ended December 31,
202520242023
(In millions)
Cash received for tax credit sales$268 $231 $— 
v3.25.4
Earnings Per Share (Tables)
 12 Months Ended
Dec. 31, 2025
Earnings Per Share [Abstract]  
Schedule of Earnings Per Share, Basic and Diluted
The following is a reconciliation of DTE Energy's basic and diluted income per share calculation for the years ended December 31:
202520242023
(In millions, except per share amounts)
Basic Earnings per Share
Net Income Attributable to DTE Energy Company1,462 $1,404 $1,397 
Less: Allocation of earnings to net restricted stock awards3 3 3 
Net income available to common shareholders — basic$1,459 $1,401 $1,394 
Average number of common shares outstanding — basic207 207 206 
Basic Earnings per Common Share$7.04 $6.78 $6.77 
Diluted Earnings per Share
Net Income Attributable to DTE Energy Company$1,462 $1,404 $1,397 
Less: Allocation of earnings to net restricted stock awards3 3 3 
Net income available to common shareholders — diluted$1,459 $1,401 $1,394 
Average number of common shares outstanding — diluted207 207 206 
Diluted Earnings per Common Share
$7.03 $6.77 $6.76 
v3.25.4
Fair Value (Tables)
 12 Months Ended
Dec. 31, 2025
Fair Value Disclosures [Abstract]  
Schedule of Assets and Liabilities Measured and Recorded at Fair Value on a Recurring Basis
The following table presents assets and liabilities for DTE Energy measured and recorded at fair value on a recurring basis:
December 31, 2025December 31, 2024
Level 1Level
 2		Level 3
Other
(a)
Netting
(b)
Net BalanceLevel 1Level
 2		Level 3
Other
(a)
Netting
(b)
Net Balance
(In millions)
Assets
Cash equivalents and Restricted cash(c)
$176 $— $— $— $— $176 $11 $— $— $— $— $11 
Nuclear decommissioning trusts
Equity securities987 — — 201 — 1,188 856 — — 147 — 1,003 
Fixed income securities133 460 — 133 — 726 124 414 — 112 — 650 
Private equity and other— — — 358 — 358 16 — — 333 — 349 
Hedge funds and similar investments228 17 — — — 245 151 16 — 61 — 228 
Cash equivalents35 — — — — 35 26 — — — — 26 
Other investments(d)
Equity securities84 — — — — 84 72 — — — — 72 
Fixed income securities9 2 — — — 11 7 — — — — 7 
Cash equivalents38 — — — — 38 29 — — — — 29 
Derivative assets
Commodity contracts(e)
Natural gas207 56 109 — (235)137 242 81 105 — (285)143 
Electricity127 115 33 — (194)81 67 69 51 — (116)71 
Environmental & Other— 46 11 — (46)11 1 47 10 — (46)12 
Other contracts— 3 — — — 3 — 21 — — — 21 
Total derivative assets334 220 153 — (475)232 310 218 166 — (447)247 
Total$2,024 $699 $153 $692 $(475)$3,093 $1,602 $648 $166 $653 $(447)$2,622 
Liabilities
Derivative liabilities
Commodity contracts(e)
Natural gas$(196)$(51)$(82)$— $227 $(102)$(217)$(70)$(123)$— $272 $(138)
Electricity(124)(59)(52)— 186 (49)(71)(52)(27)— 114 (36)
Environmental & Other(1)(31)— — 32 — (2)(39)(3)— 44 — 
Other contracts— (1)— — — (1)— (1)— — — (1)
Total$(321)$(142)$(134)$— $445 $(152)$(290)$(162)$(153)$— $430 $(175)
Net Assets (Liabilities) at end of period$1,703 $557 $19 $692 $(30)$2,941 $1,312 $486 $13 $653 $(17)$2,447 
Assets
Current$426 $130 $102 $— $(339)$319 $223 $170 $106 $— $(326)$173 
Noncurrent1,598 569 51 692 (136)2,774 1,379 478 60 653 (121)2,449 
Total Assets$2,024 $699 $153 $692 $(475)$3,093 $1,602 $648 $166 $653 $(447)$2,622 
Liabilities
Current$(240)$(106)$(67)$— $327 $(86)$(219)$(129)$(93)$— $323 $(118)
Noncurrent(81)(36)(67)— 118 (66)(71)(33)(60)— 107 (57)
Total Liabilities$(321)$(142)$(134)$— $445 $(152)$(290)$(162)$(153)$— $430 $(175)
Net Assets (Liabilities) at end of period$1,703 $557 $19 $692 $(30)$2,941 $1,312 $486 $13 $653 $(17)$2,447 
_______________________________________
(a)Amounts represent assets valued at NAV as a practical expedient for fair value.
(b)Amounts represent the impact of master netting agreements that allow DTE Energy to net gain and loss positions and cash collateral held or placed with the same counterparties.
(c)Amounts include $10 million and $8 million recorded in Restricted cash on DTE Energy's Consolidated Statements of Financial Position at December 31, 2025 and December 31, 2024, respectively. All other amounts are included in Cash and cash equivalents on DTE Energy's Consolidated Statements of Financial Position.
(d)Excludes cash surrender value of life insurance investments and certain securities classified as held-to-maturity that are recorded at amortized cost and not material to the consolidated financial statements.
(e)For contracts with a clearing agent, DTE Energy nets all activity across commodities. This can result in some individual commodities having a contra balance.
The following table presents assets for DTE Electric measured and recorded at fair value on a recurring basis as of:
December 31, 2025December 31, 2024
Level 1Level 2Level 3
Other(a)
Net Balance Level 1Level 2Level 3
Other(a)
Net Balance
(In millions)
Assets
Cash equivalents and Restricted cash(b)
$83 $— $— $— $83 $8 $— $— $— $8 
Nuclear decommissioning trusts
Equity securities987 — — 201 1,188 856 — — 147 1,003 
Fixed income securities133 460 — 133 726 124 414 — 112 650 
Private equity and other— — — 358 358 16 — — 333 349 
Hedge funds and similar investments228 17 — — 245 151 16 — 61 228 
Cash equivalents35 — — — 35 26 — — — 26 
Other investments
Equity securities33 — — — 33 26 — — — 26 
Fixed income securities— 2 — — 2 — — — — — 
Cash equivalents26 — — — 26 19 — — — 19 
Derivative assets — FTRs— — 11 — 11 — — 9 — 9 
Total$1,525 $479 $11 $692 $2,707 $1,226 $430 $9 $653 $2,318 
Assets
Current$83 $— $11 $— $94 $8 $— $9 $— $17 
Noncurrent1,442 479 — 692 2,613 1,218 430 — 653 2,301 
Total Assets$1,525 $479 $11 $692 $2,707 $1,226 $430 $9 $653 $2,318 
_______________________________________
(a)Amounts represent assets valued at NAV as a practical expedient for fair value.
(b)Amounts include $10 million and $8 million recorded in Restricted cash on DTE Electric's Consolidated Statements of Financial Position at December 31, 2025 and December 31, 2024, respectively. All other amounts are included in Cash and cash equivalents on DTE Electric's Consolidated Statements of Financial Position.
Schedule of Reconciliation of Level 3 Assets and Liabilities Measured at Fair Value on a Recurring Basis
The following table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for DTE Energy:
Year Ended December 31, 2025Year Ended December 31, 2024
Natural GasElectricityOtherTotalNatural GasElectricityOtherTotal
(In millions)
Net Assets (Liabilities) as of January 1$(18)$24 $7 $13 $22 $47 $6 $75 
Transfers into Level 3 from Level 22 — — 2 1 — — 1 
Transfers from Level 3 into Level 2— — 2 2 — 74 — 74 
Total gains (losses)
Included in earnings(a)
(25)329 4 308 16 225 (1)240 
Recorded in Regulatory liabilities— — 19 19 — — 21 21 
Purchases, issuances, and settlements:
Settlements68 (372)(21)(325)(57)(322)(19)(398)
Net Assets (Liabilities) as of December 31$27 $(19)$11 $19 $(18)$24 $7 $13 
Total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31(a)
$23 $(19)$— $4 $(47)$118 $(159)$(88)
Total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31$— $— $11 $11 $— $— $9 $9 
_______________________________________
(a)Amounts are reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, gas, and other — non-utility in DTE Energy's Consolidated Statements of Operations.
The following table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for DTE Electric:
Year Ended December 31,
20252024
(In millions)
Net Assets as of January 1$9 $7 
Total gains recorded in Regulatory liabilities19 21 
Purchases, issuances, and settlements:
Settlements(17)(19)
Net Assets as of December 31$11 $9 
Total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31$11 $9 
Schedule of Unobservable Inputs Related to Level 3 Assets and Liabilities
The following tables present the unobservable inputs related to DTE Energy's Level 3 assets and liabilities:
December 31, 2025
Commodity ContractsDerivative AssetsDerivative LiabilitiesValuation TechniquesUnobservable InputRangeWeighted Average
(In millions)
Natural Gas$109 $(82)Discounted Cash FlowForward basis price (per MMBtu)$(1.35)—$9.33 /MMBtu$(0.13)/MMBtu
Electricity$33 $(52)Discounted Cash FlowForward basis price (per MWh)$(21.82)—$17.79 /MWh$(5.58)/MWh
December 31, 2024
Commodity ContractsDerivative AssetsDerivative LiabilitiesValuation TechniquesUnobservable InputRangeWeighted Average
(In millions)
Natural Gas$105 $(123)Discounted Cash FlowForward basis price (per MMBtu)$(1.24)—$9.96 /MMBtu$(0.05)/MMBtu
Electricity$51 $(27)Discounted Cash FlowForward basis price (per MWh)$(16.34)—$17.28 /MWh$(2.74)/MWh
Schedule of Carrying Amount of Fair Value of Financial Instruments
The following table presents the carrying amount and fair value of financial instruments for DTE Energy:
December 31, 2025December 31, 2024
CarryingFair ValueCarryingFair Value
AmountLevel 1Level 2Level 3AmountLevel 1Level 2Level 3
(In millions)
Notes receivable(a), excluding lessor finance leases
$1,453 $— $— $1,482 $884 $— $— $904 
Short-term borrowings$882 $— $882 $— $1,067 $— $1,067 $— 
Notes payable(b)
$28 $— $— $28 $37 $— $— $37 
Long-term debt(c)
$25,123 $1,285 $21,204 $1,351 $21,963 $725 $18,283 $1,128 
_______________________________________
(a)Current portion included in Current Assets — Other on DTE Energy's Consolidated Statements of Financial Position. Carrying value includes credit loss reserves on Notes receivable.
(b)Included in Current Liabilities — Other and Other Liabilities — Other on DTE Energy's Consolidated Statements of Financial Position.
(c)Includes debt due within one year and excludes finance lease obligations. Carrying value also includes unamortized debt discounts and issuance costs.
The following table presents the carrying amount and fair value of financial instruments for DTE Electric:
December 31, 2025December 31, 2024
CarryingFair ValueCarryingFair Value
AmountLevel 1Level 2Level 3AmountLevel 1Level 2Level 3
(In millions)
Notes receivable — Affiliates
$— $— $— $— $42 $— $— $42 
Notes receivable — Other(a)
274 — — 289 2 — — 2 
Short-term borrowings — Other
$652 $— $652 $— $666 $— $666 $— 
Notes payable(b)
$24 $— $— $24 $35 $— $— $35 
Long-term debt(c)
$13,165 $— $12,048 $131 $11,881 $— $10,449 $127 
_______________________________________
(a)Included in Other Assets — Other on DTE Electric's Consolidated Statements of Financial Position.
(b)Included in Current Liabilities — Other and Other Liabilities — Other on DTE Electric's Consolidated Statements of Financial Position.
(c)Includes debt due within one year and excludes finance lease obligations. Carrying value also includes unamortized debt discounts and issuance costs.
Schedule of Fair Value of Nuclear Decommissioning Trust Fund Assets
The following table summarizes DTE Electric's fair value of the nuclear decommissioning trust fund assets:
December 31,
20252024
(In millions)
Fermi 2$2,523 $2,234 
Fermi 13 3 
Low-level radioactive waste26 19 
$2,552 $2,256 
Schedule of Realized Gains and Losses and Proceeds from Sale of Securities by Nuclear Decommissioning Trust Funds The following table sets forth DTE Electric's gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds:
Year Ended December 31,
202520242023
(In millions)
Realized gains$50 $47 $36 
Realized losses$(32)$(27)$(42)
Proceeds from sale of securities$717 $555 $681 
Schedule of Fair Value and Unrealized Gains and Losses for Nuclear Decommissioning Trust Funds
The following table sets forth DTE Electric's fair value and unrealized gains and losses for the nuclear decommissioning trust funds:
December 31, 2025December 31, 2024
Fair
Value		Unrealized
Gains		Unrealized LossesFair
Value		Unrealized
Gains		Unrealized Losses
(In millions)
Equity securities$1,188 $742 $(10)$1,003 $558 $(16)
Fixed income securities726 25 (17)650 16 (29)
Private equity and other358 125 (7)349 106 (8)
Hedge funds and similar investments245 8 (6)228 7 (5)
Cash equivalents35 — — 26 — — 
$2,552 $900 $(40)$2,256 $687 $(58)
Schedule of Fair Value of the Fixed Income Securities Held in Nuclear Decommissioning Trust Funds
The following table summarizes the fair value of the fixed income securities held in nuclear decommissioning trust funds by contractual maturity:
December 31, 2025
(In millions)
Due within one year$20 
Due after one through five years93 
Due after five through ten years127 
Due after ten years353 
$593 
v3.25.4
Financial and Other Derivative Instruments (Tables)
 12 Months Ended
Dec. 31, 2025
Derivative Instruments and Hedging Activities Disclosure [Abstract]  
Schedule of Fair Value of Derivative Instruments
The following table presents the fair value of derivative instruments for DTE Energy:
December 31, 2025December 31, 2024
Derivative
Assets		Derivative
Liabilities		Derivative
Assets		Derivative
Liabilities
(In millions)
Derivatives designated as hedging instruments
Interest rate contracts$3 $— $20 $— 
Foreign currency exchange contracts— (1)— (1)
Total derivatives designated as hedging instruments$3 $(1)$20 $(1)
Derivatives not designated as hedging instruments
Commodity contracts
Natural gas$372 $(329)$428 $(410)
Electricity275 (235)187 (150)
Environmental & Other57 (32)58 (44)
Foreign currency exchange contracts— — 1 — 
Total derivatives not designated as hedging instruments$704 $(596)$674 $(604)
Current$482 $(413)$488 $(441)
Noncurrent225 (184)206 (164)
Total derivatives$707 $(597)$694 $(605)
Schedule of Net Cash Collateral Offsetting Arrangements and Netting Offsets of Derivative Assets
The following table presents net cash collateral offsetting arrangements for DTE Energy:
December 31,
20252024
(In millions)
Cash collateral netted against Derivative assets$(35)$(17)
Cash collateral netted against Derivative liabilities5 — 
Cash collateral recorded in Accounts receivable(a)
20 29 
Cash collateral recorded in Accounts payable(a)
(28)(5)
Total net cash collateral posted (received)$(38)$7 
_______________________________________
(a)Amounts are recorded net by counterparty.
The following table presents the netting offsets of Derivative assets and liabilities for DTE Energy:
December 31, 2025December 31, 2024
Gross Amounts of Recognized Assets (Liabilities)Gross Amounts Offset in the Consolidated Statements of Financial PositionNet Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial PositionGross Amounts of Recognized Assets (Liabilities)Gross Amounts Offset in the Consolidated Statements of Financial PositionNet Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position
(In millions)
Derivative assets
Commodity contracts(a)
Natural gas$372 $(235)$137 $428 $(285)$143 
Electricity275 (194)81 187 (116)71 
Environmental & Other57 (46)11 58 (46)12 
Interest rate contracts3 — 3 20 — 20 
Foreign currency exchange contracts— — — 1 — 1 
Total derivative assets$707 $(475)$232 $694 $(447)$247 
Derivative liabilities
Commodity contracts(a)
Natural gas$(329)$227 $(102)$(410)$272 $(138)
Electricity(235)186 (49)(150)114 (36)
Environmental & Other(32)32 — (44)44 — 
Foreign currency exchange contracts(1)— (1)(1)— (1)
Total derivative liabilities$(597)$445 $(152)$(605)$430 $(175)
_______________________________________
(a)For contracts with a clearing agent, DTE Energy nets all activity across commodities. This can result in some individual commodities having a contra balance.
Schedule of Net Cash Collateral Offsetting Arrangements and Netting Offsets of Derivative Liabilities
The following table presents net cash collateral offsetting arrangements for DTE Energy:
December 31,
20252024
(In millions)
Cash collateral netted against Derivative assets$(35)$(17)
Cash collateral netted against Derivative liabilities5 — 
Cash collateral recorded in Accounts receivable(a)
20 29 
Cash collateral recorded in Accounts payable(a)
(28)(5)
Total net cash collateral posted (received)$(38)$7 
_______________________________________
(a)Amounts are recorded net by counterparty.
The following table presents the netting offsets of Derivative assets and liabilities for DTE Energy:
December 31, 2025December 31, 2024
Gross Amounts of Recognized Assets (Liabilities)Gross Amounts Offset in the Consolidated Statements of Financial PositionNet Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial PositionGross Amounts of Recognized Assets (Liabilities)Gross Amounts Offset in the Consolidated Statements of Financial PositionNet Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position
(In millions)
Derivative assets
Commodity contracts(a)
Natural gas$372 $(235)$137 $428 $(285)$143 
Electricity275 (194)81 187 (116)71 
Environmental & Other57 (46)11 58 (46)12 
Interest rate contracts3 — 3 20 — 20 
Foreign currency exchange contracts— — — 1 — 1 
Total derivative assets$707 $(475)$232 $694 $(447)$247 
Derivative liabilities
Commodity contracts(a)
Natural gas$(329)$227 $(102)$(410)$272 $(138)
Electricity(235)186 (49)(150)114 (36)
Environmental & Other(32)32 — (44)44 — 
Foreign currency exchange contracts(1)— (1)(1)— (1)
Total derivative liabilities$(597)$445 $(152)$(605)$430 $(175)
_______________________________________
(a)For contracts with a clearing agent, DTE Energy nets all activity across commodities. This can result in some individual commodities having a contra balance.
Schedule of Netting Offsets of Derivative Assets and Liabilities Reconciliation to the Statements of Financial Position
The following table presents the netting offsets of Derivative assets and liabilities showing the reconciliation of derivative instruments to DTE Energy's Consolidated Statements of Financial Position:
December 31, 2025December 31, 2024
Derivative AssetsDerivative LiabilitiesDerivative AssetsDerivative Liabilities
CurrentNoncurrentCurrentNoncurrentCurrentNoncurrentCurrentNoncurrent
(In millions)
Total fair value of derivatives$482 $225 $(413)$(184)$488 $206 $(441)$(164)
Counterparty netting(325)(115)325 115 (323)(107)323 107 
Collateral adjustment(14)(21)2 3 (3)(14)— — 
Total derivatives as reported$143 $89 $(86)$(66)$162 $85 $(118)$(57)
Schedule of Effect of Derivatives Not Designated as Hedging Instruments
The effect of derivatives not designated as hedging instruments on DTE Energy's Consolidated Statements of Operations is as follows:
Location of Gain (Loss) Recognized in Income on DerivativesGain (Loss) Recognized in Income on Derivatives for Years Ended December 31,
202520242023
(In millions)
Commodity contracts
Natural gasOperating Revenues — Non-utility operations $112 $(169)$153 
Natural gasFuel, purchased power, gas, and other — non-utility(160)233 122 
ElectricityOperating Revenues — Non-utility operations 361 266 105 
Environmental & OtherOperating Revenues — Non-utility operations 61 14 5 
Foreign currency exchange contractsOperating Revenues — Non-utility operations (1)3 (2)
Total$373 $347 $383 
Schedule of Cumulative Gross Volume of Derivative Contracts
The following represents the cumulative gross volume of DTE Energy's derivative contracts outstanding as of December 31, 2025:
CommodityNumber of Units
Natural gas (MMBtu)2,451,423,819 
Electricity (MWh)39,287,109 
Foreign currency exchange ($ CAD)67,058,920 
FTR (MWh)82,664 
Renewable Energy Certificates (MWh)11,860,903 
Carbon emissions (Metric Ton)1,113,500 
Interest rate contracts ($ USD)300,000,000 
v3.25.4
Long-Term Financings (Tables)
 12 Months Ended
Dec. 31, 2025
Debt Disclosure [Abstract]  
Schedule of Long-term Debt
DTE Energy's long-term debt outstanding and interest rates of debt outstanding at December 31 were:
Interest Rate(a)
Maturity Date20252024
(In millions)
Mortgage bonds, notes, and other
DTE Energy debt, unsecured4.7%2026 — 2035$7,479 $6,380 
DTE Electric debt, principally secured4.2%2026 — 205512,620 11,270 
DTE Gas debt, principally secured4.4%2027 — 20553,055 2,865 
23,154 20,515 
Unamortized debt discount(14)(28)
Unamortized debt issuance costs(127)(114)
Long-term debt due within one year(1,277)(1,220)
$21,736 $19,153 
Securitization bonds(b)
DTE Electric securitization bonds5.6%2027 — 2038$642 $713 
Unamortized debt issuance costs(6)(7)
Long-term debt due within one year(75)(71)
$561 $635 
Junior Subordinated Debentures
Subordinated debentures5.4%2077 — 2085$1,510 $910 
Unamortized debt issuance costs(36)(26)
$1,474 $884 
_______________________________________
(a)Weighted average interest rate as of December 31, 2025.
(b)Bonds are held by DTE Securitization I and DTE Securitization II, special purpose entities consolidated by DTE Electric. Refer to Note 1 to the Consolidated Financial Statements, “Organization and Basis of Presentation,” for additional information regarding these entities and restrictions related to the bonds.
DTE Electric's long-term debt outstanding and interest rates of debt outstanding at December 31 were:
Interest Rate(a)
Maturity Date20252024
(In millions)
Mortgage bonds, notes, and other
Long-term debt, principally secured4.2%2026 — 2055$12,620 $11,270 
Unamortized debt discount(11)(22)
Unamortized debt issuance costs(80)(73)
Long-term debt due within one year(677)(350)
$11,852 $10,825 
Securitization bonds(b)
DTE Electric securitization bonds5.6%2027 — 2038$642 $713 
Unamortized debt issuance costs(6)(7)
Long-term debt due within one year(75)(71)
$561 $635 
_______________________________________
(a)Weighted average interest rate as of December 31, 2025.
(b)Bonds are held by DTE Securitization I and DTE Securitization II, special purpose entities consolidated by DTE Electric. Refer to Note 1 to the Consolidated Financial Statements, “Organization and Basis of Presentation,” for additional information regarding these entities and restrictions related to the bonds.
Schedule of Debt Issuances
Refer to the table below for debt issued in 2025:
CompanyMonthTypeInterest RateMaturity DateAmount
(In millions)
DTE EnergyFebruary
Senior Notes(a)
5.20%2030$1,100 
DTE ElectricMay
Mortgage Bonds(b)
5.25%2035500 
DTE ElectricMay
Mortgage Bonds(b)
5.85%2055500 
DTE ElectricMay
Mortgage Bonds(b)
4.25%2027300 
DTE EnergySeptember
Senior Notes(a)
4.88%2028250 
DTE EnergySeptember
Senior Notes(a)
5.05%2035550 
DTE EnergySeptember
Junior Subordinated Debentures(a)
6.25%2085600 
DTE GasSeptember
Mortgage Bonds(b)
4.71%203150 
DTE GasSeptember
Mortgage Bonds(b)
5.36%203775 
DTE GasSeptember
Mortgage Bonds(b)
5.96%2055135 
DTE ElectricNovember
Mortgage Bonds(b)
5.25%2035200 
DTE ElectricNovember
Mortgage Bonds(b)
5.85%2055200 
$4,460 
_______________________________
(a)Proceeds used for the repayment of short-term borrowings and for general corporate purposes.
(b)Proceeds used for the repayment of short-term borrowings, for capital expenditures, and for other general corporate purposes.
Schedule of Debt Redemptions
Refer to the table below for debt redeemed in 2025:
CompanyMonthTypeInterest RateMaturity DateAmount
(In millions)
DTE ElectricMarchMortgage Bonds3.38%2025$350 
DTE ElectricMarchSecuritization Bonds5.97%202515
DTE EnergyJuneSenior Notes1.05%2025800
DTE ElectricJuneSecuritization Bonds2.64%202520
DTE ElectricSeptemberSecuritization Bonds5.97%202515
DTE ElectricDecemberSecuritization Bonds2.64%202521
DTE GasDecemberMortgage Bonds3.74%202570
$1,291 
Schedule of Debt Maturities
The following table shows the Registrants' scheduled debt maturities, excluding any unamortized discount on debt:
202620272028202920302031 and ThereafterTotal
(In millions)
DTE Energy(a)(b)
$1,352 $1,730 $1,987 $1,962 $2,504 $15,771 $25,306 
DTE Electric(b)
$752 $339 $617 $103 $829 $10,622 $13,262 
_______________________________________
(a)Amounts include DTE Electric's scheduled debt maturities.
(b)Amounts include DTE Securitization I and DTE Securitization II scheduled debt maturities.
Schedule of Interest Payments Related to Long-term Debt
The following table shows scheduled interest payments related to the Registrants' long-term debt:
202620272028202920302031 and ThereafterTotal
(In millions)
DTE Energy(a)(b)
$1,127 $1,039 $963 $879 $790 $11,465 $16,263 
DTE Electric(b)
$557 $518 $504 $496 $484 $5,637 $8,196 
_______________________________________
(a)Amounts include DTE Electric's scheduled interest payments.
(b)Amounts include DTE Securitization I and DTE Securitization II scheduled interest payments.
v3.25.4
Preferred and Preference Securities (Tables)
 12 Months Ended
Dec. 31, 2025
Preferred Stock, Number of Shares, Par Value and Other Disclosure [Abstract]  
Schedule of Amount of Authorized and Unissued Stock
As of December 31, 2025, the amount of authorized and unissued stock is as follows:
CompanyType of StockPar ValueShares Authorized
DTE EnergyPreferred$— 5,000,000 
DTE ElectricPreferred$100 6,747,484 
DTE ElectricPreference$1 30,000,000 
DTE GasPreferred$1 7,000,000 
DTE GasPreference$1 4,000,000 
v3.25.4
Short-Term Credit Arrangements and Borrowings (Tables)
 12 Months Ended
Dec. 31, 2025
Short-Term Debt [Abstract]  
Schedule of Availability Under Credit Facilities
The availability under the facilities in place at December 31, 2025 is shown in the following table:
DTE EnergyDTE ElectricDTE GasTotal
(In millions)
Unsecured revolving credit facility, expiring October 2030$1,500 $1,000 $300 $2,800 
Unsecured letter of credit facility, expiring June 2026(a)
150 — — 150 
Unsecured letter of credit facility, expiring February 2027200 — — 200 
Unsecured letter of credit facilities, expiring June 2028150 — — 150 
Unsecured letter of credit facility(b)
75 — — 75 
Unsecured letter of credit facilities, expiring December 2026— 150 — 150 
Unsecured letter of credit facility(c)
— 175 — 175 
Unsecured letter of credit facility(d)
— 150 — 150 
2,075 1,475 300 3,850 
Amounts outstanding at December 31, 2025
Commercial paper issuances150 652 80 882 
Letters of credit416 331 — 747 
566 983 80 1,629 
Net availability at December 31, 2025$1,509 $492 $220 $2,221 
_______________________________________
(a)Uncommitted letter of credit facility.
(b)Uncommitted letter of credit facility with automatic renewal provision and therefore no expiration. DTE Electric may also utilize availability under this facility.
(c)Uncommitted letter of credit facility with automatic renewal provision and therefore no expiration. DTE Energy may also utilize availability under this facility.
(d)Uncommitted letter of credit facility with automatic renewal provision and therefore no expiration.
v3.25.4
Leases (Tables)
 12 Months Ended
Dec. 31, 2025
Leases [Abstract]  
Schedule of Components of Lease Cost and Other Information Related to Leases
The following is a summary of the components of lease cost for the years ended December 31:
DTE EnergyDTE Electric
202520242023202520242023
(In millions)
Operating lease cost$23 $26 $22 $17 $22 $17 
Finance lease cost:
Amortization of right-of-use assets4 4 7 3 3 6 
Interest of lease liabilities1 1 — — 1 — 
Total finance lease cost5 5 7 3 4 6 
Variable lease cost17 17 13 1 — — 
Short-term lease cost19 18 12 11 10 4 
$64 $66 $54 $32 $36 $27 
The following is a summary of other information related to leases for the years ended December 31:
DTE EnergyDTE Electric
202520242023202520242023
(In millions)
Supplemental Cash Flows Information
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows for finance leases$5 $9 $9 $3 $7 $7 
Operating cash flows for operating leases$27 $19 $19 $21 $15 $15 
Right-of-use assets obtained in exchange for lease obligations:
Operating leases$95 $75 $61 $86 $74 $61 
Finance leases$— $16 $5 $— $14 $5 
Weighted Average Remaining Lease Term (Years)
Operating leases24.523.318.726.324.819.8
Finance leases6.67.48.93.04.04.5
Weighted Average Discount Rate
Operating leases5.1 %4.8 %4.4 %5.2 %4.9 %4.5 %
Finance leases4.5 %4.6 %4.0 %5.8 %5.8 %5.4 %
Schedule of Future Minimum Operating Lease Payments
The Registrants' future minimum lease payments under leases for remaining periods as of December 31, 2025 are as follows:
DTE EnergyDTE Electric
Operating LeasesFinance LeasesOperating LeasesFinance Leases
(In millions)
2026$37 $5 $31 $3 
202735 4 30 3 
202832 4 28 3 
202921 1 17 — 
203013 1 10 — 
2031 and thereafter400 5 379 — 
Total future minimum lease payments538 20 495 9 
Imputed interest(271)(2)(262)— 
Lease liabilities$267 $18 $233 $9 
Schedule of Future Minimum Finance Lease Payments
The Registrants' future minimum lease payments under leases for remaining periods as of December 31, 2025 are as follows:
DTE EnergyDTE Electric
Operating LeasesFinance LeasesOperating LeasesFinance Leases
(In millions)
2026$37 $5 $31 $3 
202735 4 30 3 
202832 4 28 3 
202921 1 17 — 
203013 1 10 — 
2031 and thereafter400 5 379 — 
Total future minimum lease payments538 20 495 9 
Imputed interest(271)(2)(262)— 
Lease liabilities$267 $18 $233 $9 
Schedule of Finance Leases Reported on Consolidated Statements of Financial Position
Finance leases reported on the Consolidated Statements of Financial Position of the Registrants are as follows for the years ended December 31:
DTE EnergyDTE Electric
2025202420252024
(In millions)
Right-of-use assets, within Property, plant, and equipment, net$18 $23 $9 $12 
Current lease liabilities, within Current portion of long-term debt$4 $5 $3 $4 
Long-term lease liabilities$14 $18 $6 $8 
Schedule of Lease Income Associated with Operating Leases
DTE Energy’s lease income associated with operating leases was included on the Consolidated Statements of Operations for the years ended December 31:
202520242023
(In millions)
Fixed payments$15 $15 $15 
Variable payments46 45 44 
$61 $60 $59 
Schedule of Minimum Future Rental Revenues under Operating Leases
DTE Energy’s minimum future rental revenues under operating leases for remaining periods as of December 31, 2025 are as follows:
DTE Energy
(In millions)
2026$11 
202710 
20286 
20296 
20306 
2031 and thereafter23 
$62 
Schedule of Property under Operating Leases
The following is a summary of property under operating leases for DTE Energy as of December 31:
20252024
(In millions)
Gross property under operating leases$228 $227 
Accumulated amortization of property under operating leases$126 $118 
v3.25.4
Commitments and Contingencies (Tables)
 12 Months Ended
Dec. 31, 2025
Commitments and Contingencies Disclosure [Abstract]  
Schedule of Purchase Commitments The Registrants estimate the following commitments from 2026 through 2057, as detailed in the following tables:
202620272028202920302031 and ThereafterTotal
DTE Energy(In millions)
Long-term power purchase agreements(a)
$116 $128 $151 $151 $151 $1,699 $2,396 
Other purchase commitments(b)
3,506 1,441 529 266 249 701 6,692 
Total commitments$3,622 $1,569 $680 $417 $400 $2,400 $9,088 
202620272028202920302031 and ThereafterTotal
DTE Electric(In millions)
Long-term power purchase agreements(a)
$122 $133 $156 $153 $153 $1,704 $2,421 
Other purchase commitments(b)
602 411 147 34 13 117 1,324 
Total commitments$724 $544 $303 $187 $166 $1,821 $3,745 
_______________________________________
(a)The agreements represent the minimum obligations with suppliers for renewable energy and renewable energy credits under existing contract terms which expire from 2030 through 2055. DTE Electric's share of plant output ranges from 28% to 100%. Purchase commitments for DTE Electric include affiliate agreements with DTE Sustainable Generation that are eliminated in consolidation for DTE Energy.
(b)Excludes amounts associated with full requirements contracts where no stated minimum purchase volume is required.
v3.25.4
Retirement Benefits and Trusteed Assets (Tables)
 12 Months Ended
Dec. 31, 2025
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Schedule of Pension and Other Postretirement Benefit Plans and Accumulated Benefit Obligation
The table below represents the pension and other postretirement benefit plans of each Registrant at December 31, 2025:
Registrants
DTE EnergyDTE Electric
Qualified Pension Plans
DTE Energy Company Retirement PlanXX
DTE Gas Company Retirement Plan for Employees Covered by Collective Bargaining AgreementsX
Shenango Inc. Pension Plan(a)
X
Non-qualified Pension Plans
DTE Energy Company Supplemental Retirement Plan(b)
XX
DTE Energy Company Executive Supplemental Retirement Plan(b)
XX
DTE Energy Company Supplemental Severance Benefit PlanX
Other Postretirement Benefit Plans
The DTE Energy Company Comprehensive Non-Health Welfare PlanXX
The DTE Energy Company Comprehensive Retiree Group Health Care PlanXX
DTE Supplemental Retiree Benefit PlanXX
DTE Energy Company Retiree Reimbursement Arrangement PlanXX
_____________________________________
(a)Sponsored by Shenango, LLC
(b)Sponsored by DTE Energy Company
Pension Plan  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Schedule of Pension and Other Postretirement Benefit Plans and Accumulated Benefit Obligation
The following table reconciles the obligations, assets, and funded status of the plans as well as the amounts recognized as a pension liability in DTE Energy's Consolidated Statements of Financial Position at December 31:
DTE Energy
20252024
(In millions)
Accumulated benefit obligation, end of year$3,851 $3,803 
Change in projected benefit obligation
Projected benefit obligation, beginning of year$3,982 $4,318 
Service cost49 58 
Interest cost216 208 
Actuarial (gain) loss111 (254)
Benefits paid(315)(348)
Projected benefit obligation, end of year$4,043 $3,982 
Change in plan assets
Plan assets at fair value, beginning of year$3,758 $3,960 
Actual return on plan assets343 137 
Company contributions9 9 
Benefits paid(315)(348)
Plan assets at fair value, end of year$3,795 $3,758 
Funded status$(248)$(224)
Amount recorded as:
Current liabilities$(13)$(10)
Noncurrent liabilities(235)(214)
$(248)$(224)
Amounts recognized in Accumulated other comprehensive income, pre-tax
Net actuarial loss$82 $76 
$82 $76 
Amounts recognized in Regulatory assets(a)
Net actuarial loss$1,283 $1,318 
Prior service credit(2)(3)
$1,281 $1,315 
______________________________________
(a)See Note 9 to the Consolidated Financial Statements, "Regulatory Matters."
Schedule of Net Pension Cost (Credit)
Net pension cost (credit) for DTE Energy includes the following components:
Year Ended December 31,
202520242023
(In millions)
Service cost$49 $58 $57 
Interest cost216 208 214 
Expected return on plan assets(291)(341)(352)
Amortization of:
Net actuarial loss87 59 7 
Prior service credit(1)(2)(2)
Settlements— — 7 
Net pension cost (credit)$60 $(18)$(69)
Schedule of Changes in Plan Assets and Benefit Obligations
December 31,
20252024
(In millions)
Other changes in plan assets and benefit obligations recognized in Regulatory assets and Other comprehensive income (loss)
Net actuarial (gain) loss$58 $(49)
Amortization of net actuarial loss and settlements(87)(59)
Amortization of prior service credit1 2 
Total recognized in Regulatory assets and Other comprehensive income (loss)$(28)$(106)
Total recognized in net periodic pension credit, Regulatory assets, and Other comprehensive income (loss)$32 $(124)
Schedule of Expected Benefit Payments
At December 31, 2025, the benefits related to DTE Energy's qualified and non-qualified pension plans expected to be paid in each of the next five years and in the aggregate for the five fiscal years thereafter are as follows:
(In millions)
2026$326 
2027326 
2028330 
2029326 
2030321 
2031-20351,599 
Total$3,228 
Schedule of Assumptions Used
Assumptions used in determining the projected benefit obligation and net pension costs of DTE Energy for the years ended December 31, 2025, 2024, and 2023 are:
202520242023
Projected benefit obligation
Discount rate5.43%5.65%5.00%
Rate of compensation increase3.55%3.55%3.80%
Cash balance interest crediting rate3.60%4.50%3.60%
Net pension costs
Discount rate5.65%5.00%5.19%
Rate of compensation increase3.55%3.80%3.80%
Expected long-term rate of return on plan assets7.80%8.00%7.60%
Cash balance interest crediting rate4.50%3.60%3.40%
Schedule of Target Allocations and Fair Value Measurement Amounts for Pension Plan Assets
Target allocations for DTE Energy's pension plan assets as of December 31, 2025 are listed below:
U.S. Large Capitalization (Cap) Equity Securities8 %
U.S. Small Cap and Mid Cap Equity Securities1 
Non-U.S. Equity Securities6 
Fixed Income Securities57 
Hedge Funds and Similar Investments8 
Private Equity and Other20 
100 %
The following table provides the fair value measurement amounts for DTE Energy's pension plan assets at December 31, 2025 and 2024(a):
December 31, 2025December 31, 2024
Level 1Level 2
Other(b)
TotalLevel 1Level 2
Other(b)
Total
DTE Energy asset category:(In millions)
Short-term Investments(c)
$83 $— $— $83 $97 $— $— $97 
Equity Securities
Domestic(d)
— — 343 343 — — 349 349 
International(e)
34 — 209 243 35 — 188 223 
Fixed Income Securities
Governmental(f)
537 81 — 618 627 76 — 703 
Corporate(g)
— 1,504 — 1,504 — 1,350 — 1,350 
Hedge Funds and Similar Investments(h)
138 14 172 324 137 14 167 318 
Private Equity and Other(i)
— — 680 680 — — 718 718 
DTE Energy Total$792 $1,599 $1,404 $3,795 $896 $1,440 $1,422 $3,758 
_______________________________________
(a)For a description of levels within the fair value hierarchy, see Note 12 to the Consolidated Financial Statements, "Fair Value."
(b)Amounts represent assets valued at NAV as a practical expedient for fair value.
(c)This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category is obtained from quoted prices in actively traded markets.
(d)This category represents portfolios of large, medium and small capitalization domestic equities. Investments in this category include exchange-traded securities held in a commingled fund classified as NAV assets.
(e)This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category include exchange-traded securities for which unadjusted quoted prices can be obtained and exchange-traded securities held in a commingled fund classified as NAV assets.
(f)This category includes U.S. Treasuries, bonds, and other governmental debt. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services.
(g)This category primarily consists of corporate bonds from diversified industries, bank loans, and mortgage-backed securities. Pricing for investments in this category is obtained from quotations from broker or pricing services.
(h)This category utilizes a diversified group of strategies that attempt to capture uncorrelated sources of return and includes publicly traded mutual funds, insurance-linked and asset-backed securities, commingled funds and limited partnership funds. Pricing for mutual funds in this category is obtained from quoted prices in actively traded markets. Pricing for insurance-linked and asset-backed securities is obtained from quotations from broker or pricing services. Commingled funds and limited partnership funds are classified as NAV assets.
(i)This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in private real estate and private debt. All investments in this category are classified as NAV assets.
Other postretirement benefit plan  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Schedule of Pension and Other Postretirement Benefit Plans and Accumulated Benefit Obligation
The following table reconciles the obligations, assets, and funded status of the plans including amounts recorded as Prepaid postretirement costs or Accrued postretirement liability in the Registrants' Consolidated Statements of Financial Position at December 31:
DTE EnergyDTE Electric
2025202420252024
(In millions)
Change in accumulated postretirement benefit obligation
Accumulated postretirement benefit obligation, beginning of year$1,123 $1,283 $849 $982 
Service cost15 18 11 14 
Interest cost61 62 46 47 
Actuarial (gain) loss24 (165)15 (139)
Benefits paid(82)(75)(60)(55)
Accumulated postretirement benefit obligation, end of year$1,141 $1,123 $861 $849 
Change in plan assets
Plan assets at fair value, beginning of year$1,594 $1,614 $1,052 $1,070 
Actual return on plan assets139 58 92 40 
Benefits paid(79)(78)(57)(58)
Plan assets at fair value, end of year$1,654 $1,594 $1,087 $1,052 
Funded status$513 $471 $226 $203 
Amount recorded as:
Noncurrent assets$761 $705 $463 $428 
Current liabilities(1)(1)— — 
Noncurrent liabilities(247)(233)(237)(225)
$513 $471 $226 $203 
Amounts recognized in Accumulated other comprehensive income (loss), pre-tax
Net actuarial gain$(13)$(14)$— $— 
Amounts recognized in Regulatory assets and liabilities(a)
Net actuarial (gain) loss$64 $65 $(25)$(26)
______________________________________
(a)See Note 9 to the Consolidated Financial Statements, "Regulatory Matters."
Schedule of Net Pension Cost (Credit)
Net other postretirement credit for DTE Energy includes the following components:
Year Ended December 31,
202520242023
(In millions)
Service cost$15 $18 $17 
Interest cost61 62 65 
Expected return on plan assets(117)(120)(111)
Amortization of:
Net actuarial loss2 6 10 
Prior service credit— (10)(19)
Net other postretirement credit$(39)$(44)$(38)
Net other postretirement credit for DTE Electric includes the following components:
Year Ended December 31,
202520242023
(In millions)
Service cost$11 $14 $13 
Interest cost46 47 49 
Expected return on plan assets(77)(79)(73)
Amortization of:
Net actuarial (gain) loss(2)1 1 
Prior service credit— (6)(14)
Net other postretirement credit$(22)$(23)$(24)
Schedule of Changes in Plan Assets and Benefit Obligations
December 31,
20252024
(In millions)
Other changes in plan assets and accumulated postretirement benefit obligation recognized in Regulatory assets and liabilities and Other comprehensive income (loss)
Net actuarial (gain) loss$2 $(103)
Amortization of net actuarial loss(2)(6)
Amortization of prior service credit— 10 
Total recognized in Regulatory assets and liabilities and Other comprehensive income (loss)$— $(99)
Total recognized in net periodic benefit cost, Regulatory assets and liabilities, and Other comprehensive income (loss)$(39)$(143)
December 31,
20252024
(In millions)
Other changes in plan assets and accumulated postretirement benefit obligation recognized in Regulatory assets and liabilities
Net actuarial gain$(1)$(98)
Amortization of net actuarial gain/(loss)2 (1)
Amortization of prior service credit— 6 
Total recognized in Regulatory assets and liabilities$1 $(93)
Total recognized in net periodic benefit cost and Regulatory assets and liabilities$(21)$(116)
Schedule of Expected Benefit Payments
At December 31, 2025, the benefits expected to be paid, including prescription drug benefits, in each of the next five years and in the aggregate for the five fiscal years thereafter for the Registrants are as follows:
DTE EnergyDTE Electric
(In millions)
2026$80 $60 
202783 62 
202885 64 
202987 65 
203089 67 
2031-2035456 347 
Total$880 $665 
Schedule of Assumptions Used
Assumptions used in determining the accumulated postretirement benefit obligation and net other postretirement benefit costs of the Registrants for the years ended December 31, 2025, 2024, and 2023 are:
202520242023
Accumulated postretirement benefit obligation
Discount rate5.43%5.66%5.00%
Health care trend rate pre- and post- 65
8.25 / 8.75%
8.50 / 9.00%
7.75 / 8.25%
Ultimate health care trend rate4.50%4.50%4.50%
Year in which ultimate reached pre- and post- 65203620352035
Other postretirement benefit costs
Discount rate5.66%5.00%5.19%
Expected long-term rate of return on plan assets7.50%7.60%7.20%
Health care trend rate pre- and post- 65
8.50 / 9.00%
7.75 / 8.25%
6.75 / 7.25%
Ultimate health care trend rate4.50%4.50%4.50%
Year in which ultimate reached pre- and post- 65203520352035
Schedule of Target Allocations and Fair Value Measurement Amounts for Pension Plan Assets
Target allocations for the Registrants' other postretirement benefit plan assets as of December 31, 2025 are listed below:
U.S. Large Cap Equity Securities4 %
Non-U.S. Equity Securities3 
Fixed Income Securities62 
Hedge Funds and Similar Investments9 
Private Equity and Other22 
100 %
The following tables provide the fair value measurement amounts for the Registrants' other postretirement benefit plan assets at December 31, 2025 and 2024(a):
December 31, 2025December 31, 2024
Level 1Level 2
Other(b)
TotalLevel 1Level 2
Other(b)
Total
(In millions)
DTE Energy asset category:
Short-term Investments(c)
$37 $— $— $37 $33 $— $— $33 
Equity Securities
Domestic(d)
— — 61 61 — — 67 67 
International(e)
7 — 42 49 6 — 34 40 
Fixed Income Securities
Governmental(f)
169 37 — 206 210 34 — 244 
Corporate(g)
— 549 222 771 — 492 208 700 
Hedge Funds and Similar Investments(h)
34 3 105 142 27 3 103 133 
Private Equity and Other(i)
— — 388 388 — — 377 377 
DTE Energy Total$247 $589 $818 $1,654 $276 $529 $789 $1,594 
DTE Electric asset category:
Short-term Investments(c)
$24 $— $— $24 $21 $— $— $21 
Equity Securities
Domestic(d)
— — 38 38 — — 42 42 
International(e)
4 — 27 31 4 — 22 26 
Fixed Income Securities
Governmental(f)
110 24 — 134 138 22 — 160 
Corporate(g)
— 359 151 510 — 324 141 465 
Hedge Funds and Similar Investments(h)
21 2 70 93 17 2 69 88 
Private Equity and Other(i)
— — 257 257 — — 250 250 
DTE Electric Total$159 $385 $543 $1,087 $180 $348 $524 $1,052 
_______________________________________
(a)For a description of levels within the fair value hierarchy see Note 12 to the Consolidated Financial Statements, "Fair Value."
(b)Amounts represent assets valued at NAV as a practical expedient for fair value.
(c)This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category is obtained from quoted prices in actively traded markets.
(d)This category represents portfolios of large, medium and small capitalization domestic equities. Investments in this category include exchange-traded securities held in a commingled fund classified as NAV assets.
(e)This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category include exchange-traded securities for which unadjusted quoted prices can be obtained and exchange-traded securities held in a commingled fund classified as NAV assets.
(f)This category includes U.S. Treasuries, bonds and other governmental debt. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services.
(g)This category primarily consists of corporate bonds from diversified industries, bank loans, and mortgage backed securities. Pricing for investments in this category is obtained from quotations from broker or pricing services. Non-exchange traded securities and exchange-traded securities held in commingled funds are classified as NAV assets.
(h)This category utilizes a diversified group of strategies that attempt to capture uncorrelated sources of return and includes publicly traded mutual funds, insurance-linked and asset-backed securities, commingled funds and limited partnership funds. Pricing for mutual funds in this category is obtained from quoted prices in actively traded markets. Pricing for insurance-linked and asset-backed securities is obtained from quotations from broker or pricing services. Commingled funds and limited partnership funds are classified as NAV assets.
(i)This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in private real estate and private debt. All investments in this category are classified as NAV assets.
Schedule of Accumulated Benefit Obligations in Excess of Plan Assets
The following table reflects other postretirement benefit plans with accumulated postretirement benefit obligations in excess of plan assets as of December 31:
DTE EnergyDTE Electric
2025202420252024
(In millions)
Accumulated postretirement benefit obligation$541 $530 $510 $501 
Fair value of plan assets293 296 273 276 
Accumulated postretirement benefit obligation in excess of plan assets$248 $234 $237 $225 
Retiree healthcare plan (VEBA)  
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]  
Schedule of VEBA Contributions The following table provides contributions to the VEBA in:
Year Ended December 31,
202520242023
(In millions)
DTE Energy$15 $15 $16 
DTE Electric$7 $6 $7 
v3.25.4
Stock-Based Compensation (Tables)
 12 Months Ended
Dec. 31, 2025
Share-Based Payment Arrangement, Noncash Expense [Abstract]  
Schedule of Components of Stock-Based Compensation
The following table summarizes the components of stock-based compensation for DTE Energy:
Year Ended December 31,
202520242023
(In millions)
Stock-based compensation expense$60 $54 $48 
Tax benefit$10 $10 $9 
Schedule of Activity Relating to Performance Stock Units
DTE Energy recorded activity relating to performance stock unit awards as follows:
Year Ended December 31,
202520242023
(In millions, except per share amounts)
Weighted average grant date fair value of awards granted (per share)$123.02 $106.04 $112.73 
Awards settled in cash(a)
$— $— $9 
Awards settled in stock(a)
$39 $63 $59 
Compensation expense$43 $40 $34 
_______________________________________
(a)Sum of awards settled in cash and stock approximates the intrinsic value of the awards.
Schedule of Performance Stock Unit Activity
The following table summarizes DTE Energy’s performance stock unit activity for the period ended December 31, 2025:
Performance Stock UnitsWeighted Average
Grant Date
Fair Value
Balance at December 31, 2024976,843 $122.25 
Grants391,290 $123.02 
Forfeitures(58,011)$118.07 
Payouts(301,030)$120.34 
Balance at December 31, 20251,009,092 $123.36 
Schedule of Unrecognized Compensation Costs
As of December 31, 2025, DTE Energy's total unrecognized compensation cost related to non-vested stock incentive plan arrangements and the weighted average recognition period was as follows:
Unrecognized
Compensation
Cost		Weighted Average
to be Recognized
(In millions)(In years)
Stock awards$23 1.97
Performance stock units44 1.68
$67 1.78
v3.25.4
Segment and Related Information (Tables)
 12 Months Ended
Dec. 31, 2025
Segment Reporting [Abstract]  
Schedule of Inter-segment Billing for Goods and Services and Financial Data of Business Segments
Inter-segment billing for goods and services exchanged between segments is based upon tariffed or market-based prices of the provider. Such billing primarily consists of power sales, sale and transportation of natural gas, and renewable natural gas sales in the segments below, as well as charges from Electric to other segments for use of the shared capital assets of DTE Electric.
Year Ended December 31,
202520242023
(In millions)
Electric segment(a)
$71 $71 $72 
Gas segment22 16 17 
DTE Vantage segment77 43 68 
Energy Trading segment176 100 85 
$346 $230 $242 
_______________________________________
(a)Inter-segment billing for the Electric segment relating to Non-utility operations includes $4 million for the year ended December 31, 2025 and $3 million for the years ended December 31, 2024 and 2023.
Financial data of DTE Energy's business segments follows:
Electric(a)
Gas
DTE
Vantage
Energy
Trading
Total
Reportable
Segments
Corporate
and
Other
Reclassifications
and
Eliminations
Total
(In millions)
2025 Segment profit (loss)
Operating Revenues — Utility operations$6,885 2,052 — — $8,937 — (88)$8,849 
Operating Revenues — Non-utility operations$50 — 696 6,477 $7,223 — (258)$6,965 
Depreciation and amortization$1,553 225 59 4 $1,841 — — $1,841 
Interest expense$555 132 30 10 $727 409 (80)$1,056 
Interest income$(9)(11)(87)(7)$(114)(69)80 $(103)
Equity earnings of equity method investees$— 1 19 — $20 27 — $47 
Other segment items (pre-tax)(b)
$3,605 1,322 582 6,306 $11,815 (46)(346)$11,423 
Income Tax Expense (Benefit)$73 88 (61)41 $141 (53)— $88 
Net Income (Loss) Attributable to DTE Energy Company$1,158 295 154 123 $1,730 (268)— $1,462 
2025 Other segment financial data
Investment in equity method investees$4 19 77 — $100 22 — $122 
Capital expenditures and acquisitions$3,892 661 80 6 $4,639 — — $4,639 
Goodwill$1,208 743 25 17 $1,993 — — $1,993 
Total Assets$39,370 8,987 2,426 1,313 $52,096 5,145 (3,175)$54,066 
2024 Segment profit (loss)
Operating Revenues — Utility operations$6,277 1,798 — — $8,075 — (85)$7,990 
Operating Revenues — Non-utility operations$16 — 753 3,843 $4,612 — (145)$4,467 
Depreciation and amortization$1,447 221 59 5 $1,732 — — $1,732 
Interest expense$498 118 28 14 $658 351 (58)$951 
Interest income$(7)(10)(76)(15)$(108)(86)58 $(136)
Equity earnings (losses) of equity method investees$— 1 15 — $16 (1)— $15 
Other segment items (pre-tax)(b)
$3,314 1,134 629 3,672 $8,749 6 (230)$8,525 
Income Tax Expense (Benefit)$(31)77 (37)42 $51 (85)— $(34)
Net Income (Loss) Attributable to
DTE Energy Company
$1,072 257 135 125 $1,589 (185)— $1,404 
2024 Other segment financial data
Investment in equity method investees$5 18 82 — $105 23 — $128 
Capital expenditures and acquisitions$3,659 740 65 3 $4,467 — — $4,467 
Goodwill$1,208 743 25 17 $1,993 — — $1,993 
Total Assets$35,400 8,474 2,065 1,159 $47,098 4,723 (2,975)$48,846 
_______________________________________
(a)The Electric segment consists principally of DTE Electric. Refer to the DTE Electric Consolidated Statements of Operations and the DTE Electric Consolidated Statements of Financial Position for the standalone DTE Electric amounts.
(b)Other segment items include Fuel, purchased power, and gas — utility; Fuel, purchased power, gas, and other — non-utility; Operation and maintenance; Taxes other than income; Asset (gains) losses and impairments, net; Non-operating retirement benefits, net; Other income; and Other expenses.
Electric(a)
Gas
DTE
Vantage
Energy
Trading
Total
Reportable
Segments
Corporate
and
Other
Reclassifications
and
Eliminations
Total
(In millions)
2023 Segment profit (loss)
Operating Revenues — Utility operations$5,804 1,748 — — $7,552 — (86)$7,466 
Operating Revenues — Non-utility operations$14 — 809 4,612 $5,435 — (156)$5,279 
Depreciation and amortization$1,340 209 53 4 $1,606 — — $1,606 
Interest expense$432 102 15 18 $567 270 (46)$791 
Interest income$(20)(9)(32)(9)$(70)(33)46 $(57)
Equity earnings (losses) of equity method investees$— 1 7 — $8 (5)— $3 
Other segment items (pre-tax)(b)
$3,216 1,058 635 4,151 $9,060 18 (242)$8,836 
Income Tax Expense (Benefit)$78 93 (22)112 $261 (92)— $169 
Net Income (Loss) Attributable to DTE Energy Company$772 294 153 336 $1,555 (158)— $1,397 
2023 Other segment financial data
Investment in equity method investees$5 16 118 — $139 27 — $166 
Capital expenditures and acquisitions$3,128 746 57 3 $3,934 — — $3,934 
Goodwill$1,208 743 25 17 $1,993 — — $1,993 
Total Assets$32,292 7,722 1,122 1,166 $42,302 4,150 (1,697)$44,755 
_______________________________________
(a)The Electric segment consists principally of DTE Electric. Refer to the DTE Electric Consolidated Statements of Operations and the DTE Electric Consolidated Statements of Financial Position for the standalone DTE Electric amounts.
(b)Other segment items include Fuel, purchased power, and gas — utility; Fuel, purchased power, gas, and other — non-utility; Operation and maintenance; Taxes other than income; Asset (gains) losses and impairments, net; Non-operating retirement benefits, net; Other income; and Other expenses.
v3.25.4
Related Party Transactions (Tables)
 12 Months Ended
Dec. 31, 2025
Related Party Transactions [Abstract]  
Schedule of Related Party Transactions
The following is a summary of DTE Electric's transactions with affiliated companies:
Year Ended December 31,
202520242023
(In millions)
Revenues and Other Income
Energy sales$12 $11 $11 
Other services and interest$— $— $3 
Shared capital assets$55 $58 $58 
Costs
Fuel and purchased power$85 $65 $50 
Other services and interest$20 $4 $2 
Corporate expenses$349 $342 $299 
Other
Dividends declared$846 $776 $1,002 
Dividends paid$846 $776 $1,002 
Capital contribution from DTE Energy$954 $634 $759 
v3.25.4
Organization and Basis of Presentation (Details Textuals)
customer in Millions, $ in Millions
Dec. 31, 2025
USD ($)
customer
Dec. 31, 2024
USD ($)
Dec. 31, 2023
USD ($)
Variable Interest Entity [Line Items]      
Number of electric utility customers | customer 2.3    
Number of gas utility customers | customer 1.4    
Material potential exposure $ 0    
Investments in equity method investees 122 $ 128 $ 166
Amount in excess of carrying amount 96 94  
Variable interest entity, nonconsolidated      
Variable Interest Entity [Line Items]      
Investments in equity method investees 63 $ 65  
DTE Electric      
Variable Interest Entity [Line Items]      
Material potential exposure $ 0    
v3.25.4
Organization and Basis of Presentation (Variable Interest Entities) (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
ASSETS      
Cash and cash equivalents $ 208 $ 24  
Restricted cash 42 64  
Accounts receivable 2,031 1,690  
Securitized regulatory assets 619 690  
Total Assets 54,066 48,846 $ 44,755
LIABILITIES      
Accounts payable 1,753 1,387  
Accrued interest 273 224  
Regulatory liabilities — current 107 181  
DTE Electric      
ASSETS      
Cash and cash equivalents 81 11  
Restricted cash 42 48  
Securitized regulatory assets 619 690  
Total Assets 38,990 35,221  
LIABILITIES      
Accrued interest 135 128  
Regulatory liabilities — current 63 156  
Variable interest entity, primary beneficiary      
ASSETS      
Cash and cash equivalents 5 6  
Restricted cash 42 64  
Accounts receivable 10 27  
Securitized regulatory assets 619 690  
Notes receivable 68 657  
Other current and long-term assets 1 1  
Total Assets 745 1,445  
LIABILITIES      
Accounts payable 0 26  
Accrued interest 11 12  
Regulatory liabilities — current 23 27  
Securitization bonds 636 706  
Other current and long-term liabilities 4 20  
Total liabilities 674 791  
Notes receivable 2 14  
Current portion of securitization bonds 75 71  
Variable interest entity, primary beneficiary | DTE Electric      
ASSETS      
Cash and cash equivalents 0 0  
Restricted cash 42 48  
Accounts receivable 6 6  
Securitized regulatory assets 619 690  
Notes receivable 0 0  
Other current and long-term assets 0 0  
Total Assets 667 744  
LIABILITIES      
Accounts payable 0 0  
Accrued interest 11 12  
Regulatory liabilities — current 23 27  
Securitization bonds 636 706  
Other current and long-term liabilities 0 0  
Total liabilities 670 745  
Current portion of securitization bonds $ 75 $ 71  
v3.25.4
Significant Accounting Policies (Other Income) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Schedule of Other Nonoperating Income, by Component [Line Items]      
Allowance for equity funds used during construction $ 105 $ 86 $ 42
Equity earnings of equity method investees 47 15 3
Contract services 43 34 26
Investment income 17 17 17
Other 18 15 14
Other income 230 167 102
DTE Electric      
Schedule of Other Nonoperating Income, by Component [Line Items]      
Allowance for equity funds used during construction 103 84 40
Contract services 43 33 25
Investment income 14 13 11
Other 11 14 11
Other income $ 171 $ 144 $ 87
v3.25.4
Significant Accounting Policies (Accumulated Other Comprehensive Income (Loss) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]      
Beginning balance $ 11,704 $ 11,055 $ 10,401
Other comprehensive income (loss) before reclassifications (14) 37  
Amounts reclassified from Accumulated other comprehensive loss 1 4  
Other comprehensive income (loss) (13) 41 (5)
Ending balance 12,308 11,704 11,055
Total      
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]      
Beginning balance (26) (67) (62)
Other comprehensive income (loss) (13) 41 (5)
Ending balance (39) (26) (67)
Net Unrealized Gain (Loss) on Derivatives      
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]      
Beginning balance 30 (17)  
Other comprehensive income (loss) before reclassifications (8) 47  
Amounts reclassified from Accumulated other comprehensive loss (3) 0  
Other comprehensive income (loss) (11) 47  
Ending balance 19 30 (17)
Benefit Obligations      
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]      
Beginning balance (51) (52)  
Other comprehensive income (loss) before reclassifications (9) (3)  
Amounts reclassified from Accumulated other comprehensive loss 4 4  
Other comprehensive income (loss) (5) 1  
Ending balance (56) (51) (52)
Foreign Currency Translation      
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]      
Beginning balance (5) 2  
Other comprehensive income (loss) before reclassifications 3 (7)  
Amounts reclassified from Accumulated other comprehensive loss 0 0  
Other comprehensive income (loss) 3 (7)  
Ending balance $ (2) $ (5) $ 2
v3.25.4
Significant Accounting Policies (Details Textuals) - USD ($)
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Significant Accounting Policies [Line Items]      
Unbilled revenues $ 2,031,000,000 $ 1,690,000,000  
Specific review of probable future collections based on receivable balances, threshold duration (in days) 30 days    
Goodwill impairments $ 0 0  
Goodwill changes in carrying value 0 0  
Intangible assets amortization expense 18,000,000 16,000,000 $ 15,000,000
Excise and sales taxes net impact on statement of operations 0    
Charitable contributions 20,000,000 10,000,000 $ 0
Natural gas inventory      
Significant Accounting Policies [Line Items]      
LIFO inventory amount 43,000,000 69,000,000  
Excess of replacement costs over stated LIFO value 147,000,000 81,000,000  
Notes receivable      
Significant Accounting Policies [Line Items]      
Financing receivables 1,455,000,000    
Past due      
Significant Accounting Policies [Line Items]      
Financing receivables $ 0    
Minimum | Notes receivable      
Significant Accounting Policies [Line Items]      
Number of days after which receivable is considered delinquent (in days) 60 days    
Maximum | Notes receivable      
Significant Accounting Policies [Line Items]      
Number of days after which receivable is considered delinquent (in days) 120 days    
DTE Electric and DTE Gas      
Significant Accounting Policies [Line Items]      
Threshold period past due for write-off of trade accounts receivable (in days) 150 days    
DTE Electric and DTE Gas | Accounts Receivable      
Significant Accounting Policies [Line Items]      
Number of days after which receivable is considered delinquent (in days) 21 days    
DTE Electric | Notes receivable      
Significant Accounting Policies [Line Items]      
Financing receivables $ 274,000,000    
DTE Electric | Minimum | Notes receivable      
Significant Accounting Policies [Line Items]      
Number of days after which receivable is considered delinquent (in days) 60 days    
DTE Electric | Maximum | Notes receivable      
Significant Accounting Policies [Line Items]      
Number of days after which receivable is considered delinquent (in days) 120 days    
Unbilled revenues      
Significant Accounting Policies [Line Items]      
Unbilled revenues $ 1,300,000,000 1,000,000,000.0  
Unbilled revenues | DTE Electric      
Significant Accounting Policies [Line Items]      
Unbilled revenues $ 322,000,000 $ 303,000,000  
v3.25.4
Significant Accounting Policies (Financing Receivables Classified by Internal Grade of Credit Risk) (Details)
$ in Millions
Dec. 31, 2025
USD ($)
Notes receivable  
Year of Origination  
2025 $ 251
2024 927
2023 and prior 277
Total 1,455
Notes receivable | DTE Electric  
Year of Origination  
Total 274
Notes receivable | Internal grade 1  
Year of Origination  
2025 247
2024 4
2023 and prior 27
Total 278
Notes receivable | Internal grade 1 | DTE Electric  
Year of Origination  
Total 274
Notes receivable | Internal grade 1 | DTE Electric | Affiliates  
Year of Origination  
Total 247
Notes receivable | Internal grade 2  
Year of Origination  
2025 4
2024 923
2023 and prior 250
Total 1,177
Notes receivable | Internal grade 2 | DTE Electric  
Year of Origination  
Total 0
Net investment in leases  
Year of Origination  
2025 0
2024 2
2023 and prior 34
Total 36
Net investment in leases | DTE Electric  
Year of Origination  
Total 0
Net investment in leases | Internal grade 1  
Year of Origination  
2025 0
2024 0
2023 and prior 34
Total 34
Net investment in leases | Internal grade 1 | DTE Electric  
Year of Origination  
Total 0
Net investment in leases | Internal grade 2  
Year of Origination  
2025 0
2024 2
2023 and prior 0
Total 2
Net investment in leases | Internal grade 2 | DTE Electric  
Year of Origination  
Total $ 0
v3.25.4
Significant Accounting Policies (Roll-Forward of Activity for Financing Receivables Credit Loss Reserves) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Financing Receivable, Allowance for Credit Loss [Roll Forward]      
Beginning balance $ 72 $ 63 $ 79
Current period provision 69 76 52
Write-offs charged against allowance (116) (108) (112)
Recoveries of amounts previously written off 37 41 44
Ending balance 62 72 63
DTE Electric      
Financing Receivable, Allowance for Credit Loss [Roll Forward]      
Beginning balance 46 41 49
Current period provision 44 49 36
Write-offs charged against allowance (74) (70) (72)
Recoveries of amounts previously written off 25 26 28
Ending balance 41 46 41
Trade accounts receivable      
Financing Receivable, Allowance for Credit Loss [Roll Forward]      
Beginning balance 69 62 78
Current period provision 69 74 52
Write-offs charged against allowance (116) (108) (112)
Recoveries of amounts previously written off 37 41 44
Ending balance 59 69 62
Other receivables      
Financing Receivable, Allowance for Credit Loss [Roll Forward]      
Beginning balance 3 1 1
Current period provision 0 2 0
Write-offs charged against allowance 0 0 0
Recoveries of amounts previously written off 0 0 0
Ending balance $ 3 $ 3 $ 1
v3.25.4
Significant Accounting Policies (Uncollectible Expense) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Accounts, Notes, Loans and Financing Receivable [Line Items]      
Uncollectible expense $ 70 $ 74 $ 55
DTE Electric      
Accounts, Notes, Loans and Financing Receivable [Line Items]      
Uncollectible expense $ 45 $ 50 $ 38
v3.25.4
Significant Accounting Policies (Intangible Assets) (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Finite-Lived Intangible Assets [Line Items]    
Accumulated Amortization $ (137) $ (119)
Indefinite-lived Intangible Assets [Line Items]    
Intangible assets not subject to amortization 19 17
DTE Energy Long-term intangible assets    
Gross Carrying Value 325 263
Accumulated Amortization (137) (119)
Net Carrying Value 188 144
Carbon offsets    
Indefinite-lived Intangible Assets [Line Items]    
Intangible assets not subject to amortization 16 14
Renewable energy credits    
Indefinite-lived Intangible Assets [Line Items]    
Intangible assets not subject to amortization 0 1
Other    
Indefinite-lived Intangible Assets [Line Items]    
Intangible assets not subject to amortization 3 2
Contract intangibles    
Finite-Lived Intangible Assets [Line Items]    
Gross Carrying Value 306 246
Accumulated Amortization (137) (119)
Net Carrying Value 169 127
DTE Energy Long-term intangible assets    
Accumulated Amortization $ (137) $ (119)
Contract intangibles | Minimum    
Finite-Lived Intangible Assets [Line Items]    
Useful Lives 5 years  
Contract intangibles | Maximum    
Finite-Lived Intangible Assets [Line Items]    
Useful Lives 39 years  
v3.25.4
Significant Accounting Policies (Estimated Contract Intangible Amortization Expense) (Details)
$ in Millions
Dec. 31, 2025
USD ($)
Estimated amortization expense  
2026 $ 24
2027 24
2028 24
2029 24
2030 $ 22
v3.25.4
Significant Accounting Policies (Cloud Computing Costs) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Significant Accounting Policies [Line Items]      
Amortization expense of capitalized cloud computing costs $ 13 $ 12 $ 10
Gross value of capitalized cloud computing costs 94 64  
Accumulated amortization of capitalized cloud computing costs 40 27  
DTE Electric      
Significant Accounting Policies [Line Items]      
Amortization expense of capitalized cloud computing costs 10 10 $ 8
Gross value of capitalized cloud computing costs 69 51  
Accumulated amortization of capitalized cloud computing costs $ 32 $ 22  
v3.25.4
Acquisition (Details Textuals) - Electric segment - Osaka Gas USA Corporation - DTE Sustainable Generation
$ in Millions
 12 Months Ended
Aug. 14, 2025
MW
Dec. 31, 2025
USD ($)
Business Combination [Line Items]    
Amount of power associated with purchase of renewable energy project | MW 123  
Consideration paid for entity acquired, paid in cash | $   $ 216
Contract intangibles    
Business Combination [Line Items]    
Intangible assets, amortization period (in years) 5 years  
v3.25.4
Acquisition (Cost Allocated to Underlying Net Assets) (Details) - DTE Sustainable Generation - Electric - Osaka Gas USA Corporation
$ in Millions
Aug. 14, 2025
USD ($)
Business Combination [Line Items]  
Cash $ 6
Property, plant, and equipment, net 135
Working capital, other assets and liabilities 18
Total 216
Contract intangibles  
Business Combination [Line Items]  
Contract intangibles $ 57
v3.25.4
Revenue (Disaggregation of Revenue By Segment) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Disaggregation of Revenue [Line Items]      
Revenues $ 15,814 $ 12,457 $ 12,745
Operating Segments | Electric      
Disaggregation of Revenue [Line Items]      
Revenues 6,935 6,293 5,818
Operating Segments | Electric | Residential      
Disaggregation of Revenue [Line Items]      
Revenues 3,144 3,045 2,847
Operating Segments | Electric | Commercial      
Disaggregation of Revenue [Line Items]      
Revenues 2,195 2,263 2,114
Operating Segments | Electric | Industrial      
Disaggregation of Revenue [Line Items]      
Revenues 652 715 732
Operating Segments | Electric | Other      
Disaggregation of Revenue [Line Items]      
Revenues 944 270 125
Operating Segments | Electric | Other | DTE Sustainable Generation      
Disaggregation of Revenue [Line Items]      
Revenues 50 16 14
Operating Segments | Gas      
Disaggregation of Revenue [Line Items]      
Revenues 2,052 1,798 1,748
Operating Segments | Gas | Other      
Disaggregation of Revenue [Line Items]      
Revenues 189 162 89
Operating Segments | Gas | Gas sales      
Disaggregation of Revenue [Line Items]      
Revenues 1,521 1,307 1,324
Operating Segments | Gas | End User Transportation      
Disaggregation of Revenue [Line Items]      
Revenues 255 246 250
Operating Segments | Gas | Intermediate Transportation      
Disaggregation of Revenue [Line Items]      
Revenues 87 83 85
Operating Segments | DTE Vantage      
Disaggregation of Revenue [Line Items]      
Revenues 696 753 809
Operating Segments | Energy Trading segment      
Disaggregation of Revenue [Line Items]      
Revenues $ 6,477 $ 3,843 $ 4,612
v3.25.4
Revenue (Revenues Outside the Scope of Topic 606) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Disaggregation of Revenue [Line Items]      
Leases $ 61 $ 60 $ 59
Operating Segments | Electric      
Disaggregation of Revenue [Line Items]      
Alternative Revenue Program 48 43 36
Other revenues 23 25 22
Operating Segments | Gas      
Disaggregation of Revenue [Line Items]      
Alternative Revenue Program 8 21 16
Other revenues 12 11 8
Operating Segments | DTE Vantage      
Disaggregation of Revenue [Line Items]      
Leases $ 61 $ 60 $ 59
Operating Lease, Lease Income, Statement of Income or Comprehensive Income [Extensible Enumeration] Regulated and Unregulated Operating Revenue Regulated and Unregulated Operating Revenue Regulated and Unregulated Operating Revenue
Operating Segments | Energy Trading segment      
Disaggregation of Revenue [Line Items]      
Derivatives $ 4,571 $ 2,540 $ 3,436
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] Regulated and Unregulated Operating Revenue Regulated and Unregulated Operating Revenue Regulated and Unregulated Operating Revenue
v3.25.4
Revenue (Details Textuals)
 12 Months Ended
Dec. 31, 2025
DTE Vantage  
Revenue from External Customer [Line Items]  
Payment term (in days) 30 days
v3.25.4
Revenue (Deferred Revenue Activity) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Contract Liability [Roll Forward]    
Beginning Balance $ 138 $ 106
Increases due to cash received or receivable, excluding amounts recognized as revenue during the period 166 132
Revenue recognized that was included in the deferred revenue balance at the beginning of the period (134) (100)
Ending Balance $ 170 $ 138
v3.25.4
Revenue (Expected Recognition of Deferred Revenue) (Details) - Deferred revenue
$ in Millions
Dec. 31, 2025
USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 170
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 169
Performance Period 1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 1
Performance Period 1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 0
Performance Period 1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 0
Performance Period 1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2030-01-01  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 0
Performance Period 1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2031-01-01  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 0
Performance Period
v3.25.4
Revenue (Expected Timing of Performance Obligation Satisfaction) (Details) - Fixed Consideration
$ in Millions
Dec. 31, 2025
USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 931
DTE Electric  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation 1
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 189
Performance Period 1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01 | DTE Electric  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 1
Performance Period 1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 168
Performance Period 1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01 | DTE Electric  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 0
Performance Period 1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 110
Performance Period 1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2028-01-01 | DTE Electric  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 0
Performance Period 1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 91
Performance Period 1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2029-01-01 | DTE Electric  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 0
Performance Period 1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2030-01-01  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 81
Performance Period 1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2030-01-01 | DTE Electric  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 0
Performance Period 1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2031-01-01  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 292
Performance Period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2031-01-01 | DTE Electric  
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]  
Remaining performance obligation $ 0
Performance Period
v3.25.4
Property, Plant, and Equipment (Property, Plant and Equipment by Classification) (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Property, Plant, and Equipment [Line Items]    
Property, plant, and equipment $ 44,623 $ 40,840
Accumulated depreciation and amortization (10,970) (9,947)
Total Property 33,653 30,893
DTE Vantage    
Property, Plant, and Equipment [Line Items]    
Property, plant, and equipment 1,191 1,135
Accumulated depreciation and amortization (564) (520)
Other    
Property, Plant, and Equipment [Line Items]    
Property, plant, and equipment 413 272
Accumulated depreciation and amortization (95) (78)
DTE Electric    
Property, Plant, and Equipment [Line Items]    
Property, plant, and equipment 33,807 30,801
Accumulated depreciation and amortization (8,239) (7,404)
Total Property 25,568 23,397
DTE Electric | Distribution    
Property, Plant, and Equipment [Line Items]    
Property, plant, and equipment 16,316 14,995
Accumulated depreciation and amortization (3,729) (3,513)
DTE Electric | Dispatchable generation    
Property, Plant, and Equipment [Line Items]    
Property, plant, and equipment 8,647 8,428
Accumulated depreciation and amortization (2,584) (2,146)
DTE Electric | Renewable generation    
Property, Plant, and Equipment [Line Items]    
Property, plant, and equipment 5,102 3,933
Accumulated depreciation and amortization (760) (615)
DTE Electric | Other    
Property, Plant, and Equipment [Line Items]    
Property, plant, and equipment 3,742 3,445
Accumulated depreciation and amortization (1,166) (1,130)
DTE Gas    
Property, Plant, and Equipment [Line Items]    
Property, plant, and equipment 9,212 8,632
Accumulated depreciation and amortization (2,072) (1,945)
DTE Gas | Distribution    
Property, Plant, and Equipment [Line Items]    
Property, plant, and equipment 6,826 6,334
Accumulated depreciation and amortization (1,413) (1,319)
DTE Gas | Other    
Property, Plant, and Equipment [Line Items]    
Property, plant, and equipment 530 500
Accumulated depreciation and amortization (228) (210)
DTE Gas | Transmission    
Property, Plant, and Equipment [Line Items]    
Property, plant, and equipment 1,267 1,212
Accumulated depreciation and amortization (291) (278)
DTE Gas | Storage    
Property, Plant, and Equipment [Line Items]    
Property, plant, and equipment 589 586
Accumulated depreciation and amortization $ (140) $ (138)
v3.25.4
Property, Plant, and Equipment (AFUDC and Capitalized Interest Rates) (Details)
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Property, Plant, and Equipment [Line Items]      
Non-regulated businesses capitalized interest 4.50% 4.25% 3.00%
DTE Electric      
Property, Plant, and Equipment [Line Items]      
AFUDC 6.01% 5.56% 5.53%
DTE Gas      
Property, Plant, and Equipment [Line Items]      
AFUDC 5.80% 5.45% 5.41%
v3.25.4
Property, Plant, and Equipment (AFUDC and Interest Capitalized) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Property, Plant and Equipment [Abstract]      
Allowance for debt funds used during construction and interest capitalized $ 47 $ 36 $ 20
Allowance for equity funds used during construction 105 86 42
Total 152 122 62
DTE Electric      
Property, Plant, and Equipment [Line Items]      
Allowance for debt funds used during construction 45 34 15
Allowance for equity funds used during construction 103 84 40
Total $ 148 $ 118 $ 55
v3.25.4
Property, Plant, and Equipment (Details Textuals)
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Minimum | Non-utility      
Public Utility Property, Plant, and Equipment [Line Items]      
Estimated useful lives (in years) 3 years    
Minimum | Capitalized software      
Public Utility Property, Plant, and Equipment [Line Items]      
Estimated useful lives (in years) 3 years    
Maximum | Non-utility      
Public Utility Property, Plant, and Equipment [Line Items]      
Estimated useful lives (in years) 50 years    
Maximum | Capitalized software      
Public Utility Property, Plant, and Equipment [Line Items]      
Estimated useful lives (in years) 15 years    
DTE Electric | Minimum | Other      
Public Utility Property, Plant, and Equipment [Line Items]      
Estimated useful lives (in years) 3 years    
DTE Electric | Minimum | Capitalized software      
Public Utility Property, Plant, and Equipment [Line Items]      
Estimated useful lives (in years) 3 years    
DTE Electric | Maximum | Other      
Public Utility Property, Plant, and Equipment [Line Items]      
Estimated useful lives (in years) 45 years    
DTE Electric | Maximum | Capitalized software      
Public Utility Property, Plant, and Equipment [Line Items]      
Estimated useful lives (in years) 15 years    
DTE Gas | Minimum | Other      
Public Utility Property, Plant, and Equipment [Line Items]      
Estimated useful lives (in years) 3 years    
DTE Gas | Maximum | Other      
Public Utility Property, Plant, and Equipment [Line Items]      
Estimated useful lives (in years) 39 years    
DTE Electric      
Public Utility Property, Plant, and Equipment [Line Items]      
Composite depreciation rate for plants in service 3.60% 4.20% 4.40%
DTE Gas      
Public Utility Property, Plant, and Equipment [Line Items]      
Composite depreciation rate for plants in service 2.80% 2.90% 2.90%
v3.25.4
Property, Plant, and Equipment (Utility Property, Plant, and Equipment) (Details)
 12 Months Ended
Dec. 31, 2025
DTE Electric  
Public Utility Property, Plant, and Equipment [Line Items]  
Distribution 38 years
Generation 32 years
DTE Gas  
Public Utility Property, Plant, and Equipment [Line Items]  
Distribution 55 years
Transmission 67 years
Storage 60 years
v3.25.4
Property, Plant, and Equipment (Depreciation and Amortization Expense) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Property, Plant, and Equipment [Line Items]      
Property, plant, and equipment $ 1,265 $ 1,316 $ 1,239
Regulatory assets and liabilities 550 394 344
Intangible assets 18 16 15
Other 8 6 8
Depreciation and amortization 1,841 1,732 1,606
DTE Electric      
Property, Plant, and Equipment [Line Items]      
Property, plant, and equipment 1,039 1,089 1,029
Regulatory assets and liabilities 486 338 292
Other 5 5 5
Depreciation and amortization $ 1,530 $ 1,432 $ 1,326
v3.25.4
Property, Plant, and Equipment (Capitalized Software) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Property, Plant, and Equipment [Line Items]      
Amortization expense of capitalized software $ 164 $ 192 $ 189
Gross carrying value of capitalized software 1,211 1,005  
Accumulated amortization of capitalized software 474 476  
DTE Electric      
Property, Plant, and Equipment [Line Items]      
Amortization expense of capitalized software 146 175 $ 172
Gross carrying value of capitalized software 1,084 910  
Accumulated amortization of capitalized software $ 399 $ 414  
v3.25.4
Jointly-Owned Utility Plant (Details Textuals)
Dec. 31, 2025
plant
Belle River  
Jointly-Owned Utility Plant Interests [Line Items]  
Percent of the total capacity and energy of the plant 19.00%
Ludington Hydroelectric Pumped Storage  
Jointly-Owned Utility Plant Interests [Line Items]  
Percent of the total capacity and energy of the plant 51.00%
DTE Electric  
Jointly-Owned Utility Plant Interests [Line Items]  
Number of power plants owned 2
v3.25.4
Jointly-Owned Utility Plant (Jointly-Owned Utility Plants) (Details) - DTE Electric
$ in Millions
Dec. 31, 2025
USD ($)
MW
Belle River  
Jointly-Owned Utility Plant Interests [Line Items]  
Total plant capacity | MW 1,270
Ownership interest 81.00%
Investment in Property, plant, and equipment (in millions) $ 1,961
Accumulated depreciation (in millions) $ 1,198
Ludington Hydroelectric Pumped Storage  
Jointly-Owned Utility Plant Interests [Line Items]  
Total plant capacity | MW 2,290
Ownership interest 49.00%
Investment in Property, plant, and equipment (in millions) $ 676
Accumulated depreciation (in millions) $ 171
v3.25.4
Asset Retirement Obligations (Changes to Asset Retirement Obligations) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]      
Asset retirement obligations at January 1 $ 4,031 $ 3,556 $ 3,460
Accretion 239 211 198
Liabilities incurred 32 324 7
Liabilities settled (10) (14) (96)
Revision in estimated cash flows 177 (46) (13)
Asset retirement obligations at December 31 4,469 4,031 3,556
DTE Electric      
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]      
Asset retirement obligations at January 1 3,791 3,326 3,221
Accretion 226 199 185
Liabilities incurred 32 323 4
Liabilities settled (9) (11) (81)
Revision in estimated cash flows 177 (46) (3)
Asset retirement obligations at December 31 $ 4,217 $ 3,791 $ 3,326
v3.25.4
Asset Retirement Obligations (Details Textuals) - USD ($)
 3 Months Ended
Sep. 30, 2025
Dec. 31, 2025
Fermi 2    
Asset Retirement Obligations [Line Items]    
Nuclear decommissioning liabilities funded through surcharge and included in ARO balance   $ 3,100,000,000
Liabilities balance upon completion of decommissioning   $ 0
Fermi 1 | Nuclear decommissioning trusts | DTE Electric    
Asset Retirement Obligations [Line Items]    
Revision in cash flow incurred $ 47,000,000  
v3.25.4
Regulatory Matters (Details Textuals) (Details) - USD ($)
$ in Millions
 1 Months Ended 12 Months Ended 33 Months Ended
Dec. 23, 2025
Nov. 13, 2025
Nov. 12, 2025
Apr. 24, 2025
Apr. 23, 2025
Feb. 27, 2025
Mar. 31, 2023
Dec. 31, 2025
Dec. 31, 2025
Dec. 01, 2023
Deferred environmental costs                    
Public Utilities, General Disclosures [Line Items]                    
Amortization period for regulatory asset (in years)               10 years 10 years  
Customer360 deferred costs                    
Public Utilities, General Disclosures [Line Items]                    
Amortization period for regulatory asset (in years)               15 years 15 years  
Securitized regulatory asset, tree trim surge costs | Maximum                    
Public Utilities, General Disclosures [Line Items]                    
Amortization period for regulatory asset (in years)               5 years 5 years  
Securitized regulatory asset, River Rouge costs | Maximum                    
Public Utilities, General Disclosures [Line Items]                    
Amortization period for regulatory asset (in years)               14 years 14 years  
Securitized regulatory asset, St Clair and Trenton Channel costs | Maximum                    
Public Utilities, General Disclosures [Line Items]                    
Amortization period for regulatory asset (in years)               15 years 15 years  
DTE Electric | Other postretirement costs                    
Public Utilities, General Disclosures [Line Items]                    
Amortization period for regulatory liability (in years)                   7 years
DTE Electric | Recovery Mechanism, Power Supply Costs | 2022 Electric PSCR Reconciliation                    
Public Utilities, General Disclosures [Line Items]                    
Recovery of cost rate             $ 421   $ 416  
MPSC | DTE Electric                    
Public Utilities, General Disclosures [Line Items]                    
Approved return on equity, percent               9.90%    
MPSC | DTE Electric | 2022 Electric PSCR Reconciliation                    
Public Utilities, General Disclosures [Line Items]                    
Cost recovery approved rate           $ 387        
Amount of disallowed costs           $ 33        
MPSC | DTE Electric | 2025 DTE Electric Rate Case Filing                    
Public Utilities, General Disclosures [Line Items]                    
Return on equity requested percent       10.75% 9.90%          
Requested rate increase       $ 574            
MPSC | DTE Electric | 2025 Electric Depreciation Case Filing                    
Public Utilities, General Disclosures [Line Items]                    
Requested rate increase $ 147                  
MPSC | DTE Electric | Integrated Resource Plan                    
Public Utilities, General Disclosures [Line Items]                    
Requested regulatory asset               $ 1,050 $ 1,050  
MPSC | DTE Electric | Recoverable undepreciated costs on retiring plants | Integrated Resource Plan | Monroe assets                    
Public Utilities, General Disclosures [Line Items]                    
Return on equity requested percent               9.00%    
Amortization period for regulatory asset (in years)               15 years 15 years  
MPSC | DTE Gas                    
Public Utilities, General Disclosures [Line Items]                    
Approved return on equity, percent               9.80%    
MPSC | DTE Gas | 2025 Gas Rate Case Filing                    
Public Utilities, General Disclosures [Line Items]                    
Return on equity requested percent   10.25% 9.80%              
Requested rate increase   $ 163                
Net increase on total revenue deficiency   238                
Net of IRM roll-in   $ 75                
v3.25.4
Regulatory Matters (Regulatory Assets) (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Regulatory Assets [Line Items]    
Regulatory assets $ 7,550 $ 6,821
Less amount included in Current Assets (170) (50)
Regulatory assets, noncurrent 7,380 6,771
Securitized regulatory assets 619 690
Recoverable undepreciated costs on retiring plants    
Regulatory Assets [Line Items]    
Regulatory assets 3,146 2,986
Pension    
Regulatory Assets [Line Items]    
Regulatory assets 1,281 1,315
Other postretirement costs    
Regulatory Assets [Line Items]    
Regulatory assets 90 91
Fermi 2 asset retirement obligation    
Regulatory Assets [Line Items]    
Regulatory assets 895 951
Removal costs asset    
Regulatory Assets [Line Items]    
Regulatory assets 700 501
Enhanced tree trimming program deferred costs    
Regulatory Assets [Line Items]    
Regulatory assets 340 211
Renewable ITC offset    
Regulatory Assets [Line Items]    
Regulatory assets 207 89
Recoverable income taxes related to AFUDC equity    
Regulatory Assets [Line Items]    
Regulatory assets 148 116
Energy Waste Reduction incentive    
Regulatory Assets [Line Items]    
Regulatory assets 115 102
Accrued PSCR/GCR revenue    
Regulatory Assets [Line Items]    
Regulatory assets 112 0
Recoverable Michigan income taxes    
Regulatory Assets [Line Items]    
Regulatory assets 107 119
Ludington contract dispute costs    
Regulatory Assets [Line Items]    
Regulatory assets 58 31
Energy Waste Reduction    
Regulatory Assets [Line Items]    
Regulatory assets 57 36
Deferred environmental costs    
Regulatory Assets [Line Items]    
Regulatory assets 39 43
Unamortized loss on reacquired debt    
Regulatory Assets [Line Items]    
Regulatory assets 33 38
Customer360 deferred costs    
Regulatory Assets [Line Items]    
Regulatory assets 29 34
Other    
Regulatory Assets [Line Items]    
Regulatory assets 193 158
DTE Electric    
Regulatory Assets [Line Items]    
Regulatory assets 6,979 6,226
Less amount included in Current Assets (158) (39)
Regulatory assets, noncurrent 6,821 6,187
Securitized regulatory assets 619 690
DTE Electric | Recoverable undepreciated costs on retiring plants    
Regulatory Assets [Line Items]    
Regulatory assets 3,146 2,986
DTE Electric | Pension    
Regulatory Assets [Line Items]    
Regulatory assets 949 971
DTE Electric | Other postretirement costs    
Regulatory Assets [Line Items]    
Regulatory assets 0 0
DTE Electric | Fermi 2 asset retirement obligation    
Regulatory Assets [Line Items]    
Regulatory assets 895 951
DTE Electric | Removal costs asset    
Regulatory Assets [Line Items]    
Regulatory assets 700 501
DTE Electric | Enhanced tree trimming program deferred costs    
Regulatory Assets [Line Items]    
Regulatory assets 340 211
DTE Electric | Renewable ITC offset    
Regulatory Assets [Line Items]    
Regulatory assets 207 89
DTE Electric | Recoverable income taxes related to AFUDC equity    
Regulatory Assets [Line Items]    
Regulatory assets 139 107
DTE Electric | Energy Waste Reduction incentive    
Regulatory Assets [Line Items]    
Regulatory assets 94 82
DTE Electric | Accrued PSCR/GCR revenue    
Regulatory Assets [Line Items]    
Regulatory assets 111 0
DTE Electric | Recoverable Michigan income taxes    
Regulatory Assets [Line Items]    
Regulatory assets 89 99
DTE Electric | Ludington contract dispute costs    
Regulatory Assets [Line Items]    
Regulatory assets 58 31
DTE Electric | Energy Waste Reduction    
Regulatory Assets [Line Items]    
Regulatory assets 52 29
DTE Electric | Deferred environmental costs    
Regulatory Assets [Line Items]    
Regulatory assets 0 0
DTE Electric | Unamortized loss on reacquired debt    
Regulatory Assets [Line Items]    
Regulatory assets 26 29
DTE Electric | Customer360 deferred costs    
Regulatory Assets [Line Items]    
Regulatory assets 29 34
DTE Electric | Other    
Regulatory Assets [Line Items]    
Regulatory assets $ 144 $ 106
v3.25.4
Regulatory Matters (Regulatory Liabilities) (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Regulatory Liabilities [Line Items]    
Regulatory liabilities $ 2,988 $ 3,037
Less amount included in Current Liabilities (107) (181)
Regulatory liabilities, noncurrent 2,881 2,856
Refundable federal income taxes    
Regulatory Liabilities [Line Items]    
Regulatory liabilities 1,646 1,733
Removal costs liability    
Regulatory Liabilities [Line Items]    
Regulatory liabilities 511 506
Non-service pension and other postretirement costs    
Regulatory Liabilities [Line Items]    
Regulatory liabilities 271 255
Negative other postretirement offset    
Regulatory Liabilities [Line Items]    
Regulatory liabilities 205 214
Renewable energy    
Regulatory Liabilities [Line Items]    
Regulatory liabilities 196 90
Accrued PSCR/GCR refund    
Regulatory Liabilities [Line Items]    
Regulatory liabilities 43 136
Other    
Regulatory Liabilities [Line Items]    
Regulatory liabilities 116 103
DTE Electric    
Regulatory Liabilities [Line Items]    
Regulatory liabilities 1,861 1,909
Less amount included in Current Liabilities (63) (156)
Regulatory liabilities, noncurrent 1,798 1,753
DTE Electric | Refundable federal income taxes    
Regulatory Liabilities [Line Items]    
Regulatory liabilities 1,318 1,389
DTE Electric | Removal costs liability    
Regulatory Liabilities [Line Items]    
Regulatory liabilities 0 0
DTE Electric | Non-service pension and other postretirement costs    
Regulatory Liabilities [Line Items]    
Regulatory liabilities 103 94
DTE Electric | Negative other postretirement offset    
Regulatory Liabilities [Line Items]    
Regulatory liabilities 133 139
DTE Electric | Renewable energy    
Regulatory Liabilities [Line Items]    
Regulatory liabilities 196 90
DTE Electric | Accrued PSCR/GCR refund    
Regulatory Liabilities [Line Items]    
Regulatory liabilities 0 111
DTE Electric | Other    
Regulatory Liabilities [Line Items]    
Regulatory liabilities $ 111 $ 86
v3.25.4
Income Taxes (Details Textuals) - USD ($)
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Operating Loss Carryforwards [Line Items]      
Accounts receivable $ 2,031,000,000 $ 1,690,000,000  
Deferred tax asset, general business tax credit carryforwards 1,600,000,000    
State and local net operating loss carryforwards 51,000,000 68,000,000  
Valuation allowance 46,000,000 25,000,000  
Valuation allowance charitable contributions carryforward 16,000,000    
Unrecognized tax benefits 0 0  
Interest expense on income taxes 0 0 $ 0
Accrued interest on income taxes 0 0 0
State and local net operating loss carryforwards      
Operating Loss Carryforwards [Line Items]      
Valuation allowance 15,000,000 16,000,000  
Charitable Contributions Carryforward      
Operating Loss Carryforwards [Line Items]      
Valuation allowance 30,000,000 3,000,000  
Federal      
Operating Loss Carryforwards [Line Items]      
Net operating loss carryforward 856,000,000    
DTE Electric      
Operating Loss Carryforwards [Line Items]      
State and local net operating loss carryforwards 27,000,000 42,000,000  
Valuation allowance 0 5,000,000  
Unrecognized tax benefits 0 0  
Interest expense on income taxes 0 0 0
Accrued interest on income taxes 0 0 $ 0
DTE Electric | General Business Credits      
Operating Loss Carryforwards [Line Items]      
Tax credit carryforwards 512,000,000    
DTE Electric | Federal      
Operating Loss Carryforwards [Line Items]      
Net operating loss carryforward 112,000,000    
Federal Income Taxes | DTE Energy | DTE Electric      
Operating Loss Carryforwards [Line Items]      
Accounts receivable $ 1,000,000 $ 5,000,000  
v3.25.4
Income Taxes (Income Tax Expense Varied from Statutory Federal Income Tax Rate) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Amount      
Income tax expense at U.S. Federal Statutory Tax Rate $ 326 $ 288 $ 329
Tax Credits      
Production tax credits (161) (174) (91)
Investment tax credits (94) (128) (44)
Other (5) (4) (5)
Other Adjustments      
TCJA regulatory liability amortization (65) (66) (63)
Other (4) 4 0
Nontaxable or Nondeductible Items      
AFUDC equity (20) (17) (7)
Other 6 (3) (4)
Changes in Tax Laws or Rates Enacted in the Current Period 16 0 0
Changes in Valuation Allowances 7 6 0
Changes in Prior Year Unrecognized Tax Benefits 0 0 (12)
Foreign Tax Effects 1 1 0
State and Local Income Taxes, Net of Federal Effect 81 59 66
Income Tax Expense (Benefit) at Effective Tax Rate $ 88 $ (34) $ 169
Percentage      
Income tax expense at U.S. Federal Statutory Tax Rate 21.00% 21.00% 21.00%
Tax Credits      
Production tax credits (10.40%) (12.70%) (5.80%)
Investment tax credits (6.10%) (9.30%) (2.80%)
Other (0.30%) (0.30%) (0.30%)
Other Adjustments      
TCJA regulatory liability amortization (4.20%) (4.80%) (4.00%)
Other (0.10%) 0.20% 0.00%
Nontaxable or Nondeductible Items      
AFUDC equity (1.30%) (1.20%) (0.50%)
Other 0.50% (0.30%) (0.20%)
Changes in Tax Laws or Rates Enacted in the Current Period 1.00% 0.00% 0.00%
Changes in Valuation Allowances 0.40% 0.50% 0.00%
Changes in Prior Year Unrecognized Tax Benefits 0.00% 0.00% (0.80%)
Foreign Tax Effects 0.00% 0.10% 0.00%
State and Local Income Taxes, Net of Federal Effect 5.20% 4.30% 4.20%
Income Tax Expense (Benefit) at Effective Tax Rate 5.70% (2.50%) 10.80%
ILLINOIS      
Nontaxable or Nondeductible Items      
State and Local Income Taxes, Net of Federal Effect $ 14    
DTE Electric      
Amount      
Income tax expense at U.S. Federal Statutory Tax Rate 257 $ 218 $ 179
Tax Credits      
Production tax credits (77) (167) (79)
Investment tax credits (95) (70) (1)
Other (4) (4) (4)
Other Adjustments      
TCJA regulatory liability amortization (53) (55) (53)
Other (1) 2 0
Nontaxable or Nondeductible Items      
AFUDC equity (20) (16) (7)
Other (2) (2) (2)
Changes in Valuation Allowances 0 5 0
Changes in Prior Year Unrecognized Tax Benefits 0 0 (7)
State and Local Income Taxes, Net of Federal Effect 66 57 52
Income Tax Expense (Benefit) at Effective Tax Rate $ 71 $ (32) $ 78
Percentage      
Income tax expense at U.S. Federal Statutory Tax Rate 21.00% 21.00% 21.00%
Tax Credits      
Production tax credits (6.30%) (16.00%) (9.30%)
Investment tax credits (7.70%) (6.70%) (0.10%)
Other (0.40%) (0.40%) (0.50%)
Other Adjustments      
TCJA regulatory liability amortization (4.40%) (5.30%) (6.20%)
Other (0.10%) 0.20% 0.00%
Nontaxable or Nondeductible Items      
AFUDC equity (1.60%) (1.60%) (0.80%)
Other (0.10%) (0.20%) (0.20%)
Changes in Valuation Allowances 0.00% 0.40% 0.00%
Changes in Prior Year Unrecognized Tax Benefits 0.00% 0.00% (0.80%)
State and Local Income Taxes, Net of Federal Effect 5.40% 5.50% 6.10%
Income Tax Expense (Benefit) at Effective Tax Rate 5.80% (3.10%) 9.20%
v3.25.4
Income Taxes (Income Taxes Paid) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Income Tax Paid, by Individual Jurisdiction [Line Items]      
U.S. Federal $ (266) $ (230) $ 2
U.S. State and Local (3) (3) (7)
Foreign 2 3 0
Total (267) (230) (5)
DTE Electric      
Income Tax Paid, by Individual Jurisdiction [Line Items]      
U.S. Federal (273) (231) 9
Total (273) (231) 15
Michigan      
Income Tax Paid, by Individual Jurisdiction [Line Items]      
U.S. State and Local (5) (5) (10)
Michigan | DTE Electric      
Income Tax Paid, by Individual Jurisdiction [Line Items]      
U.S. State and Local 0 0 6
Pennsylvania      
Income Tax Paid, by Individual Jurisdiction [Line Items]      
U.S. State and Local 1 2 2
Other      
Income Tax Paid, by Individual Jurisdiction [Line Items]      
U.S. State and Local $ 1 $ 0 $ 1
v3.25.4
Income Taxes (Components of Income Tax Expense) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Income (loss) from continuing operations before income tax expense (benefit)      
US $ 1,543 $ 1,357 $ 1,559
Foreign 7 13 7
Income Before Income Taxes 1,550 1,370 1,566
Current tax expense (benefit)      
US federal (269) (229) (10)
US state and local (3) (2) (2)
Foreign 2 3 0
Total current tax expense (benefit) (270) (228) (12)
Deferred tax expense (benefit)      
US federal 253 116 103
US state and local 105 77 76
Foreign 0 1 2
Total deferred tax expense (benefit) 358 194 181
Total tax expense (benefit)      
US federal (16) (113) 93
US state and local 102 75 74
Foreign 2 4 2
Income Tax Expense (Benefit) at Effective Tax Rate 88 (34) 169
DTE Electric      
Income (loss) from continuing operations before income tax expense (benefit)      
US 1,223 1,040 850
Income Before Income Taxes 1,223 1,040 850
Current tax expense (benefit)      
US federal (268) (228) 1
US state and local 0 0 (5)
Total current tax expense (benefit) (268) (228) (4)
Deferred tax expense (benefit)      
US federal 256 124 19
US state and local 83 72 63
Total deferred tax expense (benefit) 339 196 82
Total tax expense (benefit)      
US federal (12) (104) 20
US state and local 83 72 58
Income Tax Expense (Benefit) at Effective Tax Rate $ 71 $ (32) $ 78
v3.25.4
Income Taxes (Deferred Tax Assets and Liabilities) (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Components of Deferred Tax Assets and Liabilities [Abstract]    
Property, plant, and equipment $ (3,952) $ (3,695)
Regulatory assets and liabilities (1,412) (1,272)
Tax credit carryforwards 1,619 1,604
Pension and benefits 3 55
Federal net operating loss carryforward 180 190
State and local net operating loss carryforwards 51 68
Investments in equity method investees (25) (28)
Other 182 145
Deferred tax assets (liabilities) (3,354) (2,933)
Less: Valuation allowance (46) (25)
Long-term deferred income tax liabilities (3,400) (2,958)
Deferred income tax assets 2,575 2,508
Deferred income tax liabilities (5,975) (5,466)
DTE Electric    
Components of Deferred Tax Assets and Liabilities [Abstract]    
Property, plant, and equipment (2,947) (2,788)
Regulatory assets and liabilities (1,636) (1,492)
Tax credit carryforwards 512 583
Pension and benefits 2 62
Federal net operating loss carryforward 24 30
State and local net operating loss carryforwards 27 42
Investments in equity method investees (1) (1)
Other 207 176
Deferred tax assets (liabilities) (3,812) (3,388)
Less: Valuation allowance 0 (5)
Long-term deferred income tax liabilities (3,812) (3,393)
Deferred income tax assets 1,188 1,209
Deferred income tax liabilities $ (5,000) $ (4,602)
v3.25.4
Income Taxes (Tax Credit Sales Year of Sale) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Income Tax Disclosure [Abstract]      
Cash received for tax credit sales $ 268 $ 231 $ 0
v3.25.4
Earnings Per Share (Details) - USD ($)
$ / shares in Units, shares in Millions, $ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Basic Earnings per Share      
Net Income (Loss) Attributable to DTE Energy Company $ 1,462 $ 1,404 $ 1,397
Less: Allocation of earnings to net restricted stock awards 3 3 3
Net income available to common shareholders — basic $ 1,459 $ 1,401 $ 1,394
Average number of common shares outstanding — basic (in shares) 207 207 206
Basic Earnings per Common Share (in dollars per share) $ 7.04 $ 6.78 $ 6.77
Diluted Earnings per Share      
Net Income (Loss) Attributable to DTE Energy Company $ 1,462 $ 1,404 $ 1,397
Less: Allocation of earnings to net restricted stock awards 3 3 3
Net income available to common shareholders — diluted $ 1,459 $ 1,401 $ 1,394
Average number of common shares outstanding — diluted (in shares) 207 207 206
Diluted Earnings per Common Share (in dollars per share) $ 7.03 $ 6.77 $ 6.76
v3.25.4
Fair Value (Assets and Liabilities Recorded at Fair Value on a Recurring Basis) (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Assets    
Cash equivalents and Restricted cash $ 176 $ 11
Derivative assets    
Total derivative assets, gross 707 694
Total derivative assets, netting (475) (447)
Total derivative assets, net balance 232 247
Total Assets 3,093 2,622
Derivative liabilities    
Total derivative liabilities, gross (597) (605)
Total derivative liability, netting 445 430
Total Liabilities (152) (175)
Net Assets (Liabilities) at end of period 2,941 2,447
Net Assets (Liabilities) at end of period, netting (30) (17)
DTE Electric    
Assets    
Cash equivalents and Restricted cash 83 8
Nuclear decommissioning trusts 2,552 2,256
Derivative assets    
Total Assets 2,707 2,318
Current assets    
Derivative assets    
Total derivative assets, netting (339) (326)
Total Assets 319 173
Current assets | DTE Electric    
Derivative assets    
Total Assets 94 17
Noncurrent assets    
Derivative assets    
Total derivative assets, netting (136) (121)
Total Assets 2,774 2,449
Noncurrent assets | DTE Electric    
Derivative assets    
Total Assets 2,613 2,301
Current liabilities    
Derivative liabilities    
Total derivative liabilities, gross (413) (441)
Total derivative liability, netting 327 323
Total Liabilities (86) (118)
Noncurrent liabilities    
Derivative liabilities    
Total derivative liabilities, gross (184) (164)
Total derivative liability, netting 118 107
Total Liabilities (66) (57)
Restricted cash    
Assets    
Cash equivalents and Restricted cash 10 8
Restricted cash | DTE Electric    
Assets    
Cash equivalents and Restricted cash 10 8
Natural Gas    
Derivative assets    
Total derivative assets, gross 372 428
Total derivative assets, netting (235) (285)
Total derivative assets, net balance 137 143
Derivative liabilities    
Total derivative liabilities, gross (329) (410)
Total derivative liability, netting 227 272
Total derivative liabilities, net balance (102) (138)
Electricity    
Derivative assets    
Total derivative assets, gross 275 187
Total derivative assets, netting (194) (116)
Total derivative assets, net balance 81 71
Derivative liabilities    
Total derivative liabilities, gross (235) (150)
Total derivative liability, netting 186 114
Total derivative liabilities, net balance (49) (36)
Environmental & Other    
Derivative assets    
Total derivative assets, gross 57 58
Total derivative assets, netting (46) (46)
Total derivative assets, net balance 11 12
Derivative liabilities    
Total derivative liabilities, gross (32) (44)
Total derivative liability, netting 32 44
Total derivative liabilities, net balance 0 0
Other contracts    
Derivative assets    
Total derivative assets, netting 0 0
Total derivative assets, net balance 3 21
Derivative liabilities    
Total derivative liability, netting 0 0
Total derivative liabilities, net balance (1) (1)
Derivative assets — FTRs | DTE Electric    
Derivative assets    
Total derivative assets, net balance 11 9
Cash equivalents    
Assets    
Nuclear decommissioning trusts 35 26
Other investments 38 29
Cash equivalents | DTE Electric    
Assets    
Nuclear decommissioning trusts 35 26
Other investments 26 19
Private equity and other    
Assets    
Nuclear decommissioning trusts 358 349
Private equity and other | DTE Electric    
Assets    
Nuclear decommissioning trusts 358 349
Hedge Funds and Similar Investments    
Assets    
Nuclear decommissioning trusts 245 228
Hedge Funds and Similar Investments | DTE Electric    
Assets    
Nuclear decommissioning trusts 245 228
Equity securities    
Assets    
Nuclear decommissioning trusts 1,188 1,003
Other investments 84 72
Equity securities | DTE Electric    
Assets    
Nuclear decommissioning trusts 1,188 1,003
Other investments 33 26
Fixed income securities    
Assets    
Nuclear decommissioning trusts 726 650
Other investments 11 7
Fixed income securities | DTE Electric    
Assets    
Nuclear decommissioning trusts 726 650
Other investments 2 0
Level 1    
Assets    
Cash equivalents and Restricted cash 176 11
Derivative assets    
Total derivative assets, gross 334 310
Total Assets 2,024 1,602
Derivative liabilities    
Total Liabilities (321) (290)
Net Assets (Liabilities) at end of period 1,703 1,312
Level 1 | DTE Electric    
Assets    
Cash equivalents and Restricted cash 83 8
Derivative assets    
Total Assets 1,525 1,226
Level 1 | Current assets    
Derivative assets    
Total Assets 426 223
Level 1 | Current assets | DTE Electric    
Derivative assets    
Total Assets 83 8
Level 1 | Noncurrent assets    
Derivative assets    
Total Assets 1,598 1,379
Level 1 | Noncurrent assets | DTE Electric    
Derivative assets    
Total Assets 1,442 1,218
Level 1 | Current liabilities    
Derivative liabilities    
Total Liabilities (240) (219)
Level 1 | Noncurrent liabilities    
Derivative liabilities    
Total Liabilities (81) (71)
Level 1 | Natural Gas    
Derivative assets    
Total derivative assets, gross 207 242
Derivative liabilities    
Total derivative liabilities, gross (196) (217)
Level 1 | Electricity    
Derivative assets    
Total derivative assets, gross 127 67
Derivative liabilities    
Total derivative liabilities, gross (124) (71)
Level 1 | Environmental & Other    
Derivative assets    
Total derivative assets, gross 0 1
Derivative liabilities    
Total derivative liabilities, gross (1) (2)
Level 1 | Other contracts    
Derivative assets    
Total derivative assets, gross 0 0
Derivative liabilities    
Total derivative liabilities, gross 0 0
Level 1 | Derivative assets — FTRs | DTE Electric    
Derivative assets    
Total derivative assets, net balance 0 0
Level 1 | Cash equivalents    
Assets    
Nuclear decommissioning trusts 35 26
Other investments 38 29
Level 1 | Cash equivalents | DTE Electric    
Assets    
Nuclear decommissioning trusts 35 26
Other investments 26 19
Level 1 | Private equity and other    
Assets    
Nuclear decommissioning trusts 0 16
Level 1 | Private equity and other | DTE Electric    
Assets    
Nuclear decommissioning trusts 0 16
Level 1 | Hedge Funds and Similar Investments    
Assets    
Nuclear decommissioning trusts 228 151
Level 1 | Hedge Funds and Similar Investments | DTE Electric    
Assets    
Nuclear decommissioning trusts 228 151
Level 1 | Equity securities    
Assets    
Nuclear decommissioning trusts 987 856
Other investments 84 72
Level 1 | Equity securities | DTE Electric    
Assets    
Nuclear decommissioning trusts 987 856
Other investments 33 26
Level 1 | Fixed income securities    
Assets    
Nuclear decommissioning trusts 133 124
Other investments 9 7
Level 1 | Fixed income securities | DTE Electric    
Assets    
Nuclear decommissioning trusts 133 124
Other investments 0 0
Level 2    
Assets    
Cash equivalents and Restricted cash 0 0
Derivative assets    
Total derivative assets, gross 220 218
Total Assets 699 648
Derivative liabilities    
Total Liabilities (142) (162)
Net Assets (Liabilities) at end of period 557 486
Level 2 | DTE Electric    
Assets    
Cash equivalents and Restricted cash 0 0
Derivative assets    
Total Assets 479 430
Level 2 | Current assets    
Derivative assets    
Total Assets 130 170
Level 2 | Current assets | DTE Electric    
Derivative assets    
Total Assets 0 0
Level 2 | Noncurrent assets    
Derivative assets    
Total Assets 569 478
Level 2 | Noncurrent assets | DTE Electric    
Derivative assets    
Total Assets 479 430
Level 2 | Current liabilities    
Derivative liabilities    
Total Liabilities (106) (129)
Level 2 | Noncurrent liabilities    
Derivative liabilities    
Total Liabilities (36) (33)
Level 2 | Natural Gas    
Derivative assets    
Total derivative assets, gross 56 81
Derivative liabilities    
Total derivative liabilities, gross (51) (70)
Level 2 | Electricity    
Derivative assets    
Total derivative assets, gross 115 69
Derivative liabilities    
Total derivative liabilities, gross (59) (52)
Level 2 | Environmental & Other    
Derivative assets    
Total derivative assets, gross 46 47
Derivative liabilities    
Total derivative liabilities, gross (31) (39)
Level 2 | Other contracts    
Derivative assets    
Total derivative assets, gross 3 21
Derivative liabilities    
Total derivative liabilities, gross (1) (1)
Level 2 | Derivative assets — FTRs | DTE Electric    
Derivative assets    
Total derivative assets, net balance 0 0
Level 2 | Cash equivalents    
Assets    
Nuclear decommissioning trusts 0 0
Other investments 0 0
Level 2 | Cash equivalents | DTE Electric    
Assets    
Nuclear decommissioning trusts 0 0
Other investments 0 0
Level 2 | Private equity and other    
Assets    
Nuclear decommissioning trusts 0 0
Level 2 | Private equity and other | DTE Electric    
Assets    
Nuclear decommissioning trusts 0 0
Level 2 | Hedge Funds and Similar Investments    
Assets    
Nuclear decommissioning trusts 17 16
Level 2 | Hedge Funds and Similar Investments | DTE Electric    
Assets    
Nuclear decommissioning trusts 17 16
Level 2 | Equity securities    
Assets    
Nuclear decommissioning trusts 0 0
Other investments 0 0
Level 2 | Equity securities | DTE Electric    
Assets    
Nuclear decommissioning trusts 0 0
Other investments 0 0
Level 2 | Fixed income securities    
Assets    
Nuclear decommissioning trusts 460 414
Other investments 2 0
Level 2 | Fixed income securities | DTE Electric    
Assets    
Nuclear decommissioning trusts 460 414
Other investments 2 0
Level 3    
Assets    
Cash equivalents and Restricted cash 0 0
Derivative assets    
Total derivative assets, gross 153 166
Total Assets 153 166
Derivative liabilities    
Total Liabilities (134) (153)
Net Assets (Liabilities) at end of period 19 13
Level 3 | DTE Electric    
Assets    
Cash equivalents and Restricted cash 0 0
Derivative assets    
Total Assets 11 9
Level 3 | Current assets    
Derivative assets    
Total Assets 102 106
Level 3 | Current assets | DTE Electric    
Derivative assets    
Total Assets 11 9
Level 3 | Noncurrent assets    
Derivative assets    
Total Assets 51 60
Level 3 | Noncurrent assets | DTE Electric    
Derivative assets    
Total Assets 0 0
Level 3 | Current liabilities    
Derivative liabilities    
Total Liabilities (67) (93)
Level 3 | Noncurrent liabilities    
Derivative liabilities    
Total Liabilities (67) (60)
Level 3 | Natural Gas    
Derivative assets    
Total derivative assets, gross 109 105
Derivative liabilities    
Total derivative liabilities, gross (82) (123)
Level 3 | Electricity    
Derivative assets    
Total derivative assets, gross 33 51
Derivative liabilities    
Total derivative liabilities, gross (52) (27)
Level 3 | Environmental & Other    
Derivative assets    
Total derivative assets, gross 11 10
Derivative liabilities    
Total derivative liabilities, gross 0 (3)
Level 3 | Other contracts    
Derivative assets    
Total derivative assets, gross 0 0
Derivative liabilities    
Total derivative liabilities, gross 0 0
Level 3 | Derivative assets — FTRs | DTE Electric    
Derivative assets    
Total derivative assets, net balance 11 9
Level 3 | Cash equivalents    
Assets    
Nuclear decommissioning trusts 0 0
Other investments 0 0
Level 3 | Cash equivalents | DTE Electric    
Assets    
Nuclear decommissioning trusts 0 0
Other investments 0 0
Level 3 | Private equity and other    
Assets    
Nuclear decommissioning trusts 0 0
Level 3 | Private equity and other | DTE Electric    
Assets    
Nuclear decommissioning trusts 0 0
Level 3 | Hedge Funds and Similar Investments    
Assets    
Nuclear decommissioning trusts 0 0
Level 3 | Hedge Funds and Similar Investments | DTE Electric    
Assets    
Nuclear decommissioning trusts 0 0
Level 3 | Equity securities    
Assets    
Nuclear decommissioning trusts 0 0
Other investments 0 0
Level 3 | Equity securities | DTE Electric    
Assets    
Nuclear decommissioning trusts 0 0
Other investments 0 0
Level 3 | Fixed income securities    
Assets    
Nuclear decommissioning trusts 0 0
Other investments 0 0
Level 3 | Fixed income securities | DTE Electric    
Assets    
Nuclear decommissioning trusts 0 0
Other investments 0 0
Other    
Derivative assets    
Total Assets 692 653
Derivative liabilities    
Net Assets (Liabilities) at end of period 692 653
Other | DTE Electric    
Derivative assets    
Total Assets 692 653
Other | Noncurrent assets    
Derivative assets    
Total Assets 692 653
Other | Noncurrent assets | DTE Electric    
Derivative assets    
Total Assets 692 653
Other | Private equity and other    
Assets    
Nuclear decommissioning trusts 358 333
Other | Private equity and other | DTE Electric    
Assets    
Nuclear decommissioning trusts 358 333
Other | Hedge Funds and Similar Investments    
Assets    
Nuclear decommissioning trusts 0 61
Other | Hedge Funds and Similar Investments | DTE Electric    
Assets    
Nuclear decommissioning trusts 0 61
Other | Equity securities    
Assets    
Nuclear decommissioning trusts 201 147
Other | Equity securities | DTE Electric    
Assets    
Nuclear decommissioning trusts 201 147
Other | Fixed income securities    
Assets    
Nuclear decommissioning trusts 133 112
Other | Fixed income securities | DTE Electric    
Assets    
Nuclear decommissioning trusts $ 133 $ 112
v3.25.4
Fair Value (Details Textuals) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Nuclear decommissioning trusts | Fixed Income Securities    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Securities with no contractual maturity date $ 133  
Private Equity and Other    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Unfunded commitments related to investments classified as NAV assets $ 179 $ 120
Minimum | Equity or debt securities    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Investments, redemption notice period (in days) 7 days  
Minimum | Private Equity and Other    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Investments classified as NAV assets, general contractual durations (in years) 7 years  
Maximum | Equity or debt securities    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Investments, redemption notice period (in days) 65 days  
Maximum | Private Equity and Other    
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]    
Investments classified as NAV assets, general contractual durations (in years) 12 years  
v3.25.4
Fair Value (Reconciliation of Level 3 Assets and Liabilities at Fair Value on a Recurring Basis) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]    
Net Assets (Liabilities) as of January 1 $ 13 $ 75
Transfers into Level 3 from Level 2 2 1
Transfers from Level 3 into Level 2 2 74
Total gains (losses)    
Included in earnings 308 240
Recorded in Regulatory liabilities 19 21
Purchases, issuances, and settlements:    
Settlements (325) (398)
Net Assets (Liabilities) as of December 31 19 13
Total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31 4 (88)
Total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31 $ 11 $ 9
Fair Value, Net Derivative Asset (Liability), Recurring Basis, Unobservable Input Reconciliation, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] Non-utility operations Non-utility operations
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration] Non-utility operations Non-utility operations
Natural Gas    
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]    
Net Assets (Liabilities) as of January 1 $ (18) $ 22
Transfers into Level 3 from Level 2 2 1
Transfers from Level 3 into Level 2 0 0
Total gains (losses)    
Included in earnings (25) 16
Recorded in Regulatory liabilities 0 0
Purchases, issuances, and settlements:    
Settlements 68 (57)
Net Assets (Liabilities) as of December 31 27 (18)
Total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31 23 (47)
Total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31 0 0
Electricity    
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]    
Net Assets (Liabilities) as of January 1 24 47
Transfers into Level 3 from Level 2 0 0
Transfers from Level 3 into Level 2 0 74
Total gains (losses)    
Included in earnings 329 225
Recorded in Regulatory liabilities 0 0
Purchases, issuances, and settlements:    
Settlements (372) (322)
Net Assets (Liabilities) as of December 31 (19) 24
Total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31 (19) 118
Total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31 0 0
Other    
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]    
Net Assets (Liabilities) as of January 1 7 6
Transfers into Level 3 from Level 2 0 0
Transfers from Level 3 into Level 2 2 0
Total gains (losses)    
Included in earnings 4 (1)
Recorded in Regulatory liabilities 19 21
Purchases, issuances, and settlements:    
Settlements (21) (19)
Net Assets (Liabilities) as of December 31 11 7
Total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31 0 (159)
Total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31 11 9
DTE Electric    
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]    
Net Assets (Liabilities) as of January 1 9 7
Total gains (losses)    
Recorded in Regulatory liabilities 19 21
Purchases, issuances, and settlements:    
Settlements (17) (19)
Net Assets (Liabilities) as of December 31 11 9
Total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31 $ 11 $ 9
v3.25.4
Fair Value (Unobservable Inputs related to Level 3 Assets and Liabilities) (Details)
$ in Millions
Dec. 31, 2025
USD ($)
$ / MWh
$ / MMBTU
Dec. 31, 2024
USD ($)
$ / MMBTU
$ / MWh
Unobservable Input Valuation Techniques [Line Items]    
Derivative Assets $ 707 $ 694
Derivative Liabilities (597) (605)
Natural Gas    
Unobservable Input Valuation Techniques [Line Items]    
Derivative Assets 372 428
Derivative Liabilities (329) (410)
Electricity    
Unobservable Input Valuation Techniques [Line Items]    
Derivative Assets 275 187
Derivative Liabilities (235) (150)
Level 3    
Unobservable Input Valuation Techniques [Line Items]    
Derivative Assets 153 166
Level 3 | Natural Gas    
Unobservable Input Valuation Techniques [Line Items]    
Derivative Assets 109 105
Derivative Liabilities (82) (123)
Level 3 | Electricity    
Unobservable Input Valuation Techniques [Line Items]    
Derivative Assets 33 51
Derivative Liabilities $ (52) $ (27)
Level 3 | Discounted Cash Flow | Forward basis price | Natural Gas | Minimum    
Unobservable Input Valuation Techniques [Line Items]    
Forward basis price | $ / MMBTU (1.35) (1.24)
Level 3 | Discounted Cash Flow | Forward basis price | Natural Gas | Maximum    
Unobservable Input Valuation Techniques [Line Items]    
Forward basis price | $ / MMBTU 9.33 9.96
Level 3 | Discounted Cash Flow | Forward basis price | Natural Gas | Weighted Average    
Unobservable Input Valuation Techniques [Line Items]    
Forward basis price | $ / MMBTU (0.13) (0.05)
Level 3 | Discounted Cash Flow | Forward basis price | Electricity | Minimum    
Unobservable Input Valuation Techniques [Line Items]    
Forward basis price | $ / MWh (21.82) (16.34)
Level 3 | Discounted Cash Flow | Forward basis price | Electricity | Maximum    
Unobservable Input Valuation Techniques [Line Items]    
Forward basis price | $ / MWh 17.79 17.28
Level 3 | Discounted Cash Flow | Forward basis price | Electricity | Weighted Average    
Unobservable Input Valuation Techniques [Line Items]    
Forward basis price | $ / MWh (5.58) (2.74)
v3.25.4
Fair Value (Carrying Amount of Fair Value of Financial Instruments) (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Carrying Amount    
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]    
Notes receivable $ 1,453 $ 884
Short-term borrowings 882 1,067
Notes payable 28 37
Long-term debt 25,123 21,963
Carrying Amount | DTE Electric    
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]    
Short-term borrowings 652 666
Notes payable 24 35
Long-term debt 13,165 11,881
Carrying Amount | DTE Electric | Affiliates    
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]    
Notes receivable 0 42
Carrying Amount | DTE Electric | Other    
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]    
Notes receivable 274 2
Fair Value | Level 1    
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]    
Notes receivable 0 0
Short-term borrowings 0 0
Notes payable 0 0
Long-term debt 1,285 725
Fair Value | Level 1 | DTE Electric    
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]    
Short-term borrowings 0 0
Notes payable 0 0
Long-term debt 0 0
Fair Value | Level 1 | DTE Electric | Affiliates    
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]    
Notes receivable 0 0
Fair Value | Level 1 | DTE Electric | Other    
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]    
Notes receivable 0 0
Fair Value | Level 2    
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]    
Notes receivable 0 0
Short-term borrowings 882 1,067
Notes payable 0 0
Long-term debt 21,204 18,283
Fair Value | Level 2 | DTE Electric    
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]    
Short-term borrowings 652 666
Notes payable 0 0
Long-term debt 12,048 10,449
Fair Value | Level 2 | DTE Electric | Affiliates    
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]    
Notes receivable 0 0
Fair Value | Level 2 | DTE Electric | Other    
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]    
Notes receivable 0 0
Fair Value | Level 3    
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]    
Notes receivable 1,482 904
Short-term borrowings 0 0
Notes payable 28 37
Long-term debt 1,351 1,128
Fair Value | Level 3 | DTE Electric    
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]    
Short-term borrowings 0 0
Notes payable 24 35
Long-term debt 131 127
Fair Value | Level 3 | DTE Electric | Affiliates    
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]    
Notes receivable 0 42
Fair Value | Level 3 | DTE Electric | Other    
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]    
Notes receivable $ 289 $ 2
v3.25.4
Fair Value (Fair Value of Nuclear Decommissioning Trust Fund Assets) (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Debt Securities, Available-for-sale [Line Items]    
Nuclear decommissioning trust funds $ 2,552 $ 2,256
DTE Electric    
Debt Securities, Available-for-sale [Line Items]    
Nuclear decommissioning trust funds 2,552 2,256
DTE Electric | Nuclear decommissioning trusts    
Debt Securities, Available-for-sale [Line Items]    
Nuclear decommissioning trust funds 2,552 2,256
DTE Electric | Nuclear decommissioning trusts | Fermi 2    
Debt Securities, Available-for-sale [Line Items]    
Nuclear decommissioning trust funds 2,523 2,234
DTE Electric | Nuclear decommissioning trusts | Fermi 1    
Debt Securities, Available-for-sale [Line Items]    
Nuclear decommissioning trust funds 3 3
DTE Electric | Nuclear decommissioning trusts | Low-level radioactive waste    
Debt Securities, Available-for-sale [Line Items]    
Nuclear decommissioning trust funds $ 26 $ 19
v3.25.4
Fair Value (Realized Gains and Losses and Proceeds from Sale of Securities by Nuclear Decommissioning Trust Funds) (Details) - DTE Electric - Nuclear decommissioning trusts - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Debt Securities, Available-for-sale [Line Items]      
Realized gains $ 50 $ 47 $ 36
Realized losses (32) (27) (42)
Proceeds from sale of securities $ 717 $ 555 $ 681
v3.25.4
Fair Value (Fair Value and Unrealized Gains and Losses for Nuclear Decommissioning Trust Funds) (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Cash equivalents    
Debt Securities, Available-for-sale [Line Items]    
Fair Value $ 35 $ 26
Private Equity and Other    
Debt Securities, Available-for-sale [Line Items]    
Fair Value 358 349
Hedge Funds and Similar Investments    
Debt Securities, Available-for-sale [Line Items]    
Fair Value 245 228
Equity securities    
Debt Securities, Available-for-sale [Line Items]    
Fair Value 1,188 1,003
Fixed Income Securities    
Debt Securities, Available-for-sale [Line Items]    
Fair Value 726 650
DTE Electric    
Debt Securities, Available-for-sale [Line Items]    
Fair Value 2,552 2,256
Unrealized Gains 900 687
Unrealized Losses (40) (58)
DTE Electric | Cash equivalents    
Debt Securities, Available-for-sale [Line Items]    
Fair Value 35 26
Unrealized Gains 0 0
Unrealized Losses 0 0
DTE Electric | Private Equity and Other    
Debt Securities, Available-for-sale [Line Items]    
Fair Value 358 349
Unrealized Gains 125 106
Unrealized Losses (7) (8)
DTE Electric | Hedge Funds and Similar Investments    
Debt Securities, Available-for-sale [Line Items]    
Fair Value 245 228
Unrealized Gains 8 7
Unrealized Losses (6) (5)
DTE Electric | Equity securities    
Debt Securities, Available-for-sale [Line Items]    
Fair Value 1,188 1,003
Unrealized Gains 742 558
Unrealized Losses (10) (16)
DTE Electric | Fixed Income Securities    
Debt Securities, Available-for-sale [Line Items]    
Fair Value 726 650
Unrealized Gains 25 16
Unrealized Losses $ (17) $ (29)
v3.25.4
Fair Value (Fair Value of the Fixed Income Securities Held in Nuclear Decommissioning Trust Funds) (Details) - Nuclear decommissioning trusts - Fixed Income Securities
$ in Millions
Dec. 31, 2025
USD ($)
Debt Securities, Available-for-sale [Line Items]  
Due within one year $ 20
Due after one through five years 93
Due after five through ten years 127
Due after ten years 353
Fixed income securities total $ 593
v3.25.4
Financial and Other Derivative Instruments (Fair Value of Derivative Instruments) (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Derivatives, Fair Value [Line Items]    
Derivative Assets $ 707 $ 694
Derivative Liabilities $ (597) $ (605)
Derivative Asset, Statement of Financial Position [Extensible Enumeration] Derivative Asset, Current, Derivative Asset, Noncurrent Derivative Asset, Current, Derivative Asset, Noncurrent
Current derivative assets    
Derivatives, Fair Value [Line Items]    
Derivative Assets $ 482 $ 488
Current derivative liabilities    
Derivatives, Fair Value [Line Items]    
Derivative Liabilities (413) (441)
Noncurrent derivative assets    
Derivatives, Fair Value [Line Items]    
Derivative Assets 225 206
Noncurrent derivative liabilities    
Derivatives, Fair Value [Line Items]    
Derivative Liabilities (184) (164)
Interest rate contracts (Enter as Other)    
Derivatives, Fair Value [Line Items]    
Derivative Assets 3 20
Foreign currency exchange contracts    
Derivatives, Fair Value [Line Items]    
Derivative Assets 0 1
Derivative Liabilities (1) (1)
Natural gas    
Derivatives, Fair Value [Line Items]    
Derivative Assets 372 428
Derivative Liabilities (329) (410)
Electricity    
Derivatives, Fair Value [Line Items]    
Derivative Assets 275 187
Derivative Liabilities (235) (150)
Environmental & Other    
Derivatives, Fair Value [Line Items]    
Derivative Assets 57 58
Derivative Liabilities (32) (44)
Derivatives designated as hedging instruments    
Derivatives, Fair Value [Line Items]    
Derivative Assets 3 20
Derivative Liabilities (1) (1)
Derivatives designated as hedging instruments | Interest rate contracts (Enter as Other)    
Derivatives, Fair Value [Line Items]    
Derivative Assets 3 20
Derivative Liabilities 0 0
Derivatives designated as hedging instruments | Foreign currency exchange contracts    
Derivatives, Fair Value [Line Items]    
Derivative Assets 0 0
Derivative Liabilities (1) (1)
Derivatives not designated as hedging instruments    
Derivatives, Fair Value [Line Items]    
Derivative Assets 704 674
Derivative Liabilities (596) (604)
Derivatives not designated as hedging instruments | Foreign currency exchange contracts    
Derivatives, Fair Value [Line Items]    
Derivative Assets 0 1
Derivative Liabilities 0 0
Derivatives not designated as hedging instruments | Natural gas    
Derivatives, Fair Value [Line Items]    
Derivative Assets 372 428
Derivative Liabilities (329) (410)
Derivatives not designated as hedging instruments | Electricity    
Derivatives, Fair Value [Line Items]    
Derivative Assets 275 187
Derivative Liabilities (235) (150)
Derivatives not designated as hedging instruments | Environmental & Other    
Derivatives, Fair Value [Line Items]    
Derivative Assets 57 58
Derivative Liabilities $ (32) $ (44)
v3.25.4
Financial and Other Derivative Instruments (Details Textuals) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Derivative [Line Items]    
Total derivative assets, gross $ 707 $ 694
Letters of credit that could be used to offset net derivative liabilities 2 1
Letters of credit that could be used to offset net derivative assets 17 0
Additional collateral, aggregate fair value 483  
Derivative net liability position aggregate fair value 491  
Collateral already posted fair value 3  
Derivative, net asset position, fair value 426  
Remaining amount of offsets to derivative net liability positions for hard and soft trigger provisions 62  
Derivatives not designated as hedging instruments    
Derivative [Line Items]    
Total derivative assets, gross 704 674
Other current assets | Derivative assets — FTRs | Derivatives not designated as hedging instruments | DTE Electric    
Derivative [Line Items]    
Total derivative assets, gross $ 11 $ 9
v3.25.4
Financial and Other Derivative Instruments (Net Cash Collateral Offsetting Arrangements) (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]    
Cash collateral netted against Derivative assets $ (35) $ (17)
Cash collateral netted against Derivative liabilities 5 0
Cash collateral recorded in Accounts receivable 20 29
Cash collateral recorded in Accounts payable (28) (5)
Total net cash collateral posted (received) $ (38) $ 7
v3.25.4
Financial and Other Derivative Instruments (Netting Offsets of Derivative Assets and Liabilities) (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Derivative assets    
Gross Amounts of Recognized Assets (Liabilities) $ 707 $ 694
Gross Amounts Offset in the Consolidated Statements of Financial Position (475) (447)
Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position 232 247
Derivative liabilities    
Gross Amounts of Recognized Assets (Liabilities) (597) (605)
Gross Amounts Offset in the Consolidated Statements of Financial Position 445 430
Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position (152) (175)
Natural gas    
Derivative assets    
Gross Amounts of Recognized Assets (Liabilities) 372 428
Gross Amounts Offset in the Consolidated Statements of Financial Position (235) (285)
Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position 137 143
Derivative liabilities    
Gross Amounts of Recognized Assets (Liabilities) (329) (410)
Gross Amounts Offset in the Consolidated Statements of Financial Position 227 272
Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position (102) (138)
Electricity    
Derivative assets    
Gross Amounts of Recognized Assets (Liabilities) 275 187
Gross Amounts Offset in the Consolidated Statements of Financial Position (194) (116)
Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position 81 71
Derivative liabilities    
Gross Amounts of Recognized Assets (Liabilities) (235) (150)
Gross Amounts Offset in the Consolidated Statements of Financial Position 186 114
Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position (49) (36)
Environmental & Other    
Derivative assets    
Gross Amounts of Recognized Assets (Liabilities) 57 58
Gross Amounts Offset in the Consolidated Statements of Financial Position (46) (46)
Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position 11 12
Derivative liabilities    
Gross Amounts of Recognized Assets (Liabilities) (32) (44)
Gross Amounts Offset in the Consolidated Statements of Financial Position 32 44
Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position 0 0
Interest rate contracts (Enter as Other)    
Derivative assets    
Gross Amounts of Recognized Assets (Liabilities) 3 20
Gross Amounts Offset in the Consolidated Statements of Financial Position 0 0
Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position 3 20
Foreign currency exchange contracts    
Derivative assets    
Gross Amounts of Recognized Assets (Liabilities) 0 1
Gross Amounts Offset in the Consolidated Statements of Financial Position 0 0
Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position 0 1
Derivative liabilities    
Gross Amounts of Recognized Assets (Liabilities) (1) (1)
Gross Amounts Offset in the Consolidated Statements of Financial Position 0 0
Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position $ (1) $ (1)
v3.25.4
Financial and Other Derivative Instruments ( Netting Offsets of Derivative Assets and Liabilities Reconciliation to the Statements of Financial Position) (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Derivative Assets    
Derivative Assets $ 707 $ 694
Collateral adjustment (35) (17)
Total derivatives assets as reported, current 143 162
Total derivatives assets as reported, noncurrent 89 85
Derivative Liabilities    
Derivative Liabilities (597) (605)
Collateral adjustment 5 0
Total derivatives liabilities as reported, current (86) (118)
Total derivatives liabilities as reported, noncurrent (66) (57)
Current derivative assets    
Derivative Assets    
Derivative Assets 482 488
Counterparty netting (325) (323)
Collateral adjustment (14) (3)
Noncurrent derivative assets    
Derivative Assets    
Derivative Assets 225 206
Counterparty netting (115) (107)
Collateral adjustment (21) (14)
Current derivative liabilities    
Derivative Liabilities    
Derivative Liabilities (413) (441)
Counterparty netting 325 323
Collateral adjustment 2 0
Noncurrent derivative liabilities    
Derivative Liabilities    
Derivative Liabilities (184) (164)
Counterparty netting 115 107
Collateral adjustment $ 3 $ 0
v3.25.4
Financial and Other Derivative Instruments (Effect of Derivatives Not Designated as Hedging Instruments) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Derivative Instruments, Gain (Loss) [Line Items]      
Total $ 373 $ 347 $ 383
Natural gas | Operating Revenues — Non-utility operations      
Derivative Instruments, Gain (Loss) [Line Items]      
Total 112 (169) 153
Natural gas | Fuel, purchased power, gas, and other — non-utility      
Derivative Instruments, Gain (Loss) [Line Items]      
Total (160) 233 122
Electricity | Operating Revenues — Non-utility operations      
Derivative Instruments, Gain (Loss) [Line Items]      
Total 361 266 105
Environmental & Other | Operating Revenues — Non-utility operations      
Derivative Instruments, Gain (Loss) [Line Items]      
Total 61 14 5
Foreign currency exchange contracts | Operating Revenues — Non-utility operations      
Derivative Instruments, Gain (Loss) [Line Items]      
Total $ (1) $ 3 $ (2)
v3.25.4
Financial and Other Derivative Instruments (Cumulative Gross Volume of Derivative Contracts) (Details) - 12 months ended Dec. 31, 2025
CAD ($)
MWh
MMBTU
T
USD ($)
Natural gas (MMBtu)    
Derivative [Line Items]    
Notional amount, energy measure | MMBTU 2,451,423,819  
Electricity (MWh)    
Derivative [Line Items]    
Notional amount, energy measure 39,287,109  
Foreign currency exchange ($ CAD)    
Derivative [Line Items]    
Notional amount, monetary measure | $ $ 67,058,920  
FTR (MWh)    
Derivative [Line Items]    
Notional amount, energy measure 82,664  
Renewable Energy Certificates (MWh)    
Derivative [Line Items]    
Notional amount, energy measure 11,860,903  
Carbon emissions (Metric Ton)    
Derivative [Line Items]    
Notional amount, mass measure | T 1,113,500  
Interest rate contracts ($ USD)    
Derivative [Line Items]    
Notional amount, monetary measure | $   $ 300,000,000
v3.25.4
Long-Term Financings (Long-term Debt) (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Debt Instrument [Line Items]    
Total $ 25,306  
Mortgage Bonds, Notes and Other    
Debt Instrument [Line Items]    
Long-term debt, gross 23,154 $ 20,515
Unamortized debt discount (14) (28)
Unamortized debt issuance costs (127) (114)
Long-term debt due within one year (1,277) (1,220)
Long-term debt (net of current portion) $ 21,736 19,153
Unsecured    
Debt Instrument [Line Items]    
Interest rate 4.70%  
Long-term debt, gross $ 7,479 6,380
Securitization Bonds    
Debt Instrument [Line Items]    
Unamortized debt issuance costs (6) (7)
Long-term debt due within one year (75) (71)
Long-term debt (net of current portion) $ 561 635
Junior Subordinated Debentures    
Debt Instrument [Line Items]    
Interest rate 5.40%  
Long-term debt, gross $ 1,510 910
Unamortized debt issuance costs (36) (26)
Total 1,474 884
DTE Electric    
Debt Instrument [Line Items]    
Long-term debt due within one year (677) (350)
Total 13,262  
DTE Electric | Mortgage Bonds, Notes and Other    
Debt Instrument [Line Items]    
Unamortized debt discount (11) (22)
Unamortized debt issuance costs (80) (73)
Long-term debt (net of current portion) $ 11,852 10,825
DTE Electric | Principally Secured    
Debt Instrument [Line Items]    
Interest rate 4.20%  
Long-term debt, gross $ 12,620 11,270
DTE Electric | Securitization Bonds    
Debt Instrument [Line Items]    
Interest rate 5.60%  
Long-term debt, gross $ 642 713
Unamortized debt issuance costs (6) (7)
Long-term debt due within one year (75) (71)
Long-term debt (net of current portion) $ 561 635
DTE Gas | Principally Secured    
Debt Instrument [Line Items]    
Interest rate 4.40%  
Long-term debt, gross $ 3,055 $ 2,865
v3.25.4
Long-Term Financings (Debt Issuances) (Details)
$ in Millions
Dec. 31, 2025
USD ($)
Debt Instrument [Line Items]  
Amount $ 4,460
Senior Notes | February 2025 5.20% Senior Notes Maturing In 2030  
Debt Instrument [Line Items]  
Interest Rate 5.20%
Amount $ 1,100
Senior Notes | September 2025 4.88% Senior Notes Maturing In 2028  
Debt Instrument [Line Items]  
Interest Rate 4.88%
Amount $ 250
Senior Notes | September 2025 5.05% Senior Notes Maturing In 2035  
Debt Instrument [Line Items]  
Interest Rate 5.05%
Amount $ 550
Junior Subordinated Debentures | September 2025 6.25% Junior Subordinated Debentures Maturing In 2085  
Debt Instrument [Line Items]  
Interest Rate 6.25%
Amount $ 600
DTE Electric | Mortgage Bonds | May 2025 5.25% Mortgage Bonds Maturing In 2035  
Debt Instrument [Line Items]  
Interest Rate 5.25%
Amount $ 500
DTE Electric | Mortgage Bonds | May 2025 5.85% Mortgage Bonds Maturing In 2055  
Debt Instrument [Line Items]  
Interest Rate 5.85%
Amount $ 500
DTE Electric | Mortgage Bonds | May 2025 4.25% Mortgage Bonds Maturing In 2027  
Debt Instrument [Line Items]  
Interest Rate 4.25%
Amount $ 300
DTE Electric | Mortgage Bonds | November 2025 5.25% Mortgage Bonds Maturing In 2035  
Debt Instrument [Line Items]  
Interest Rate 5.25%
Amount $ 200
DTE Electric | Mortgage Bonds | November 2025 5.85% Mortgage Bonds Maturing In 2055  
Debt Instrument [Line Items]  
Interest Rate 5.85%
Amount $ 200
DTE Gas | Mortgage Bonds | September 2025 4.71% Mortgage Bonds Maturing In 2031  
Debt Instrument [Line Items]  
Interest Rate 4.71%
Amount $ 50
DTE Gas | Mortgage Bonds | September 2025 5.36% Mortgage Bonds Maturing In 2037  
Debt Instrument [Line Items]  
Interest Rate 5.36%
Amount $ 75
DTE Gas | Mortgage Bonds | September 2025 5.96% Mortgage Bonds Maturing In 2055  
Debt Instrument [Line Items]  
Interest Rate 5.96%
Amount $ 135
v3.25.4
Long-Term Financings (Debt Redemptions) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Debt Instrument, Redemption [Line Items]      
Amount $ 1,291 $ 2,139 $ 1,616
Senior Notes | Senior Notes 1.05% Due 2025      
Debt Instrument, Redemption [Line Items]      
Interest Rate 1.05%    
Amount $ 800    
DTE Electric      
Debt Instrument, Redemption [Line Items]      
Amount $ 421 $ 164 $ 541
DTE Electric | Mortgage Bonds | Mortgage Bonds 3.38% Due 2025      
Debt Instrument, Redemption [Line Items]      
Interest Rate 3.38%    
Amount $ 350    
DTE Electric | Securitization Bonds | Securitization Bonds 5.97% Due 2025      
Debt Instrument, Redemption [Line Items]      
Interest Rate 5.97%    
Amount $ 15    
DTE Electric | Securitization Bonds | Securitization Bonds 2.64% Due 2025      
Debt Instrument, Redemption [Line Items]      
Interest Rate 2.64%    
Amount $ 20    
DTE Electric | Securitization Bonds | Securitization Bonds 2.64% Due December 2025      
Debt Instrument, Redemption [Line Items]      
Interest Rate 2.64%    
Amount $ 21    
DTE Gas | Mortgage Bonds | Mortgage Bonds 3.74% Due 2025      
Debt Instrument, Redemption [Line Items]      
Interest Rate 3.74%    
Amount $ 70    
v3.25.4
Long-Term Financings (Debt Maturities) (Details)
$ in Millions
Dec. 31, 2025
USD ($)
Maturities of Long-term Debt [Abstract]  
2026 $ 1,352
2027 1,730
2028 1,987
2029 1,962
2030 2,504
2031 and Thereafter 15,771
Total 25,306
DTE Electric  
Maturities of Long-term Debt [Abstract]  
2026 752
2027 339
2028 617
2029 103
2030 829
2031 and Thereafter 10,622
Total $ 13,262
v3.25.4
Long-Term Financings (Interest Payments Related to Long-term Debt) (Details)
$ in Millions
Dec. 31, 2025
USD ($)
Debt Instrument [Line Items]  
2026 $ 1,127
2027 1,039
2028 963
2029 879
2030 790
2031 and Thereafter 11,465
Total 16,263
DTE Electric  
Debt Instrument [Line Items]  
2026 557
2027 518
2028 504
2029 496
2030 484
2031 and Thereafter 5,637
Total $ 8,196
v3.25.4
Long-Term Financings (Details Textuals)
$ in Billions
 1 Months Ended
Dec. 31, 2025
USD ($)
At-the-Market Program  
Debt Instrument [Line Items]  
Authorized aggregate, amount $ 1.5
v3.25.4
Preferred and Preference Securities (Details)
Dec. 31, 2025
$ / shares
shares
DTE Electric  
Preferred and Preferenced Securities [Line Items]  
Preferred stock, par value (in dollars per share) | $ / shares $ 100
Preferred stock, shares authorized (in shares) | shares 6,747,484
Preference stock, par value (in dollars per share) | $ / shares $ 1
Preference stock shares authorized (in shares) | shares 30,000,000
DTE Gas  
Preferred and Preferenced Securities [Line Items]  
Preferred stock, par value (in dollars per share) | $ / shares $ 1
Preferred stock, shares authorized (in shares) | shares 7,000,000
Preference stock, par value (in dollars per share) | $ / shares $ 1
Preference stock shares authorized (in shares) | shares 4,000,000
DTE Energy  
Preferred and Preferenced Securities [Line Items]  
Preferred stock, par value (in dollars per share) | $ / shares $ 0
Preferred stock, shares authorized (in shares) | shares 5,000,000
v3.25.4
Short-Term Credit Arrangements and Borrowings (Details Textuals)
 1 Months Ended
Feb. 17, 2026
USD ($)
segment
Dec. 31, 2025
USD ($)
Dec. 31, 2024
USD ($)
Short-term Debt [Line Items]      
Maximum borrowing capacity   $ 3,850,000,000  
Weighted average interest rate   3.80% 4.70%
Dividend restriction   $ 2,100,000,000  
Retained earnings   5,484,000,000 $ 4,946,000,000
Effective limitations   0  
Subsequent Event      
Short-term Debt [Line Items]      
Number of debt instruments issued | segment 2    
DTE Gas      
Short-term Debt [Line Items]      
Maximum borrowing capacity   $ 300,000,000  
Total funded debt to capitalization ratio   0.49  
DTE Electric      
Short-term Debt [Line Items]      
Maximum borrowing capacity   $ 1,475,000,000  
Total funded debt to capitalization ratio   0.52  
Weighted average interest rate   3.80% 4.70%
Retained earnings   $ 3,465,000,000 $ 3,159,000,000
Maximum | DTE Gas      
Short-term Debt [Line Items]      
Total funded debt to capitalization ratio   0.65  
Maximum | DTE Electric      
Short-term Debt [Line Items]      
Total funded debt to capitalization ratio   0.65  
DTE Energy      
Short-term Debt [Line Items]      
Maximum borrowing capacity   $ 2,075,000,000  
Total funded debt to capitalization ratio   0.66  
DTE Energy | Maximum      
Short-term Debt [Line Items]      
Total funded debt to capitalization ratio   0.70  
DTE Energy | Letters of credit | DTE Energy Revolver      
Short-term Debt [Line Items]      
Maximum borrowing capacity   $ 500,000,000  
DTE Energy | Letters of credit | Unsecured Term Loan, Expiring August 2026 | Subsequent Event      
Short-term Debt [Line Items]      
Maximum borrowing capacity $ 550,000,000    
DTE Energy | Demand financing agreement      
Short-term Debt [Line Items]      
Maximum borrowing capacity   200,000,000  
Amount outstanding   $ 94,000,000 $ 49,000,000
v3.25.4
Short-Term Credit Arrangements and Borrowings (Availability Under Credit Facilities) (Details)
$ in Millions
Dec. 31, 2025
USD ($)
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity $ 3,850
Amounts outstanding at December 31, 2025 1,629
Net availability at December 31, 2025 2,221
DTE Electric  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 1,475
Amounts outstanding at December 31, 2025 983
Net availability at December 31, 2025 492
DTE Gas  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 300
Amounts outstanding at December 31, 2025 80
Net availability at December 31, 2025 220
DTE Energy  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 2,075
Amounts outstanding at December 31, 2025 566
Net availability at December 31, 2025 1,509
Revolving credit facility | Unsecured revolving credit facility, expiring October 2030  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 2,800
Revolving credit facility | Unsecured revolving credit facility, expiring October 2030 | DTE Electric  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 1,000
Revolving credit facility | Unsecured revolving credit facility, expiring October 2030 | DTE Gas  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 300
Revolving credit facility | Unsecured revolving credit facility, expiring October 2030 | DTE Energy  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 1,500
Letters of credit  
Line Of Credit Facility [Line Items]  
Amounts outstanding at December 31, 2025 747
Letters of credit | DTE Electric  
Line Of Credit Facility [Line Items]  
Amounts outstanding at December 31, 2025 331
Letters of credit | DTE Gas  
Line Of Credit Facility [Line Items]  
Amounts outstanding at December 31, 2025 0
Letters of credit | DTE Energy  
Line Of Credit Facility [Line Items]  
Amounts outstanding at December 31, 2025 416
Letters of credit | Unsecured letter of credit facility, expiring June 2026  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 150
Letters of credit | Unsecured letter of credit facility, expiring June 2026 | DTE Electric  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 0
Letters of credit | Unsecured letter of credit facility, expiring June 2026 | DTE Gas  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 0
Letters of credit | Unsecured letter of credit facility, expiring June 2026 | DTE Energy  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 150
Letters of credit | Unsecured letter of credit facility, expiring February 2027  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 200
Letters of credit | Unsecured letter of credit facility, expiring February 2027 | DTE Electric  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 0
Letters of credit | Unsecured letter of credit facility, expiring February 2027 | DTE Gas  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 0
Letters of credit | Unsecured letter of credit facility, expiring February 2027 | DTE Energy  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 200
Letters of credit | Unsecured letter of credit facilities, expiring June 2028  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 150
Letters of credit | Unsecured letter of credit facilities, expiring June 2028 | DTE Electric  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 0
Letters of credit | Unsecured letter of credit facilities, expiring June 2028 | DTE Gas  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 0
Letters of credit | Unsecured letter of credit facilities, expiring June 2028 | DTE Energy  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 150
Letters of credit | Unsecured letter of credit facility  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 75
Letters of credit | Unsecured letter of credit facility | DTE Electric  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 0
Letters of credit | Unsecured letter of credit facility | DTE Gas  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 0
Letters of credit | Unsecured letter of credit facility | DTE Energy  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 75
Letters of credit | Unsecured letter of credit facilities, expiring December 2026  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 150
Letters of credit | Unsecured letter of credit facilities, expiring December 2026 | DTE Electric  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 150
Letters of credit | Unsecured letter of credit facilities, expiring December 2026 | DTE Gas  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 0
Letters of credit | Unsecured letter of credit facilities, expiring December 2026 | DTE Energy  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 0
Letters of credit | Unsecured letter of credit facility  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 175
Letters of credit | Unsecured letter of credit facility | DTE Electric  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 175
Letters of credit | Unsecured letter of credit facility | DTE Gas  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 0
Letters of credit | Unsecured letter of credit facility | DTE Energy  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 0
Letters of credit | Unsecured letter of credit facility  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 150
Letters of credit | Unsecured letter of credit facility | DTE Electric  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 150
Letters of credit | Unsecured letter of credit facility | DTE Gas  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 0
Letters of credit | Unsecured letter of credit facility | DTE Energy  
Line Of Credit Facility [Line Items]  
Maximum borrowing capacity 0
Commercial paper issuances  
Line Of Credit Facility [Line Items]  
Amounts outstanding at December 31, 2025 882
Commercial paper issuances | DTE Electric  
Line Of Credit Facility [Line Items]  
Amounts outstanding at December 31, 2025 652
Commercial paper issuances | DTE Gas  
Line Of Credit Facility [Line Items]  
Amounts outstanding at December 31, 2025 80
Commercial paper issuances | DTE Energy  
Line Of Credit Facility [Line Items]  
Amounts outstanding at December 31, 2025 $ 150
v3.25.4
Leases (Details Textuals) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Lessee, Lease, Description [Line Items]      
Depreciation expense $ 8 $ 9 $ 8
Minimum      
Lessee, Lease, Description [Line Items]      
Lease terms (in years) 2 years    
Lessor, operating lease term (in years) 10 years    
Maximum      
Lessee, Lease, Description [Line Items]      
Lease terms (in years) 52 years    
Lessor, operating lease term (in years) 24 years    
DTE Electric | Minimum      
Lessee, Lease, Description [Line Items]      
Lease terms (in years) 2 years    
DTE Electric | Maximum      
Lessee, Lease, Description [Line Items]      
Lease terms (in years) 52 years    
v3.25.4
Leases (Components of Lease Cost) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Lessee, Lease, Description [Line Items]      
Operating lease cost $ 23 $ 26 $ 22
Finance lease cost:      
Amortization of right-of-use assets 4 4 7
Interest of lease liabilities 1 1 0
Total finance lease cost 5 5 7
Variable lease cost 17 17 13
Short-term lease cost 19 18 12
Total lease cost 64 66 54
DTE Electric      
Lessee, Lease, Description [Line Items]      
Operating lease cost 17 22 17
Finance lease cost:      
Amortization of right-of-use assets 3 3 6
Interest of lease liabilities 0 1 0
Total finance lease cost 3 4 6
Variable lease cost 1 0 0
Short-term lease cost 11 10 4
Total lease cost $ 32 $ 36 $ 27
v3.25.4
Leases (Other Information Related to Leases) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Cash paid for amounts included in the measurement of these liabilities:      
Operating cash flows for finance leases $ 5 $ 9 $ 9
Operating cash flows for operating leases 27 19 19
Right-of-use assets obtained in exchange for lease obligations:      
Operating leases 95 75 61
Finance leases $ 0 $ 16 $ 5
Weighted Average Remaining Lease Term (Years)      
Operating leases 24 years 6 months 23 years 3 months 18 days 18 years 8 months 12 days
Finance leases 6 years 7 months 6 days 7 years 4 months 24 days 8 years 10 months 24 days
Weighted Average Discount Rate      
Operating leases 5.10% 4.80% 4.40%
Finance leases 4.50% 4.60% 4.00%
DTE Electric      
Cash paid for amounts included in the measurement of these liabilities:      
Operating cash flows for finance leases $ 3 $ 7 $ 7
Operating cash flows for operating leases 21 15 15
Right-of-use assets obtained in exchange for lease obligations:      
Operating leases 86 74 61
Finance leases $ 0 $ 14 $ 5
Weighted Average Remaining Lease Term (Years)      
Operating leases 26 years 3 months 18 days 24 years 9 months 18 days 19 years 9 months 18 days
Finance leases 3 years 4 years 4 years 6 months
Weighted Average Discount Rate      
Operating leases 5.20% 4.90% 4.50%
Finance leases 5.80% 5.80% 5.40%
v3.25.4
Leases (Future Minimum Lease Payments) (Details)
$ in Millions
Dec. 31, 2025
USD ($)
Operating Leases  
2026 $ 37
2027 35
2028 32
2029 21
2030 13
2031 and thereafter 400
Total future minimum lease payments 538
Imputed interest (271)
Lease liabilities 267
Finance Leases  
2026 5
2027 4
2028 4
2029 1
2030 1
2031 and thereafter 5
Total future minimum lease payments 20
Imputed interest (2)
Lease liabilities 18
DTE Electric  
Operating Leases  
2026 31
2027 30
2028 28
2029 17
2030 10
2031 and thereafter 379
Total future minimum lease payments 495
Imputed interest (262)
Lease liabilities 233
Finance Leases  
2026 3
2027 3
2028 3
2029 0
2030 0
2031 and thereafter 0
Total future minimum lease payments 9
Imputed interest 0
Lease liabilities $ 9
v3.25.4
Leases (Finance Leases Reported on Consolidated Statements of Financial Position) (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Lessee, Lease, Description [Line Items]    
Right-of-use assets, within Property, plant, and equipment, net $ 18 $ 23
Current lease liabilities, within Current portion of long-term debt 4 5
Long-term lease liabilities $ 14 $ 18
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration] Long-Term Debt and Lease Obligation, Current Long-Term Debt and Lease Obligation, Current
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration] Property, Plant and Equipment, Net Property, Plant and Equipment, Net
DTE Electric    
Lessee, Lease, Description [Line Items]    
Right-of-use assets, within Property, plant, and equipment, net $ 9 $ 12
Current lease liabilities, within Current portion of long-term debt 3 4
Long-term lease liabilities $ 6 $ 8
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration] Long-Term Debt and Lease Obligation, Current Long-Term Debt and Lease Obligation, Current
v3.25.4
Leases (Lease Income Associated with Operating Leases) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Leases [Abstract]      
Fixed payments $ 15 $ 15 $ 15
Variable payments 46 45 44
Total lease income under operating leases $ 61 $ 60 $ 59
v3.25.4
Leases (Minimum Future Rental Revenues under Operating Leases) (Details)
$ in Millions
Dec. 31, 2025
USD ($)
Leases [Abstract]  
2026 $ 11
2027 10
2028 6
2029 6
2030 6
2031 and thereafter 23
Total minimum future rental revenues under operating leases $ 62
v3.25.4
Leases (Property under Operating Leases) (Details) - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Leases [Abstract]    
Gross property under operating leases $ 228 $ 227
Accumulated amortization of property under operating leases $ 126 $ 118
v3.25.4
Commitments and Contingencies (Details Textuals)
 3 Months Ended 12 Months Ended
Sep. 30, 2025
USD ($)
Dec. 31, 2025
USD ($)
employee
site
Dec. 31, 2022
USD ($)
Dec. 31, 2024
USD ($)
Loss Contingencies [Line Items]        
Asset retirement obligations   $ 4,469,000,000   $ 4,031,000,000
Capital expenditures estimated for next year   $ 6,800,000,000    
Workforce subject to collective bargaining arrangements | Labor force concentration risk        
Loss Contingencies [Line Items]        
Approximate number of employees | employee   4,850    
Percentage of total employees   50.00%    
Workforce subject to collective bargaining arrangements expiring within one year | Labor force concentration risk        
Loss Contingencies [Line Items]        
Percentage of total employees   16.00%    
Reduced emissions fuel guarantees        
Loss Contingencies [Line Items]        
Number of days after expiration of statutes of limitations (in days)   90 days    
Maximum potential liability   $ 201,000,000    
Other guarantees        
Loss Contingencies [Line Items]        
Maximum potential liability   69,000,000    
Performance surety bonds        
Loss Contingencies [Line Items]        
Performance bonds outstanding   383,000,000    
Performance surety bonds | Energy Trading segment        
Loss Contingencies [Line Items]        
Performance bonds outstanding   $ 91,000,000    
Performance surety bonds | Energy Trading segment | Minimum        
Loss Contingencies [Line Items]        
Performance bonds term (in years)   1 year    
Performance surety bonds | Energy Trading segment | Maximum        
Loss Contingencies [Line Items]        
Performance bonds term (in years)   3 years    
Penalties Related to EES Coke | Pending Litigation        
Loss Contingencies [Line Items]        
Loss contingency accrual   $ 8,000,000    
DTE Electric        
Loss Contingencies [Line Items]        
Environmental capital expenditures   2,400,000,000    
Estimated capital expenditures   $ 0    
Number of former MGP sites | site   3    
Accrued for remediation   $ 10,000,000   10,000,000
Asset retirement obligations   4,217,000,000   3,791,000,000
Capital expenditures estimated for next year   $ 5,200,000,000    
DTE Electric | Workforce subject to collective bargaining arrangements | Labor force concentration risk        
Loss Contingencies [Line Items]        
Approximate number of employees | employee   2,600    
Percentage of total employees   58.00%    
DTE Electric | Workforce subject to collective bargaining arrangements expiring within one year | Labor force concentration risk        
Loss Contingencies [Line Items]        
Percentage of total employees   22.00%    
DTE Electric | Performance surety bonds        
Loss Contingencies [Line Items]        
Performance bonds outstanding   $ 248,000,000    
DTE Electric | Ludington Plant Contract Dispute | Pending Litigation | Minimum        
Loss Contingencies [Line Items]        
Estimated impact of contingencies   350,000,000    
DTE Electric | Ludington Plant Contract Dispute | Pending Litigation | Maximum        
Loss Contingencies [Line Items]        
Estimated impact of contingencies   400,000,000    
DTE Electric | Legacy CCR Surface Impoundments And CCR Management Units        
Loss Contingencies [Line Items]        
Asset retirement obligations   430,000,000    
Asset retirement obligation, period increase $ 130,000,000      
DTE Electric | CCR and ELG Rules        
Loss Contingencies [Line Items]        
Estimated impact of contingencies   $ 424,000,000    
DTE Gas        
Loss Contingencies [Line Items]        
Number of former MGP sites | site   14    
Accrued for remediation   $ 25,000,000   $ 26,000,000
Amortization period (in years)   10 years    
DTE Gas | Cleanup completed and site closed        
Loss Contingencies [Line Items]        
Number of former MGP sites | site   8    
DTE Gas | Partial closure completed        
Loss Contingencies [Line Items]        
Number of former MGP sites | site   5    
Toshiba America Energy Systems and Toshiba Corporation | Ludington Plant Contract Dispute | Pending Litigation | DTE Electric and Consumers Energy Company        
Loss Contingencies [Line Items]        
Damages sought     $ 15,000,000  
v3.25.4
Commitments and Contingencies (Purchase Commitments) (Details)
$ in Millions
 12 Months Ended
Dec. 31, 2025
USD ($)
Entity Information [Line Items]  
2026 $ 3,622
2027 1,569
2028 680
2029 417
2030 400
2031 and thereafter 2,400
Total 9,088
Long-term power purchase agreements  
Entity Information [Line Items]  
2026 116
2027 128
2028 151
2029 151
2030 151
2031 and thereafter 1,699
Total 2,396
Other purchase commitments  
Entity Information [Line Items]  
2026 3,506
2027 1,441
2028 529
2029 266
2030 249
2031 and thereafter 701
Total 6,692
DTE Electric  
Entity Information [Line Items]  
2026 724
2027 544
2028 303
2029 187
2030 166
2031 and thereafter 1,821
Total 3,745
DTE Electric | Long-term power purchase agreements  
Entity Information [Line Items]  
2026 122
2027 133
2028 156
2029 153
2030 153
2031 and thereafter 1,704
Total 2,421
DTE Electric | Other purchase commitments  
Entity Information [Line Items]  
2026 602
2027 411
2028 147
2029 34
2030 13
2031 and thereafter 117
Total $ 1,324
DTE Electric | Minimum  
Entity Information [Line Items]  
Share of plant output 28.00%
DTE Electric | Maximum  
Entity Information [Line Items]  
Share of plant output 100.00%
v3.25.4
Nuclear Operations (Details) - DTE Electric
$ in Millions
 4 Months Ended 12 Months Ended
May 16, 2014
kWh
May 15, 2014
$ / MWh
Dec. 31, 2025
USD ($)
Entity Information [Line Items]      
Policy waiting period (in days)     84 days
Insurance coverage for extra expense when power plant unavailable     $ 490
Period of coverage of policy for extra expenses (in years)     3 years
Primary coverage for stabilization, decontamination, debris removal, repair and/or replacement of property, and decommissioning     $ 1,500
Excess coverage for stabilization, decontamination, debris removal, repair and/or replacement of property, and decommissioning     1,250
Combined coverage limit for total property damage     2,750
Total limit for property damage for non-nuclear events     1,800
Limit of coverage for aggregate extra expenses for non-nuclear events     $ 291
Period of coverage for extra expenses (in years)     2 years
Time period for TRIA after the first loss from terrorism (in years)     1 year
NEIL policies against terrorism loss, amount made available to all insured entities (up to)     $ 3,200
Maximum assessment if loss amount exceeds funds available     39
Public liability insurance for a nuclear incident     500
Maximum deferred premium charges that could be levied against each licensed nuclear facility     166
Limit of deferred premium charges per year per facility     $ 25
Company obligated to pay DOE fee of Fermi 2 electricity generated and sold (in dollars per MWh) | $ / MWh   1  
New DOE fee for Fermi 2 electricity generated and sold (KWh) | kWh 0    
v3.25.4
Retirement Benefits and Trusteed Assets (Net Pension Cost (Credit)) (Details) - Pension plan - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]      
Service cost $ 49 $ 58 $ 57
Interest cost 216 208 214
Expected return on plan assets (291) (341) (352)
Amortization of:      
Net actuarial loss 87 59 7
Prior service credit (1) (2) (2)
Settlements 0 0 7
Net pension/other postretirement cost (credit) $ 60 $ (18) $ (69)
v3.25.4
Retirement Benefits and Trusteed Assets (Other Changes in Plan Assets and Benefit Obligations) (Details) - Pension plan - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Other changes in plan assets and benefit obligations recognized in Regulatory assets and Other comprehensive income (loss)    
Net actuarial (gain) loss $ 58 $ (49)
Amortization of net actuarial loss and settlements (87) (59)
Amortization of prior service credit 1 2
Total recognized in Regulatory assets and liabilities and Other comprehensive income (loss) (28) (106)
Total recognized in net periodic pension credit, Regulatory assets, and Other comprehensive income (loss) $ 32 $ (124)
v3.25.4
Retirement Benefits and Trusteed Assets (Reconciliation of Obligations, Assets and Funded Status of Plans) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Amounts recognized in Regulatory assets      
Regulatory assets $ 7,550 $ 6,821  
Pension plan      
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]      
Accumulated benefit obligation, end of year 3,851 3,803  
Change in projected benefit obligation      
Projected/Accumulated postretirement benefit obligation, beginning of year 3,982 4,318  
Service cost 49 58 $ 57
Interest cost 216 208 214
Actuarial (gain) loss 111 (254)  
Benefits paid (315) (348)  
Projected/Accumulated postretirement benefit obligation, end of year 4,043 3,982 4,318
Change in plan assets      
Plan assets at fair value, beginning of year 3,758 3,960  
Actual return on plan assets 343 137  
Company contributions 9 9  
Benefits paid (315) (348)  
Plan assets at fair value, end of year 3,795 3,758 $ 3,960
Funded status (248) (224)  
Amount recorded as:      
Current liabilities (13) (10)  
Noncurrent liabilities (235) (214)  
Defined benefit plans liabilities (248) (224)  
Amounts recognized in Accumulated other comprehensive income, pre-tax      
Net actuarial loss 82 76  
Amounts recognized in Accumulated other comprehensive income, pre-tax 82 76  
Amounts recognized in Regulatory assets      
Net actuarial loss 1,283 1,318  
Prior service credit (2) (3)  
Regulatory assets $ 1,281 $ 1,315  
v3.25.4
Retirement Benefits and Trusteed Assets (Details Textuals) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2026
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]        
Annual contributions per employee, percentage   4.00%    
Defined contribution plan cost   $ 80 $ 76 $ 75
DTE Electric        
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]        
Defined contribution plan cost   $ 37 35 35
DTE Gas        
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]        
Annual contributions per employee, percentage   8.00%    
Pension plan        
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]        
Company contributions   $ 9 9  
Pension credit   $ (60) 18 69
Expected return on plan assets for next fiscal year   7.80%    
Pension plan | Qualified Plan        
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]        
Company contributions   $ 0 0  
Pension plan | DTE Electric        
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]        
Pension funds transferred to (from) plan   25   50
Pension credit   (53) 5 39
Pension plan | DTE Electric | Forecast        
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]        
Pension funds transferred to (from) plan $ 25      
Pension plan | DTE Gas        
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]        
Pension funds transferred to (from) plan       (50)
Pension plan | DTE Gas | Forecast        
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]        
Pension funds transferred to (from) plan $ (25)      
Other postretirement benefit plan        
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]        
Pension credit   $ 39 44 38
Expected return on plan assets for next fiscal year   7.40%    
Retiree health care allowance will increase at lower of the rate of medical inflation or a set percentage   2.00%    
Other postretirement benefit plan | DTE Electric        
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]        
Pension credit   $ 22 $ 23 $ 24
v3.25.4
Retirement Benefits and Trusteed Assets (Benefits Related to Qualified and Non-Qualified Pension Plans Expected to be Paid) (Details) - Pension plan
$ in Millions
Dec. 31, 2025
USD ($)
Defined Benefit Plan, Expected Future Benefit Payment [Abstract]  
2026 $ 326
2027 326
2028 330
2029 326
2030 321
2031-2035 1,599
Total $ 3,228
v3.25.4
Retirement Benefits and Trusteed Assets (Assumptions used in Determining the PBO and Net Pension Costs) (Details) - Pension plan
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Projected benefit obligation      
Discount rate 5.43% 5.65% 5.00%
Rate of compensation increase 3.55% 3.55% 3.80%
Cash balance interest crediting rate 3.60% 4.50% 3.60%
Net pension costs      
Discount rate 5.65% 5.00% 5.19%
Rate of compensation increase 3.55% 3.80% 3.80%
Expected long-term rate of return on plan assets 7.80% 8.00% 7.60%
Cash balance interest crediting rate 4.50% 3.60% 3.40%
v3.25.4
Retirement Benefits and Trusteed Assets (Target Allocations of Pension Plan Assets) (Details) - Pension plan
Dec. 31, 2025
Defined Benefit Plan Disclosure [Line Items]  
Target allocation percentage of assets 100.00%
U.S. Large Capitalization (Cap) Equity Securities  
Defined Benefit Plan Disclosure [Line Items]  
Target allocation percentage of assets 8.00%
U.S. Small Cap and Mid Cap Equity Securities  
Defined Benefit Plan Disclosure [Line Items]  
Target allocation percentage of assets 1.00%
Non-U.S. Equity Securities  
Defined Benefit Plan Disclosure [Line Items]  
Target allocation percentage of assets 6.00%
Fixed Income Securities  
Defined Benefit Plan Disclosure [Line Items]  
Target allocation percentage of assets 57.00%
Hedge Funds and Similar Investments  
Defined Benefit Plan Disclosure [Line Items]  
Target allocation percentage of assets 8.00%
Private Equity and Other  
Defined Benefit Plan Disclosure [Line Items]  
Target allocation percentage of assets 20.00%
v3.25.4
Retirement Benefits and Trusteed Assets (Fair Value Measurement Amounts for Pension Plan Assets) (Details) - Pension Plan - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total $ 3,795 $ 3,758 $ 3,960
Short-term Investments      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 83 97  
Equity Securities, Domestic      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 343 349  
Equity Securities, International      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 243 223  
Fixed Income Securities, Governmental      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 618 703  
Fixed Income Securities, Corporate      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 1,504 1,350  
Hedge Funds and Similar Investments      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 324 318  
Private Equity and Other      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 680 718  
Level 1      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 792 896  
Level 1 | Short-term Investments      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 83 97  
Level 1 | Equity Securities, Domestic      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 0 0  
Level 1 | Equity Securities, International      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 34 35  
Level 1 | Fixed Income Securities, Governmental      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 537 627  
Level 1 | Fixed Income Securities, Corporate      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 0 0  
Level 1 | Hedge Funds and Similar Investments      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 138 137  
Level 1 | Private Equity and Other      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 0 0  
Level 2      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 1,599 1,440  
Level 2 | Short-term Investments      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 0 0  
Level 2 | Equity Securities, Domestic      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 0 0  
Level 2 | Equity Securities, International      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 0 0  
Level 2 | Fixed Income Securities, Governmental      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 81 76  
Level 2 | Fixed Income Securities, Corporate      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 1,504 1,350  
Level 2 | Hedge Funds and Similar Investments      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 14 14  
Level 2 | Private Equity and Other      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 0 0  
Other      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 1,404 1,422  
Other | Short-term Investments      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 0 0  
Other | Equity Securities, Domestic      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 343 349  
Other | Equity Securities, International      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 209 188  
Other | Fixed Income Securities, Governmental      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 0 0  
Other | Fixed Income Securities, Corporate      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 0 0  
Other | Hedge Funds and Similar Investments      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total 172 167  
Other | Private Equity and Other      
Defined Benefit Plan Disclosure [Line Items]      
DTE Energy Total $ 680 $ 718  
v3.25.4
Retirement Benefits and Trusteed Assets (Contributions to the VEBA) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Defined Contribution Plan Disclosure [Line Items]      
Contributions $ 80 $ 76 $ 75
DTE Electric      
Defined Contribution Plan Disclosure [Line Items]      
Contributions 37 35 35
Retiree healthcare plan (VEBA)      
Defined Contribution Plan Disclosure [Line Items]      
Contributions 15 15 16
Retiree healthcare plan (VEBA) | DTE Electric      
Defined Contribution Plan Disclosure [Line Items]      
Contributions $ 7 $ 6 $ 7
v3.25.4
Retirement Benefits and Trusteed Assets (Net Other Postretirement Credit) (Details) - Other postretirement benefit plan - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Defined Benefit Plan Disclosure [Line Items]      
Service cost $ 15 $ 18 $ 17
Interest cost 61 62 65
Expected return on plan assets (117) (120) (111)
Amortization of:      
Net actuarial loss 2 6 10
Prior service credit 0 (10) (19)
Net pension/other postretirement cost (credit) (39) (44) (38)
DTE Electric      
Defined Benefit Plan Disclosure [Line Items]      
Service cost 11 14 13
Interest cost 46 47 49
Expected return on plan assets (77) (79) (73)
Amortization of:      
Net actuarial loss (2) 1 1
Prior service credit 0 (6) (14)
Net pension/other postretirement cost (credit) $ (22) $ (23) $ (24)
v3.25.4
Retirement Benefits and Trusteed Assets (Other Changes in Plan Assets and Accumulated Postretirement Benefit Obligation) (Details) - Other postretirement benefit plan - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Other changes in plan assets and accumulated postretirement benefit obligation recognized in Regulatory assets and liabilities and Other comprehensive income (loss)    
Net actuarial (gain) loss $ 2 $ (103)
Amortization of net actuarial loss (2) (6)
Amortization of prior service credit 0 10
Total recognized in Regulatory assets and liabilities and Other comprehensive income (loss) 0 (99)
Total recognized in net periodic pension credit, Regulatory assets, and Other comprehensive income (loss) (39) (143)
DTE Electric    
Other changes in plan assets and accumulated postretirement benefit obligation recognized in Regulatory assets and liabilities and Other comprehensive income (loss)    
Net actuarial (gain) loss (1) (98)
Amortization of net actuarial loss 2 (1)
Amortization of prior service credit 0 6
Total recognized in Regulatory assets and liabilities and Other comprehensive income (loss) 1 (93)
Total recognized in net periodic pension credit, Regulatory assets, and Other comprehensive income (loss) $ (21) $ (116)
v3.25.4
Retirement Benefits and Trusteed Assets (Reconciliation of Obligations, Assets and Funded Status of Postretirement Plans) (Details) - Other postretirement benefit plan - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Change in accumulated postretirement benefit obligation      
Projected/Accumulated postretirement benefit obligation, beginning of year $ 1,123 $ 1,283  
Service cost 15 18 $ 17
Interest cost 61 62 65
Actuarial (gain) loss 24 (165)  
Benefits paid (82) (75)  
Projected/Accumulated postretirement benefit obligation, end of year 1,141 1,123 1,283
Change in plan assets      
Plan assets at fair value, beginning of year 1,594 1,614  
Actual return on plan assets 139 58  
Benefits paid (79) (78)  
Plan assets at fair value, end of year 1,654 1,594 1,614
Funded status 513 471  
Amount recorded as:      
Noncurrent assets 761 705  
Current liabilities (1) (1)  
Noncurrent liabilities (247) (233)  
Defined benefit plans assets (liabilities) 513 471  
Amounts recognized in Accumulated other comprehensive income, pre-tax      
Net actuarial gain (13) (14)  
Amounts recognized in Regulatory assets and liabilities      
Net actuarial (gain) loss 64 65  
DTE Electric      
Change in accumulated postretirement benefit obligation      
Projected/Accumulated postretirement benefit obligation, beginning of year 849 982  
Service cost 11 14 13
Interest cost 46 47 49
Actuarial (gain) loss 15 (139)  
Benefits paid (60) (55)  
Projected/Accumulated postretirement benefit obligation, end of year 861 849 982
Change in plan assets      
Plan assets at fair value, beginning of year 1,052 1,070  
Actual return on plan assets 92 40  
Benefits paid (57) (58)  
Plan assets at fair value, end of year 1,087 1,052 $ 1,070
Funded status 226 203  
Amount recorded as:      
Noncurrent assets 463 428  
Current liabilities 0 0  
Noncurrent liabilities (237) (225)  
Defined benefit plans assets (liabilities) 226 203  
Amounts recognized in Accumulated other comprehensive income, pre-tax      
Net actuarial gain 0 0  
Amounts recognized in Regulatory assets and liabilities      
Net actuarial (gain) loss $ (25) $ (26)  
v3.25.4
Retirement Benefits and Trusteed Assets (Accumulated Postretirement Benefit Obligations in Excess of Plan Assets) (Details) - Other postretirement benefit plan - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Defined Benefit Plan Disclosure [Line Items]    
Accumulated postretirement benefit obligation $ 541 $ 530
Fair value of plan assets 293 296
Accumulated postretirement benefit obligation in excess of plan assets 248 234
DTE Electric    
Defined Benefit Plan Disclosure [Line Items]    
Accumulated postretirement benefit obligation 510 501
Fair value of plan assets 273 276
Accumulated postretirement benefit obligation in excess of plan assets $ 237 $ 225
v3.25.4
Retirement Benefits and Trusteed Assets (Benefits Expected To Be Paid) (Details) - Other postretirement benefit plan
$ in Millions
Dec. 31, 2025
USD ($)
Defined Benefit Plan Disclosure [Line Items]  
2026 $ 80
2027 83
2028 85
2029 87
2030 89
2031-2035 456
Total 880
DTE Electric  
Defined Benefit Plan Disclosure [Line Items]  
2026 60
2027 62
2028 64
2029 65
2030 67
2031-2035 347
Total $ 665
v3.25.4
Retirement Benefits and Trusteed Assets (Assumptions Used in Determining the Accumulated Postretirement Benefit Obligation and Net Other Postretirement Benefit Costs) (Details) - Other postretirement benefit plan
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Accumulated postretirement benefit obligation      
Discount rate 5.43% 5.66% 5.00%
Health care trend rate pre- 65 8.25% 8.50% 7.75%
Health care trend post- 65 8.75% 9.00% 8.25%
Ultimate health care trend rate 4.50% 4.50% 4.50%
Other postretirement benefit costs      
Discount rate 5.66% 5.00% 5.19%
Expected long-term rate of return on plan assets 7.50% 7.60% 7.20%
Health care trend rate pre- 65 8.50% 7.75% 6.75%
Health care trend post- 65 9.00% 8.25% 7.25%
Ultimate health care trend rate 4.50% 4.50% 4.50%
v3.25.4
Retirement Benefits and Trusteed Assets (Target Allocations for Other Postretirement Benefit Plan Assets) (Details) - Other postretirement benefit plan
Dec. 31, 2025
Defined Benefit Plan Disclosure [Line Items]  
Target allocation percentage of assets 100.00%
U.S. Large Cap Equity Securities  
Defined Benefit Plan Disclosure [Line Items]  
Target allocation percentage of assets 4.00%
Non-U.S. Equity Securities  
Defined Benefit Plan Disclosure [Line Items]  
Target allocation percentage of assets 3.00%
Fixed Income Securities  
Defined Benefit Plan Disclosure [Line Items]  
Target allocation percentage of assets 62.00%
Hedge Funds and Similar Investments  
Defined Benefit Plan Disclosure [Line Items]  
Target allocation percentage of assets 9.00%
Private Equity and Other  
Defined Benefit Plan Disclosure [Line Items]  
Target allocation percentage of assets 22.00%
v3.25.4
Retirement Benefits and Trusteed Assets (Fair Value Measurement Amounts for Other Postretirement Benefit Plan Assets) (Details) - Other postretirement benefit plan - USD ($)
$ in Millions
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Defined Benefit Plan Disclosure [Line Items]      
Total $ 1,654 $ 1,594 $ 1,614
Level 1      
Defined Benefit Plan Disclosure [Line Items]      
Total 247 276  
Level 2      
Defined Benefit Plan Disclosure [Line Items]      
Total 589 529  
Other      
Defined Benefit Plan Disclosure [Line Items]      
Total 818 789  
Short-term Investments      
Defined Benefit Plan Disclosure [Line Items]      
Total 37 33  
Short-term Investments | Level 1      
Defined Benefit Plan Disclosure [Line Items]      
Total 37 33  
Short-term Investments | Level 2      
Defined Benefit Plan Disclosure [Line Items]      
Total 0 0  
Short-term Investments | Other      
Defined Benefit Plan Disclosure [Line Items]      
Total 0 0  
Equity Securities, Domestic      
Defined Benefit Plan Disclosure [Line Items]      
Total 61 67  
Equity Securities, Domestic | Level 1      
Defined Benefit Plan Disclosure [Line Items]      
Total 0 0  
Equity Securities, Domestic | Level 2      
Defined Benefit Plan Disclosure [Line Items]      
Total 0 0  
Equity Securities, Domestic | Other      
Defined Benefit Plan Disclosure [Line Items]      
Total 61 67  
Equity Securities, International      
Defined Benefit Plan Disclosure [Line Items]      
Total 49 40  
Equity Securities, International | Level 1      
Defined Benefit Plan Disclosure [Line Items]      
Total 7 6  
Equity Securities, International | Level 2      
Defined Benefit Plan Disclosure [Line Items]      
Total 0 0  
Equity Securities, International | Other      
Defined Benefit Plan Disclosure [Line Items]      
Total 42 34  
Fixed Income Securities, Governmental      
Defined Benefit Plan Disclosure [Line Items]      
Total 206 244  
Fixed Income Securities, Governmental | Level 1      
Defined Benefit Plan Disclosure [Line Items]      
Total 169 210  
Fixed Income Securities, Governmental | Level 2      
Defined Benefit Plan Disclosure [Line Items]      
Total 37 34  
Fixed Income Securities, Governmental | Other      
Defined Benefit Plan Disclosure [Line Items]      
Total 0 0  
Fixed Income Securities, Corporate      
Defined Benefit Plan Disclosure [Line Items]      
Total 771 700  
Fixed Income Securities, Corporate | Level 1      
Defined Benefit Plan Disclosure [Line Items]      
Total 0 0  
Fixed Income Securities, Corporate | Level 2      
Defined Benefit Plan Disclosure [Line Items]      
Total 549 492  
Fixed Income Securities, Corporate | Other      
Defined Benefit Plan Disclosure [Line Items]      
Total 222 208  
Hedge Funds and Similar Investments      
Defined Benefit Plan Disclosure [Line Items]      
Total 142 133  
Hedge Funds and Similar Investments | Level 1      
Defined Benefit Plan Disclosure [Line Items]      
Total 34 27  
Hedge Funds and Similar Investments | Level 2      
Defined Benefit Plan Disclosure [Line Items]      
Total 3 3  
Hedge Funds and Similar Investments | Other      
Defined Benefit Plan Disclosure [Line Items]      
Total 105 103  
Private Equity and Other      
Defined Benefit Plan Disclosure [Line Items]      
Total 388 377  
Private Equity and Other | Level 1      
Defined Benefit Plan Disclosure [Line Items]      
Total 0 0  
Private Equity and Other | Level 2      
Defined Benefit Plan Disclosure [Line Items]      
Total 0 0  
Private Equity and Other | Other      
Defined Benefit Plan Disclosure [Line Items]      
Total 388 377  
DTE Electric      
Defined Benefit Plan Disclosure [Line Items]      
Total 1,087 1,052 $ 1,070
DTE Electric | Level 1      
Defined Benefit Plan Disclosure [Line Items]      
Total 159 180  
DTE Electric | Level 2      
Defined Benefit Plan Disclosure [Line Items]      
Total 385 348  
DTE Electric | Other      
Defined Benefit Plan Disclosure [Line Items]      
Total 543 524  
DTE Electric | Short-term Investments      
Defined Benefit Plan Disclosure [Line Items]      
Total 24 21  
DTE Electric | Short-term Investments | Level 1      
Defined Benefit Plan Disclosure [Line Items]      
Total 24 21  
DTE Electric | Short-term Investments | Level 2      
Defined Benefit Plan Disclosure [Line Items]      
Total 0 0  
DTE Electric | Short-term Investments | Other      
Defined Benefit Plan Disclosure [Line Items]      
Total 0 0  
DTE Electric | Equity Securities, Domestic      
Defined Benefit Plan Disclosure [Line Items]      
Total 38 42  
DTE Electric | Equity Securities, Domestic | Level 1      
Defined Benefit Plan Disclosure [Line Items]      
Total 0 0  
DTE Electric | Equity Securities, Domestic | Level 2      
Defined Benefit Plan Disclosure [Line Items]      
Total 0 0  
DTE Electric | Equity Securities, Domestic | Other      
Defined Benefit Plan Disclosure [Line Items]      
Total 38 42  
DTE Electric | Equity Securities, International      
Defined Benefit Plan Disclosure [Line Items]      
Total 31 26  
DTE Electric | Equity Securities, International | Level 1      
Defined Benefit Plan Disclosure [Line Items]      
Total 4 4  
DTE Electric | Equity Securities, International | Level 2      
Defined Benefit Plan Disclosure [Line Items]      
Total 0 0  
DTE Electric | Equity Securities, International | Other      
Defined Benefit Plan Disclosure [Line Items]      
Total 27 22  
DTE Electric | Fixed Income Securities, Governmental      
Defined Benefit Plan Disclosure [Line Items]      
Total 134 160  
DTE Electric | Fixed Income Securities, Governmental | Level 1      
Defined Benefit Plan Disclosure [Line Items]      
Total 110 138  
DTE Electric | Fixed Income Securities, Governmental | Level 2      
Defined Benefit Plan Disclosure [Line Items]      
Total 24 22  
DTE Electric | Fixed Income Securities, Governmental | Other      
Defined Benefit Plan Disclosure [Line Items]      
Total 0 0  
DTE Electric | Fixed Income Securities, Corporate      
Defined Benefit Plan Disclosure [Line Items]      
Total 510 465  
DTE Electric | Fixed Income Securities, Corporate | Level 1      
Defined Benefit Plan Disclosure [Line Items]      
Total 0 0  
DTE Electric | Fixed Income Securities, Corporate | Level 2      
Defined Benefit Plan Disclosure [Line Items]      
Total 359 324  
DTE Electric | Fixed Income Securities, Corporate | Other      
Defined Benefit Plan Disclosure [Line Items]      
Total 151 141  
DTE Electric | Hedge Funds and Similar Investments      
Defined Benefit Plan Disclosure [Line Items]      
Total 93 88  
DTE Electric | Hedge Funds and Similar Investments | Level 1      
Defined Benefit Plan Disclosure [Line Items]      
Total 21 17  
DTE Electric | Hedge Funds and Similar Investments | Level 2      
Defined Benefit Plan Disclosure [Line Items]      
Total 2 2  
DTE Electric | Hedge Funds and Similar Investments | Other      
Defined Benefit Plan Disclosure [Line Items]      
Total 70 69  
DTE Electric | Private Equity and Other      
Defined Benefit Plan Disclosure [Line Items]      
Total 257 250  
DTE Electric | Private Equity and Other | Level 1      
Defined Benefit Plan Disclosure [Line Items]      
Total 0 0  
DTE Electric | Private Equity and Other | Level 2      
Defined Benefit Plan Disclosure [Line Items]      
Total 0 0  
DTE Electric | Private Equity and Other | Other      
Defined Benefit Plan Disclosure [Line Items]      
Total $ 257 $ 250  
v3.25.4
Stock-Based Compensation (Details Textuals) - 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]      
Authorized limit of common stock shares (in shares) 4,663,434    
DTE Electric | DTE Energy      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Compensation cost charged against income $ 41 $ 37 $ 31
Restricted Stock Awards      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Award vesting period (in years) 3 years    
Compensation cost charged against income $ 17 $ 14 $ 14
Performance Share Awards      
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]      
Award vesting period (in years) 3 years    
v3.25.4
Stock-Based Compensation (Components of Stock-Based Compensation) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Components of stock based-compensation [Abstract]      
Stock-based compensation expense $ 60 $ 54 $ 48
Tax benefit $ 10 $ 10 $ 9
v3.25.4
Stock-Based Compensation (Activity Relating to Performance Stock Units) (Details) - USD ($)
$ / shares in Units, $ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Compensation Expense Recorded [Line Items]      
Compensation expense $ 60 $ 54 $ 48
Performance Share Awards      
Compensation Expense Recorded [Line Items]      
Weighted grant date fair value of awards granted (in dollars per share) $ 123.02 $ 106.04 $ 112.73
Awards settled in cash $ 0 $ 0 $ 9
Awards settled in stock 39 63 59
Compensation expense $ 43 $ 40 $ 34
v3.25.4
Stock-Based Compensation (Performance Stock Unit Activity) (Details) - Performance stock units - $ / shares
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Performance Stock Units      
Balance at beginning of period (in shares) 976,843    
Grants (in shares) 391,290    
Forfeitures (in shares) (58,011)    
Payouts (in shares) (301,030)    
Balance at end of period (in shares) 1,009,092 976,843  
Weighted Average Grant Date Fair Value      
Balance at beginning of period (in dollars per share) $ 122.25    
Grants (in dollars per share) 123.02 $ 106.04 $ 112.73
Forfeitures (in dollars per share) 118.07    
Payouts (in dollars per share) 120.34    
Balance at end of period (in dollars per share) $ 123.36 $ 122.25  
v3.25.4
Stock-Based Compensation (Unrecognized Compensation Costs) (Details)
$ in Millions
 12 Months Ended
Dec. 31, 2025
USD ($)
Share Based Compensation Unrecognized and Non-Vested Cost [Line Items]  
Unrecognized Compensation Cost $ 67
Weighted Average to be Recognized 1 year 9 months 10 days
Stock awards  
Share Based Compensation Unrecognized and Non-Vested Cost [Line Items]  
Unrecognized Compensation Cost $ 23
Weighted Average to be Recognized 1 year 11 months 19 days
Performance stock units  
Share Based Compensation Unrecognized and Non-Vested Cost [Line Items]  
Unrecognized Compensation Cost $ 44
Weighted Average to be Recognized 1 year 8 months 4 days
v3.25.4
Segment and Related Information (Details Textuals)
customer in Millions
 12 Months Ended
Dec. 31, 2025
customer
segment
Segment Reporting Information [Line Items]  
Number of reportable segments | segment 4
Number of electric utility customers | customer 2.3
Number of gas utility customers | customer 1.4
DTE Electric  
Segment Reporting Information [Line Items]  
Number of reportable segments | segment 1
v3.25.4
Segment and Related Information (Inter-segment Billing for Goods and Services) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Segment Reporting Information [Line Items]      
Operating revenues $ (15,814) $ (12,457) $ (12,745)
Inter-segment billing relating to Non-utility operations (6,965) (4,467) (5,279)
Reclassifications and Eliminations      
Segment Reporting Information [Line Items]      
Operating revenues 346 230 242
Inter-segment billing relating to Non-utility operations 258 145 156
Reclassifications and Eliminations | Electric segment      
Segment Reporting Information [Line Items]      
Operating revenues 71 71 72
Inter-segment billing relating to Non-utility operations 4 3 3
Reclassifications and Eliminations | Gas segment      
Segment Reporting Information [Line Items]      
Operating revenues 22 16 17
Reclassifications and Eliminations | DTE Vantage segment      
Segment Reporting Information [Line Items]      
Operating revenues 77 43 68
Reclassifications and Eliminations | Energy Trading segment      
Segment Reporting Information [Line Items]      
Operating revenues $ 176 $ 100 $ 85
v3.25.4
Segment and Related Information (Financial Data of Business Segments) (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Segment Reporting Information [Line Items]      
Operating Revenues — Utility operations $ 8,849 $ 7,990 $ 7,466
Operating Revenues — Non-utility operations 6,965 4,467 5,279
Depreciation and amortization 1,841 1,732 1,606
Interest expense 1,056 951 791
Interest income (103) (136) (57)
Equity earnings of equity method investees 47 15 3
Other segment items (pre-tax) 11,423 8,525 8,836
Income Tax Expense (Benefit) 88 (34) 169
Net Income (Loss) Attributable to DTE Energy Company 1,462 1,404 1,397
Other Segment Financial Data      
Investments in equity method investees 122 128 166
Capital expenditures and acquisitions 4,639 4,467 3,934
Goodwill 1,993 1,993 1,993
Total Assets 54,066 48,846 44,755
Operating Segments      
Segment Reporting Information [Line Items]      
Operating Revenues — Utility operations 8,937 8,075 7,552
Operating Revenues — Non-utility operations 7,223 4,612 5,435
Depreciation and amortization 1,841 1,732 1,606
Interest expense 727 658 567
Interest income (114) (108) (70)
Equity earnings of equity method investees 20 16 8
Other segment items (pre-tax) 11,815 8,749 9,060
Income Tax Expense (Benefit) 141 51 261
Net Income (Loss) Attributable to DTE Energy Company 1,730 1,589 1,555
Other Segment Financial Data      
Investments in equity method investees 100 105 139
Capital expenditures and acquisitions 4,639 4,467 3,934
Goodwill 1,993 1,993 1,993
Total Assets 52,096 47,098 42,302
Operating Segments | Electric      
Segment Reporting Information [Line Items]      
Operating Revenues — Utility operations 6,885 6,277 5,804
Operating Revenues — Non-utility operations 50 16 14
Depreciation and amortization 1,553 1,447 1,340
Interest expense 555 498 432
Interest income (9) (7) (20)
Equity earnings of equity method investees 0 0 0
Other segment items (pre-tax) 3,605 3,314 3,216
Income Tax Expense (Benefit) 73 (31) 78
Net Income (Loss) Attributable to DTE Energy Company 1,158 1,072 772
Other Segment Financial Data      
Investments in equity method investees 4 5 5
Capital expenditures and acquisitions 3,892 3,659 3,128
Goodwill 1,208 1,208 1,208
Total Assets 39,370 35,400 32,292
Operating Segments | Gas segment      
Segment Reporting Information [Line Items]      
Operating Revenues — Utility operations 2,052 1,798 1,748
Operating Revenues — Non-utility operations 0 0 0
Depreciation and amortization 225 221 209
Interest expense 132 118 102
Interest income (11) (10) (9)
Equity earnings of equity method investees 1 1 1
Other segment items (pre-tax) 1,322 1,134 1,058
Income Tax Expense (Benefit) 88 77 93
Net Income (Loss) Attributable to DTE Energy Company 295 257 294
Other Segment Financial Data      
Investments in equity method investees 19 18 16
Capital expenditures and acquisitions 661 740 746
Goodwill 743 743 743
Total Assets 8,987 8,474 7,722
Operating Segments | DTE Vantage      
Segment Reporting Information [Line Items]      
Operating Revenues — Utility operations 0 0 0
Operating Revenues — Non-utility operations 696 753 809
Depreciation and amortization 59 59 53
Interest expense 30 28 15
Interest income (87) (76) (32)
Equity earnings of equity method investees 19 15 7
Other segment items (pre-tax) 582 629 635
Income Tax Expense (Benefit) (61) (37) (22)
Net Income (Loss) Attributable to DTE Energy Company 154 135 153
Other Segment Financial Data      
Investments in equity method investees 77 82 118
Capital expenditures and acquisitions 80 65 57
Goodwill 25 25 25
Total Assets 2,426 2,065 1,122
Operating Segments | Energy Trading segment      
Segment Reporting Information [Line Items]      
Operating Revenues — Utility operations 0 0 0
Operating Revenues — Non-utility operations 6,477 3,843 4,612
Depreciation and amortization 4 5 4
Interest expense 10 14 18
Interest income (7) (15) (9)
Equity earnings of equity method investees 0 0 0
Other segment items (pre-tax) 6,306 3,672 4,151
Income Tax Expense (Benefit) 41 42 112
Net Income (Loss) Attributable to DTE Energy Company 123 125 336
Other Segment Financial Data      
Investments in equity method investees 0 0 0
Capital expenditures and acquisitions 6 3 3
Goodwill 17 17 17
Total Assets 1,313 1,159 1,166
Corporate and Other      
Segment Reporting Information [Line Items]      
Operating Revenues — Utility operations 0 0 0
Operating Revenues — Non-utility operations 0 0 0
Depreciation and amortization 0 0 0
Interest expense 409 351 270
Interest income (69) (86) (33)
Equity earnings of equity method investees 27 (1) (5)
Other segment items (pre-tax) (46) 6 18
Income Tax Expense (Benefit) (53) (85) (92)
Net Income (Loss) Attributable to DTE Energy Company (268) (185) (158)
Other Segment Financial Data      
Investments in equity method investees 22 23 27
Capital expenditures and acquisitions 0 0 0
Goodwill 0 0 0
Total Assets 5,145 4,723 4,150
Reclassifications and Eliminations      
Segment Reporting Information [Line Items]      
Operating Revenues — Utility operations (88) (85) (86)
Operating Revenues — Non-utility operations (258) (145) (156)
Depreciation and amortization 0 0 0
Interest expense (80) (58) (46)
Interest income 80 58 46
Equity earnings of equity method investees 0 0 0
Other segment items (pre-tax) (346) (230) (242)
Income Tax Expense (Benefit) 0 0 0
Net Income (Loss) Attributable to DTE Energy Company 0 0 0
Other Segment Financial Data      
Investments in equity method investees 0 0 0
Capital expenditures and acquisitions 0 0 0
Goodwill 0 0 0
Total Assets (3,175) (2,975) (1,697)
Reclassifications and Eliminations | Electric      
Segment Reporting Information [Line Items]      
Operating Revenues — Non-utility operations $ (4) $ (3) $ (3)
v3.25.4
Related Party Transactions (Details) - USD ($)
$ in Millions
 12 Months Ended
Dec. 31, 2025
Dec. 31, 2024
Dec. 31, 2023
Related Party Transaction [Line Items]      
Dividends declared $ 921 $ 859 $ 800
Dividends paid 871 810 752
DTE Electric      
Related Party Transaction [Line Items]      
Dividends declared 846 776 1,002
Dividends paid 846 776 1,002
DTE Electric | DTE Energy      
Related Party Transaction [Line Items]      
Dividends declared 846 776 1,002
Dividends paid 846 776 1,002
Capital contribution from DTE Energy $ 954 $ 634 759
DTE Electric | Affiliates      
Related Party Transaction [Line Items]      
Weighted average interest rate 3.90% 4.70%  
DTE Electric | Energy sales      
Related Party Transaction [Line Items]      
Revenues and Other Income/ Costs $ 12 $ 11 11
DTE Electric | Other services and interest      
Related Party Transaction [Line Items]      
Revenues and Other Income/ Costs 0 0 3
DTE Electric | Shared capital assets      
Related Party Transaction [Line Items]      
Revenues and Other Income/ Costs 55 58 58
DTE Electric | Fuel and purchased power      
Related Party Transaction [Line Items]      
Revenues and Other Income/ Costs 85 65 50
DTE Electric | Other services and interest      
Related Party Transaction [Line Items]      
Revenues and Other Income/ Costs 20 4 2
DTE Electric | Corporate expenses      
Related Party Transaction [Line Items]      
Revenues and Other Income/ Costs $ 349 $ 342 $ 299