Document and Entity Information
Document and Entity Information | 9 Months Ended |
Sep. 30, 2020shares | |
Document Type | 10-Q |
Document Quarterly Report | true |
Document Period End Date | Sep. 30, 2020 |
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 | 48226-1279 |
City Area Code | 313 |
Local Phone Number | 235-4000 |
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 |
Entity Shell Company | false |
Entity Common Stock, Shares Outstanding | 193,559,593 |
Entity Central Index Key | 0000936340 |
Current Fiscal Year End Date | --12-31 |
Document Fiscal Year Focus | 2020 |
Document Fiscal Period Focus | Q3 |
Amendment Flag | false |
DTE Electric | |
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 Current Reporting Status | Yes |
Entity Interactive Data Current | Yes |
Entity Filer Category | Non-accelerated Filer |
Entity Small Business | false |
Entity Emerging Growth Company | false |
Entity Shell Company | false |
Entity Common Stock, Shares Outstanding | 138,632,324 |
Entity Central Index Key | 0000028385 |
Common stock, without par value | |
Title of 12(b) Security | Common stock, without par value |
Trading Symbol | DTE |
Security Exchange Name | NYSE |
2016 Series B 5.375% Junior Subordinated Debentures due 2076 | |
Title of 12(b) Security | 2016 Series B 5.375% Junior Subordinated Debentures due 2076 |
Trading Symbol | DTJ |
Security Exchange Name | NYSE |
2016 Series F 6.00% Junior Subordinated Debentures due 2076 | |
Title of 12(b) Security | 2016 Series F 6.00% Junior Subordinated Debentures due 2076 |
Trading Symbol | DTY |
Security Exchange Name | NYSE |
2017 Series E 5.25% Junior Subordinated Debentures due 2077 | |
Title of 12(b) Security | 2017 Series E 5.25% Junior Subordinated Debentures due 2077 |
Trading Symbol | DTW |
Security Exchange Name | NYSE |
2019 6.25% Corporate Units | |
Title of 12(b) Security | 2019 6.25% Corporate Units |
Trading Symbol | DTP |
Security Exchange Name | NYSE |
2020 Series G 4.375% Junior Subordinated Debentures due 2080 | |
Title of 12(b) Security | 2020 Series G 4.375% Junior Subordinated Debentures due 2080 |
Trading Symbol | DTB |
Security Exchange Name | NYSE |
Consolidated Statements of Oper
Consolidated Statements of Operations (Unaudited) - USD ($) shares in Millions, $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | |
Operating Revenues | ||||
Utility operations | $ 1,844 | $ 1,656 | $ 5,119 | $ 4,937 |
Non-utility operations | 1,440 | 1,463 | 3,770 | 4,584 |
Operating Revenues | 3,284 | 3,119 | 8,889 | 9,521 |
Operating Expenses | ||||
Fuel, purchased power, and gas — utility | 455 | 400 | 1,296 | 1,342 |
Fuel, purchased power, and gas — non-utility | 1,180 | 1,257 | 2,937 | 3,900 |
Operation and maintenance | 588 | 588 | 1,731 | 1,739 |
Depreciation and amortization | 356 | 322 | 1,059 | 923 |
Taxes other than income | 103 | 101 | 306 | 311 |
Asset (gains) losses and impairments, net | (6) | 1 | 39 | 14 |
Operating Expenses | 2,676 | 2,669 | 7,368 | 8,229 |
Operating Income | 608 | 450 | 1,521 | 1,292 |
Other (Income) and Deductions | ||||
Interest expense | 178 | 162 | 532 | 468 |
Interest income | (15) | (4) | (31) | (11) |
Non-operating retirement benefits, net | 5 | 9 | 20 | 28 |
Other income | (120) | (98) | (286) | (259) |
Other expenses | 20 | 17 | 72 | 40 |
Other (Income) and Deductions | 68 | 86 | 307 | 266 |
Income Before Income Taxes | 540 | 364 | 1,214 | 1,026 |
Income Tax Expense | 63 | 47 | 118 | 122 |
Net Income | 477 | 317 | 1,096 | 904 |
Less: Net Income (Loss) Attributable to Noncontrolling Interests | 1 | (2) | 3 | 2 |
Net Income Attributable to DTE Energy Company/DTE Electric Company | $ 476 | $ 319 | $ 1,093 | $ 902 |
Basic Earnings per Common Share | ||||
Net Income Attributable to DTE Energy Company (in dollars per share) | $ 2.47 | $ 1.74 | $ 5.67 | $ 4.93 |
Diluted Earnings per Common Share | ||||
Net Income Attributable to DTE Energy Company (in dollars per share) | $ 2.46 | $ 1.73 | $ 5.66 | $ 4.91 |
Weighted Average Common Shares Outstanding | ||||
Basic (in shares) | 193 | 183 | 192 | 183 |
Diluted (in shares) | 193 | 184 | 193 | 184 |
DTE Electric | ||||
Operating Revenues | ||||
Utility operations | $ 1,690 | $ 1,519 | $ 4,211 | $ 3,944 |
Operating Expenses | ||||
Fuel, purchased power, and gas — utility | 451 | 399 | 1,090 | 1,067 |
Operation and maintenance | 361 | 356 | 1,074 | 1,048 |
Depreciation and amortization | 258 | 244 | 768 | 694 |
Taxes other than income | 79 | 80 | 220 | 233 |
Asset (gains) losses and impairments, net | 0 | 0 | 41 | 13 |
Operating Expenses | 1,149 | 1,079 | 3,193 | 3,055 |
Operating Income | 541 | 440 | 1,018 | 889 |
Other (Income) and Deductions | ||||
Interest expense | 83 | 80 | 249 | 234 |
Interest income | 0 | 0 | (2) | (1) |
Other income | (18) | (20) | (68) | (78) |
Other expenses | 18 | 14 | 66 | 34 |
Other (Income) and Deductions | 83 | 74 | 245 | 189 |
Income Before Income Taxes | 458 | 366 | 773 | 700 |
Income Tax Expense | 58 | 59 | 96 | 113 |
Net Income Attributable to DTE Energy Company/DTE Electric Company | $ 400 | $ 307 | $ 677 | $ 587 |
Consolidated Statements of Comp
Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | |
Net Income | $ 477 | $ 317 | $ 1,096 | $ 904 |
Net Income | 476 | 319 | 1,093 | 902 |
Other comprehensive income (loss), net of tax: | ||||
Benefit obligations, net of taxes of $1, $2, $3, and $4, respectively | 2 | 4 | 7 | 11 |
Net unrealized gains (losses) on derivatives, net of taxes of $—, $(1), $1, and $(4), respectively | 1 | (4) | 3 | (13) |
Foreign currency translation | 0 | 0 | 0 | 1 |
Other comprehensive income (loss) | 3 | 0 | 10 | (1) |
Comprehensive income | 480 | 317 | 1,106 | 903 |
Less: Comprehensive income (loss) attributable to noncontrolling interests | 1 | (2) | 3 | 2 |
Comprehensive Income Attributable to DTE Energy Company/DTE Electric Company | 479 | 319 | 1,103 | 901 |
DTE Electric | ||||
Net Income | 400 | 307 | 677 | 587 |
Other comprehensive income (loss), net of tax: | ||||
Other comprehensive income (loss) | 0 | 0 | 0 | 0 |
Comprehensive Income Attributable to DTE Energy Company/DTE Electric Company | $ 400 | $ 307 | $ 677 | $ 587 |
Consolidated Statements of Co_2
Consolidated Statements of Comprehensive Income (Unaudited) (Parentheticals) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | |
Statement of Comprehensive Income [Abstract] | ||||
Tax effect on benefit obligation | $ 1 | $ 2 | $ 3 | $ 4 |
Tax effect on net unrealized gains (losses) on derivatives during the period | $ 0 | $ (1) | $ 1 | $ (4) |
Consolidated Statements of Fina
Consolidated Statements of Financial Position (Unaudited) - USD ($) $ in Millions | Sep. 30, 2020 | Dec. 31, 2019 |
Current Assets | ||
Cash and cash equivalents | $ 945 | $ 93 |
Restricted cash | 17 | 0 |
Accounts receivable (less allowance for doubtful accounts) | ||
Customer | 1,419 | 1,642 |
Other | 140 | 245 |
Inventories | ||
Fuel and gas | 412 | 373 |
Materials and supplies | 403 | 386 |
Derivative assets | 65 | 133 |
Regulatory assets | 125 | 5 |
Other | 295 | 209 |
Total Current Assets | 3,821 | 3,086 |
Investments | ||
Nuclear decommissioning trust funds | 1,664 | 1,661 |
Investments in equity method investees | 1,865 | 1,862 |
Other | 186 | 265 |
Total Investments | 3,715 | 3,788 |
Property | ||
Property, plant, and equipment | 37,256 | 35,072 |
Accumulated depreciation and amortization | (10,097) | (9,755) |
Property, plant, and equipment, net | 27,159 | 25,317 |
Other Assets | ||
Goodwill | 2,465 | 2,464 |
Regulatory assets | 4,187 | 4,171 |
Intangible assets | 2,358 | 2,393 |
Notes receivable | 255 | 202 |
Derivative assets | 29 | 41 |
Prepaid postretirement costs | 125 | 69 |
Operating lease right-of-use assets | 157 | 169 |
Other | 168 | 182 |
Total Other Assets | 9,744 | 9,691 |
Total Assets | 44,439 | 41,882 |
Accounts payable | ||
Accounts payable | 964 | 1,076 |
Accrued interest | 167 | 147 |
Dividends payable | 196 | 195 |
Short-term borrowings | 988 | 828 |
Current portion long-term debt, including finance leases | 467 | 687 |
Derivative liabilities | 60 | 83 |
Regulatory liabilities | 34 | 65 |
Short-term borrowings | ||
Operating lease liabilities | 32 | 33 |
Acquisition related deferred payment | 0 | 379 |
Other | 509 | 504 |
Total Current Liabilities | 3,417 | 3,997 |
Long-Term Debt (net of current portion) | ||
Mortgage bonds, notes, and other | 17,052 | 14,778 |
Junior subordinated debentures | 1,146 | 1,146 |
Finance lease liabilities | 21 | 11 |
Total Long-Term Debt (net of current portion) | 18,219 | 15,935 |
Other Liabilities | ||
Deferred income taxes | 2,736 | 2,315 |
Regulatory liabilities | 3,129 | 3,264 |
Asset retirement obligations | 2,794 | 2,672 |
Unamortized investment tax credit | 163 | 166 |
Derivative liabilities | 44 | 86 |
Accrued pension liability | 682 | 808 |
Nuclear decommissioning | 251 | 249 |
Operating lease liabilities | 116 | 127 |
Other | 400 | 427 |
Total Other Liabilities | 10,315 | 10,114 |
Commitments and Contingencies (Notes 6 and 13) | ||
Equity | ||
Common stock | 5,369 | 5,233 |
Retained earnings | 7,092 | 6,587 |
Accumulated other comprehensive income (loss) | (138) | (148) |
Total DTE Energy/DTE Electric Company Equity | 12,323 | 11,672 |
Noncontrolling interests | 165 | 164 |
Total Equity | 12,488 | 11,836 |
Total Liabilities and Equity | 44,439 | 41,882 |
DTE Electric | ||
Current Assets | ||
Cash and cash equivalents | 189 | 12 |
Accounts receivable (less allowance for doubtful accounts) | ||
Customer | 784 | 729 |
Affiliates | 1 | 25 |
Other | 81 | 41 |
Inventories | ||
Fuel and gas | 204 | 187 |
Materials and supplies | 293 | 280 |
Regulatory assets | 123 | 5 |
Prepaid property tax | 115 | 52 |
Other | 25 | 26 |
Total Current Assets | 1,815 | 1,357 |
Investments | ||
Nuclear decommissioning trust funds | 1,664 | 1,661 |
Other | 38 | 38 |
Total Investments | 1,702 | 1,699 |
Property | ||
Property, plant, and equipment | 25,585 | 24,279 |
Accumulated depreciation and amortization | (6,895) | (6,706) |
Property, plant, and equipment, net | 18,690 | 17,573 |
Other Assets | ||
Regulatory assets | 3,500 | 3,448 |
Intangible assets | 11 | 15 |
Prepaid postretirement costs — affiliates | 266 | 266 |
Operating lease right-of-use assets | 78 | 87 |
Other | 137 | 143 |
Total Other Assets | 3,992 | 3,959 |
Total Assets | 26,199 | 24,588 |
Accounts payable | ||
Affiliates | 65 | 59 |
Other | 392 | 406 |
Accrued interest | 79 | 84 |
Current portion long-term debt, including finance leases | 466 | 636 |
Regulatory liabilities | 12 | 40 |
Short-term borrowings | ||
Affiliates | 104 | 97 |
Other | 200 | 354 |
Operating lease liabilities | 12 | 12 |
Other | 167 | 155 |
Total Current Liabilities | 1,497 | 1,843 |
Long-Term Debt (net of current portion) | ||
Mortgage bonds, notes, and other | 7,773 | 6,548 |
Finance lease liabilities | 14 | 4 |
Total Long-Term Debt (net of current portion) | 7,787 | 6,552 |
Other Liabilities | ||
Deferred income taxes | 2,489 | 2,355 |
Regulatory liabilities | 2,441 | 2,546 |
Asset retirement obligations | 2,564 | 2,447 |
Unamortized investment tax credit | 163 | 166 |
Nuclear decommissioning | 251 | 249 |
Accrued pension liability — affiliates | 637 | 717 |
Accrued postretirement liability — affiliates | 332 | 367 |
Operating lease liabilities | 59 | 67 |
Other | 111 | 84 |
Total Other Liabilities | 9,047 | 8,998 |
Commitments and Contingencies (Notes 6 and 13) | ||
Equity | ||
Common stock | 5,211 | 4,811 |
Retained earnings | 2,657 | 2,384 |
Total DTE Energy/DTE Electric Company Equity | 7,868 | 7,195 |
Total Liabilities and Equity | $ 26,199 | $ 24,588 |
Consolidated Statements of Fi_2
Consolidated Statements of Financial Position (Unaudited) (Parenthetical) - USD ($) $ in Millions | Sep. 30, 2020 | Dec. 31, 2019 |
Allowance for doubtful accounts | $ 87 | $ 91 |
Shareholder’s Equity | ||
Common stock, shares authorized (in shares) | 400,000,000 | 400,000,000 |
Common stock, shares issued (in shares) | 193,559,593 | 192,208,533 |
Common stock, shares outstanding (in shares) | 193,559,593 | 192,208,533 |
DTE Electric | ||
Allowance for doubtful accounts | $ 49 | $ 46 |
Shareholder’s Equity | ||
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 |
Consolidated Statements of Cash
Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2020 | Sep. 30, 2019 | |
Operating Activities | ||
Net Income | $ 1,096 | $ 904 |
Net Income | 1,093 | 902 |
Adjustments to reconcile Net Income to Net cash from operating activities: | ||
Depreciation and amortization | 1,059 | 923 |
Nuclear fuel amortization | 22 | 45 |
Allowance for equity funds used during construction | (19) | (18) |
Deferred income taxes | 350 | 285 |
Equity earnings of equity method investees | (96) | (77) |
Dividends from equity method investees | 122 | 129 |
Asset (gains) losses and impairments, net | 44 | 14 |
Changes in assets and liabilities: | ||
Accounts receivable, net | 343 | 188 |
Inventories | (54) | 5 |
Prepaid postretirement benefit costs | (56) | (29) |
Accounts payable | (80) | (291) |
Accrued pension liability | (126) | (179) |
Derivative assets and liabilities | 15 | 8 |
Regulatory assets and liabilities | (30) | 203 |
Other current and noncurrent assets and liabilities | 191 | (209) |
Net cash from operating activities | 2,781 | 1,901 |
Investing Activities | ||
Plant and equipment expenditures — utility | (2,362) | (1,982) |
Plant and equipment expenditures — non-utility | (526) | (177) |
Acquisitions related to business combinations, net of cash acquired | (126) | (174) |
Proceeds from sale of assets | 7 | 0 |
Proceeds from sale of nuclear decommissioning trust fund assets | 2,054 | 594 |
Investment in nuclear decommissioning trust funds | (2,051) | (599) |
Distributions from equity method investees | 6 | 9 |
Contributions to equity method investees | (32) | (128) |
Notes receivable | (58) | (81) |
Other | (5) | (20) |
Net cash used for investing activities | (3,093) | (2,558) |
Financing Activities | ||
Issuance of long-term debt, net of issuance costs | 2,724 | 1,433 |
Redemption of long-term debt | (682) | 0 |
Short-term borrowings, net | 160 | 115 |
Dividends paid on common stock | (574) | (518) |
Contributions from noncontrolling interests, principally REF entities | 25 | 23 |
Distributions to noncontrolling interests | (27) | (44) |
Purchases of noncontrolling interest, principally SGG | 0 | (300) |
Acquisition related deferred payment | (380) | 0 |
Other | (65) | (52) |
Net cash from financing activities | 1,181 | 657 |
Net Increase in Cash, Cash Equivalents, and Restricted Cash | 869 | 0 |
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | 93 | 76 |
Cash, Cash Equivalents, and Restricted Cash at End of Period | 962 | 76 |
Supplemental disclosure of non-cash investing and financing activities | ||
Plant and equipment expenditures in accounts payable | 282 | 292 |
DTE Electric | ||
Operating Activities | ||
Net Income | 677 | 587 |
Adjustments to reconcile Net Income to Net cash from operating activities: | ||
Depreciation and amortization | 768 | 694 |
Nuclear fuel amortization | 22 | 45 |
Allowance for equity funds used during construction | (18) | (17) |
Deferred income taxes | 74 | 66 |
Asset (gains) losses and impairments, net | 41 | 13 |
Changes in assets and liabilities: | ||
Accounts receivable, net | (71) | (20) |
Inventories | (30) | (14) |
Accounts payable | 37 | (15) |
Accrued pension liability — affiliates | (80) | (107) |
Accrued postretirement liability — affiliates | (35) | (16) |
Regulatory assets and liabilities | (79) | 178 |
Other current and noncurrent assets and liabilities | (20) | (237) |
Net cash from operating activities | 1,286 | 1,157 |
Investing Activities | ||
Plant and equipment expenditures | (1,981) | (1,611) |
Proceeds from sale of nuclear decommissioning trust fund assets | 2,054 | 594 |
Investment in nuclear decommissioning trust funds | (2,051) | (599) |
Other | (14) | (19) |
Net cash used for investing activities | (1,992) | (1,635) |
Financing Activities | ||
Issuance of long-term debt, net of issuance costs | 1,683 | 643 |
Redemption of long-term debt | (632) | 0 |
Capital contribution by parent company | 400 | 0 |
Short-term borrowings, net — affiliate | 7 | (4) |
Short-term borrowings, net — other | (154) | 233 |
Dividends paid on common stock | (404) | (370) |
Other | (17) | (16) |
Net cash from financing activities | 883 | 486 |
Net Increase in Cash, Cash Equivalents, and Restricted Cash | 177 | 8 |
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | 12 | 18 |
Cash, Cash Equivalents, and Restricted Cash at End of Period | 189 | 26 |
Supplemental disclosure of non-cash investing and financing activities | ||
Plant and equipment expenditures in accounts payable | $ 141 | $ 168 |
Consolidated Statements of Chan
Consolidated Statements of Changes in Equity (Unaudited) - USD ($) $ in Millions | Total | Implementation of ASU | Common Stock | Retained Earnings | Retained EarningsImplementation of ASU | Accumulated Other Comprehensive Income (Loss) | Accumulated Other Comprehensive Income (Loss)Implementation of ASU | Noncontrolling Interests | DTE Electric | DTE ElectricCommon Stock | DTE ElectricAdditional Paid-in Capital | DTE ElectricRetained Earnings |
Beginning Balance (in shares) at Dec. 31, 2018 | 181,925,000 | 138,632,000 | ||||||||||
Beginning Balance at Dec. 31, 2018 | $ 10,717 | $ 0 | $ 4,245 | $ 6,112 | $ 25 | $ (120) | $ (25) | $ 480 | ||||
Beginning Balance at Dec. 31, 2018 | $ 6,793 | $ 1,386 | $ 3,245 | $ 2,162 | ||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||
Net Income | 147 | 147 | ||||||||||
Net Income (Loss) | 408 | 401 | 7 | |||||||||
Dividends declared on common stock | (173) | (173) | (124) | (124) | ||||||||
Contribution of common stock to pension plan (in shares) | 815,000 | |||||||||||
Contribution of common stock to pension plan | 100 | $ 100 | ||||||||||
Other comprehensive income (loss), net of tax | 2 | 2 | ||||||||||
Stock-based compensation, net distributions to (contributions from) noncontrolling interests, and other (in shares) | 472,000 | |||||||||||
Stock-based compensation, net (distributions to) contributions from noncontrolling interests, and other | (34) | $ (21) | (1) | (12) | ||||||||
Ending Balance (in shares) at Mar. 31, 2019 | 183,212,000 | 138,632,000 | ||||||||||
Ending Balance at Mar. 31, 2019 | 11,020 | $ 4,324 | 6,364 | (143) | 475 | |||||||
Ending Balance at Mar. 31, 2019 | 6,816 | $ 1,386 | 3,245 | 2,185 | ||||||||
Beginning Balance (in shares) at Dec. 31, 2018 | 181,925,000 | 138,632,000 | ||||||||||
Beginning Balance at Dec. 31, 2018 | 10,717 | 0 | $ 4,245 | 6,112 | 25 | (120) | (25) | 480 | ||||
Beginning Balance at Dec. 31, 2018 | 6,793 | $ 1,386 | 3,245 | 2,162 | ||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||
Net Income | 902 | 587 | ||||||||||
Net Income (Loss) | 904 | |||||||||||
Other comprehensive income (loss), net of tax | (1) | 0 | ||||||||||
Ending Balance (in shares) at Sep. 30, 2019 | 183,397,000 | 138,632,000 | ||||||||||
Ending Balance at Sep. 30, 2019 | 10,904 | $ 4,370 | 6,516 | (146) | 164 | |||||||
Ending Balance at Sep. 30, 2019 | 7,010 | $ 1,386 | 3,245 | 2,379 | ||||||||
Beginning Balance (in shares) at Dec. 31, 2018 | 181,925,000 | 138,632,000 | ||||||||||
Beginning Balance at Dec. 31, 2018 | $ 10,717 | $ 0 | $ 4,245 | 6,112 | $ 25 | (120) | $ (25) | 480 | ||||
Beginning Balance at Dec. 31, 2018 | $ 6,793 | $ 1,386 | 3,245 | 2,162 | ||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||
Implementation of ASU | us-gaap:AccountingStandardsUpdate201802Member | |||||||||||
Ending Balance (in shares) at Dec. 31, 2019 | 192,208,533 | 192,209,000 | 138,632,324 | 138,632,000 | ||||||||
Ending Balance at Dec. 31, 2019 | $ 11,836 | $ 5,233 | 6,587 | (148) | 164 | |||||||
Ending Balance at Dec. 31, 2019 | 11,672 | $ 7,195 | $ 1,386 | 3,425 | 2,384 | |||||||
Beginning Balance (in shares) at Mar. 31, 2019 | 183,212,000 | 138,632,000 | ||||||||||
Beginning Balance at Mar. 31, 2019 | 11,020 | $ 4,324 | 6,364 | (143) | 475 | |||||||
Beginning Balance at Mar. 31, 2019 | 6,816 | $ 1,386 | 3,245 | 2,185 | ||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||
Net Income | 133 | 133 | ||||||||||
Net Income (Loss) | 179 | 182 | (3) | |||||||||
Dividends declared on common stock | (347) | (347) | (123) | (123) | ||||||||
Other comprehensive income (loss), net of tax | (3) | (3) | ||||||||||
Purchase of noncontrolling interests, principally SGG | (300) | $ (3) | (297) | |||||||||
Stock-based compensation, net distributions to (contributions from) noncontrolling interests, and other (in shares) | 90,000 | |||||||||||
Stock-based compensation, net (distributions to) contributions from noncontrolling interests, and other | 20 | $ 23 | (1) | (2) | ||||||||
Ending Balance (in shares) at Jun. 30, 2019 | 183,302,000 | 138,632,000 | ||||||||||
Ending Balance at Jun. 30, 2019 | 10,569 | $ 4,344 | 6,198 | (146) | 173 | |||||||
Ending Balance at Jun. 30, 2019 | 6,826 | $ 1,386 | 3,245 | 2,195 | ||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||
Net Income | 319 | 307 | 307 | |||||||||
Net Income (Loss) | 317 | 319 | (2) | |||||||||
Dividends declared on common stock | (123) | (123) | ||||||||||
Other comprehensive income (loss), net of tax | 0 | 0 | ||||||||||
Stock-based compensation, net distributions to (contributions from) noncontrolling interests, and other (in shares) | 95,000 | |||||||||||
Stock-based compensation, net (distributions to) contributions from noncontrolling interests, and other | 18 | $ 26 | (1) | (7) | ||||||||
Ending Balance (in shares) at Sep. 30, 2019 | 183,397,000 | 138,632,000 | ||||||||||
Ending Balance at Sep. 30, 2019 | $ 10,904 | $ 4,370 | 6,516 | (146) | 164 | |||||||
Ending Balance at Sep. 30, 2019 | $ 7,010 | $ 1,386 | 3,245 | 2,379 | ||||||||
Beginning Balance (in shares) at Dec. 31, 2019 | 192,208,533 | 192,209,000 | 138,632,324 | 138,632,000 | ||||||||
Beginning Balance at Dec. 31, 2019 | $ 11,836 | $ 5,233 | 6,587 | (148) | 164 | |||||||
Beginning Balance at Dec. 31, 2019 | 11,672 | $ 7,195 | $ 1,386 | 3,425 | 2,384 | |||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||
Net Income | 94 | 94 | ||||||||||
Net Income (Loss) | 342 | 340 | 2 | |||||||||
Dividends declared on common stock | (195) | (195) | (135) | (135) | ||||||||
Other comprehensive income (loss), net of tax | 3 | 3 | ||||||||||
Stock-based compensation, net distributions to (contributions from) noncontrolling interests, and other (in shares) | 403,000 | |||||||||||
Stock-based compensation, net (distributions to) contributions from noncontrolling interests, and other | 2 | $ 2 | ||||||||||
Ending Balance (in shares) at Mar. 31, 2020 | 192,612,000 | 138,632,000 | ||||||||||
Ending Balance at Mar. 31, 2020 | $ 11,988 | $ 5,235 | 6,732 | (145) | 166 | |||||||
Ending Balance at Mar. 31, 2020 | $ 7,154 | $ 1,386 | 3,425 | 2,343 | ||||||||
Beginning Balance (in shares) at Dec. 31, 2019 | 192,208,533 | 192,209,000 | 138,632,324 | 138,632,000 | ||||||||
Beginning Balance at Dec. 31, 2019 | $ 11,836 | $ 5,233 | 6,587 | (148) | 164 | |||||||
Beginning Balance at Dec. 31, 2019 | 11,672 | $ 7,195 | $ 1,386 | 3,425 | 2,384 | |||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||
Net Income | 1,093 | 677 | ||||||||||
Net Income (Loss) | 1,096 | |||||||||||
Other comprehensive income (loss), net of tax | $ 10 | $ 0 | ||||||||||
Ending Balance (in shares) at Sep. 30, 2020 | 193,559,593 | 193,560,000 | 138,632,324 | 138,632,000 | ||||||||
Ending Balance at Sep. 30, 2020 | $ 12,488 | $ 5,369 | 7,092 | (138) | 165 | |||||||
Ending Balance at Sep. 30, 2020 | 12,323 | $ 7,868 | $ 1,386 | 3,825 | 2,657 | |||||||
Beginning Balance (in shares) at Mar. 31, 2020 | 192,612,000 | 138,632,000 | ||||||||||
Beginning Balance at Mar. 31, 2020 | 11,988 | $ 5,235 | 6,732 | (145) | 166 | |||||||
Beginning Balance at Mar. 31, 2020 | 7,154 | $ 1,386 | 3,425 | 2,343 | ||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||
Net Income | 183 | 183 | ||||||||||
Net Income (Loss) | 277 | 277 | ||||||||||
Dividends declared on common stock | (390) | (390) | (134) | (134) | ||||||||
Other comprehensive income (loss), net of tax | 4 | 4 | ||||||||||
Stock-based compensation, net distributions to (contributions from) noncontrolling interests, and other (in shares) | 39,000 | |||||||||||
Stock-based compensation, net (distributions to) contributions from noncontrolling interests, and other | 13 | $ 12 | (1) | 2 | ||||||||
Ending Balance (in shares) at Jun. 30, 2020 | 192,651,000 | 138,632,000 | ||||||||||
Ending Balance at Jun. 30, 2020 | 11,892 | $ 5,247 | 6,618 | (141) | 168 | |||||||
Ending Balance at Jun. 30, 2020 | 7,203 | $ 1,386 | 3,425 | 2,392 | ||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | ||||||||||||
Net Income | 476 | 400 | 400 | |||||||||
Net Income (Loss) | 477 | 476 | 1 | |||||||||
Dividends declared on common stock | (135) | (135) | ||||||||||
Capital contribution by parent company | 400 | 400 | ||||||||||
Issuance of common stock (in shares) | 98,000 | |||||||||||
Issuance of common stock | 11 | $ 11 | ||||||||||
Contribution of common stock to pension plan (in shares) | 694,000 | |||||||||||
Contribution of common stock to pension plan | 82 | $ 82 | ||||||||||
Other comprehensive income (loss), net of tax | 3 | 3 | $ 0 | |||||||||
Stock-based compensation, net distributions to (contributions from) noncontrolling interests, and other (in shares) | 117,000 | |||||||||||
Stock-based compensation, net (distributions to) contributions from noncontrolling interests, and other | $ 23 | $ 29 | (2) | (4) | ||||||||
Ending Balance (in shares) at Sep. 30, 2020 | 193,559,593 | 193,560,000 | 138,632,324 | 138,632,000 | ||||||||
Ending Balance at Sep. 30, 2020 | $ 12,488 | $ 5,369 | $ 7,092 | $ (138) | $ 165 | |||||||
Ending Balance at Sep. 30, 2020 | $ 12,323 | $ 7,868 | $ 1,386 | $ 3,825 | $ 2,657 |
Consolidated Statements of Ch_2
Consolidated Statements of Changes in Equity (Unaudited) (Parenthetical) - $ / shares | 3 Months Ended | |||
Jun. 30, 2020 | Mar. 31, 2020 | Jun. 30, 2019 | Mar. 31, 2019 | |
Statement of Stockholders' Equity [Abstract] | ||||
Dividends declared on common stock (in dollars per share) | $ 2.03 | $ 1.01 | $ 1.89 | $ 0.95 |
Organization and Basis of Prese
Organization and Basis of Presentation | 9 Months Ended |
Sep. 30, 2020 | |
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 2.2 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 1.3 million customers throughout Michigan and the sale of storage and transportation capacity; and • Other businesses primarily involved in 1) services related to the gathering, transportation, and storage of natural gas; 2) power and industrial projects; and 3) 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, the EGLE, and for DTE Energy, the CFTC. Basis of Presentation The Consolidated Financial Statements should be read in conjunction with the Combined Notes to Consolidated Financial Statements included in the combined DTE Energy and DTE Electric 2019 Annual Report on Form 10-K. 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 Consolidated Financial Statements are unaudited but, in the Registrants' opinions, include all adjustments necessary to present a fair statement of the results for the interim periods. All adjustments are of a normal recurring nature, except as otherwise disclosed in these Consolidated Financial Statements and Combined Notes to Consolidated Financial Statements. Financial results for this interim period are not necessarily indicative of results that may be expected for any other interim period or for the fiscal year ending December 31, 2020. 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 DTE Electric 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 cost method is used. 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 DTE Energy's Power and Industrial Projects 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. DTE Energy currently owns an 85% interest in SGG, which owns and operates midstream natural gas assets. SGG has contracts through which certain construction risk is designed to pass-through to the customers, with DTE Energy retaining operational and customer default risk. SGG is a VIE with DTE Energy as the primary beneficiary. The Registrants have variable interests in NEXUS, which include DTE Energy's 50% ownership interest and DTE Electric's transportation services contract. NEXUS is a joint venture which owns a 256-mile pipeline to transport Utica and Marcellus shale gas to Ohio, Michigan, and Ontario market centers. NEXUS also owns Generation Pipeline, LLC, a 23-mile regulated pipeline system located in northern Ohio, which was acquired in September 2019. NEXUS is a VIE as it has insufficient equity at risk to finance its activities. The Registrants are not the primary beneficiaries, as the power to direct significant activities is shared between the owners of the equity interests. DTE Energy accounts for its ownership interest in NEXUS 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, including the transportation services contract with NEXUS. As of September 30, 2020, 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 September 30, 2020, 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. The maximum risk exposure for consolidated VIEs is reflected on the Registrants' Consolidated Statements of Financial Position and, for DTE Energy, in Note 13 to the Consolidated Financial Statements, "Commitments and Contingencies," related to the REF guarantees and indemnities. For non-consolidated VIEs, the maximum risk exposure of the Registrants is generally limited to their investment, notes receivable, future funding commitments, and amounts which DTE Energy has guaranteed. See Note 13 to the Consolidated Financial Statements, "Commitments and Contingencies," for further discussion of the NEXUS guarantee arrangements. The following table summarizes the major Consolidated Statements of Financial Position items for consolidated VIEs as of September 30, 2020 and December 31, 2019. 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. 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 below. Amounts for DTE Energy's consolidated VIEs are as follows: September 30, 2020 December 31, 2019 SGG (a) Other Total SGG (a) Other Total (In millions) ASSETS Cash and cash equivalents $ 33 $ 22 $ 55 $ 16 $ 11 $ 27 Accounts receivable 7 18 25 8 19 27 Inventories — 102 102 — 74 74 Property, plant, and equipment, net 404 25 429 410 33 443 Goodwill 25 — 25 25 — 25 Intangible assets 531 — 531 542 — 542 Other current and long-term assets 1 19 20 2 — 2 $ 1,001 $ 186 $ 1,187 $ 1,003 $ 137 $ 1,140 LIABILITIES Accounts payable and accrued current liabilities $ — $ 19 $ 19 $ 2 $ 13 $ 15 Short-term borrowings — 21 21 — — — Other current and long-term liabilities 6 4 10 7 7 14 $ 6 $ 44 $ 50 $ 9 $ 20 $ 29 _____________________________________ (a) Amounts shown are 100% of SGG's assets and liabilities, of which DTE Energy owns 85% at September 30, 2020 and December 31, 2019. Amounts for DTE Energy's non-consolidated VIEs are as follows: September 30, 2020 December 31, 2019 (In millions) Investments in equity method investees $ 1,505 $ 1,503 Notes receivable $ 40 $ 21 Future funding commitments $ 36 $ 63 |
Significant Accounting Policies
Significant Accounting Policies | 9 Months Ended |
Sep. 30, 2020 | |
Accounting Policies [Abstract] | |
Significant Accounting Policies | SIGNIFICANT ACCOUNTING POLICIES Other Income The following is a summary of DTE Energy's Other income: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Equity earnings of equity method investees $ 37 $ 34 $ 96 $ 77 Income from REF entities 43 40 95 96 Gains from equity and fixed income securities 2 3 24 27 Contract services 7 7 20 21 Gas Storage and Pipelines post-acquisition settlement 20 — 20 — Allowance for equity funds used during construction 6 5 19 18 Other 5 9 12 20 $ 120 $ 98 $ 286 $ 259 The following is a summary of DTE Electric's Other income: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Gains from equity and fixed income securities allocated from DTE Energy $ 2 $ 3 $ 24 $ 27 Contract services 7 7 20 23 Allowance for equity funds used during construction 6 5 18 17 Other 3 5 6 11 $ 18 $ 20 $ 68 $ 78 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. 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. For the three and nine months ended September 30, 2020, reclassifications out of Accumulated other comprehensive income (loss) were not material. On January 1, 2019, DTE Energy reclassified $25 million of stranded tax effects resulting from the TCJA from Accumulated other comprehensive income (loss) to Retained Earnings. The reclassification was recorded upon adoption of ASU No. 2018-02 Income Statement — Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income . For the three and nine months ended September 30, 2019, reclassifications out of Accumulated other comprehensive income (loss) not relating to the adoption of this standard were not material. Income Taxes The interim effective tax rates of the Registrants are as follows: Effective Tax Rate Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 DTE Energy 12 % 13 % 10 % 12 % DTE Electric 13 % 16 % 12 % 16 % These tax rates are affected by estimated annual permanent items, including AFUDC equity, production tax credits, and other flow-through items, as well as discrete items that may occur in any given period, but are not consistent from period to period. The 1% decrease in DTE Energy's effective tax rate for the three months ended September 30, 2020 was primarily due to higher amortization of the TCJA regulatory liability of 2%, partially offset by a decrease in annual production tax credits of 1%. The 2% decrease in DTE Energy's effective tax rate for the nine months ended September 30, 2020 was primarily due to the carryback of the 2018 net operating loss due to the CARES Act of 3% and higher amortization of the TCJA regulatory liability of 2%, partially offset by a decrease in production tax credits and other of 3%. Refer below for additional information regarding the CARES Act and related tax impacts. The 3% decrease in DTE Electric's effective tax rate for the three months ended September 30, 2020 was primarily due to higher amortization of the TCJA regulatory liability of 3%. The 4% decrease in DTE Electric's effective tax rate for the nine months ended September 30, 2020 was primarily due to higher amortization of the TCJA regulatory liability of 3% and an increase in annual production tax credits of 1%. DTE Electric had an income tax payable with DTE Energy of $5 million and an income tax receivable with DTE Energy of $14 million at September 30, 2020 and December 31, 2019, respectively. In March 2020, the "Coronavirus Aid, Relief, and Economic Security Act" (CARES Act) was signed into law and included several significant changes to the Internal Revenue Code. The CARES Act includes certain tax relief provisions applicable to the Registrants including a) the immediate refund of the corporate AMT credit, b) the ability to carryback net operating losses five years for tax years 2018 through 2020, c) the employee retention credit, and d) delayed payment of employer payroll taxes. During the third quarter 2020, DTE Energy received $220 million of refunds from the U.S. Treasury, including $153 million for the immediate refund of the 2018 remaining AMT credit balance and $67 million as a result of carrying back the 2018 net operating loss to 2013. In addition, the carryback of the 2018 net operating loss to 2013 resulted in a $34 million reduction in Income Tax Expense for the nine months ended September 30, 2020 due primarily to the difference in rates between the two years (35% in 2013 and 21% in 2018). During the second quarter 2020, the Registrants filed a claim for employee retention credits of $6 million, of which $3 million is attributable to DTE Electric. These amounts are included in Taxes other than income in the Consolidated Statements of Operations for the nine months ended September 30, 2020. The Registrants have also deferred employer payroll taxes of $32 million, of which $17 million was attributable to DTE Electric, increasing the amount of Other Liabilities - Other on the Registrants' Consolidated Statements of Financial Position as of September 30, 2020. Unrecognized Compensation Costs As of September 30, 2020, DTE Energy had $84 million of total unrecognized compensation cost related to non-vested stock incentive plan arrangements. That cost is expected to be recognized over a weighted-average period of 1.41 years. Allocated Stock-Based Compensation DTE Electric received an allocation of costs from DTE Energy associated with stock-based compensation of $12 million and $9 million for the three months ended September 30, 2020 and 2019, respectively, while such allocation was $28 million and $33 million for the nine months ended September 30, 2020 and 2019, respectively. Cash, Cash Equivalents, and Restricted Cash Cash and cash equivalents include cash on hand, cash in banks, and temporary investments purchased with remaining maturities of three months or less. Restricted cash consists of funds held in separate bank accounts to satisfy contractual obligations to fund certain construction projects and guarantee performance. Restricted cash designated for payments within one year is classified as a Current Asset. Financing Receivables 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, classified by internal grade of credit risk. The related credit quality indicators and risk ratings utilized to develop the internal grades have been updated through September 30, 2020. DTE Energy DTE Electric Year of origination 2020 2019 2018 and prior Total 2020 and prior (In millions) Notes receivable Internal grade 1 $ — $ 18 $ 9 $ 27 $ 18 Internal grade 2 60 19 6 85 — Total notes receivable (a) $ 60 $ 37 $ 15 $ 112 $ 18 Net investment in leases Net investment in leases, internal grade 1 $ 8 $ — $ 40 $ 48 $ — Net investment in leases, internal grade 2 132 — 1 133 — Total net investment in leases (a) $ 140 $ — $ 41 $ 181 $ — _______________________________________ (a) For DTE Energy, included in Current Assets — Other and Other Assets — Notes Receivable on the Consolidated Statements of Financial Position. For DTE Electric, included in Current Assets — Other and 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, or financing receivables, for DTE Energy are primarily comprised of finance lease receivables and loans that are included in Notes Receivable and Other current assets on DTE Energy's Consolidated Statements of Financial Position. Notes receivable, or financing receivables, for DTE Electric are primarily comprised of loans. Notes receivable are typically considered delinquent when payment is not received for periods ranging from 60 to 120 days. The Registrants cease accruing interest (nonaccrual status), consider a note receivable impaired, and establish an allowance for credit loss when it is probable that all principal and interest amounts due will not be collected 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. DTE Energy has off balance sheet exposure in the form of a revolving credit facility. Refer to Note 13, "Commitments and Contingencies," for additional information. In determining the level of credit reserve needed, DTE considers the likelihood of funding in addition to the other factors noted above. A reserve may be established when it is likely that funding will occur. 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 table presents a roll-forward of the activity for the Registrants' financing receivables credit loss reserves as of September 30, 2020. DTE Energy DTE Electric Trade accounts receivable Other receivables Total Trade and other accounts receivable (In millions) Beginning reserve balance, January 1, 2020 $ 87 $ 4 $ 91 $ 46 Current period provision 73 2 75 47 Write-offs charged against allowance (117) (3) (120) (68) Recoveries of amounts previously written off 41 — 41 24 Ending reserve balance, September 30, 2020 $ 84 $ 3 $ 87 $ 49 The Registrants have been monitoring the impacts from the COVID-19 pandemic on our customers and various counterparties. For DTE Electric and DTE Gas, the allowance for doubtful accounts has been increased to account for additional risk related to the pandemic. As of September 30, 2020, the impact of these increases has not been material. In April 2020, the MPSC issued an order in response to the COVID-19 pandemic and authorized the deferral of certain uncollectible expense that is in excess of the amount used to set current rates. As a result of the order, DTE Electric and DTE Gas deferred $5 million and $1 million of uncollectible expense as Regulatory assets, respectively, for the nine months ended September 30, 2020. For the three months ended September 30, 2020, DTE Electric and DTE Gas, both reversed $1 million of previously deferred uncollectible expense. Refer to Note 6 to the Consolidated Financial Statements, "Regulatory Matters," for further information regarding the order. For DTE Energy, uncollectible expense was $22 million and $70 million for the three and nine months ended September 30, 2020, respectively, which is primarily comprised of the current period provision for allowance for doubtful accounts adjusted for regulatory deferrals. DTE Energy uncollectible expense was $28 million and $81 million for the three and nine months ended September 30, 2019, respectively. For DTE Electric, uncollectible expense was $16 million and $42 million for the three and nine months ended September 30, 2020, respectively, which is primarily comprised of the current period provision adjusted for regulatory deferrals. DTE Electric uncollectible expense was $17 million and $47 million for the three and nine months ended September 30, 2019, respectively. |
New Accounting Pronouncements
New Accounting Pronouncements | 9 Months Ended |
Sep. 30, 2020 | |
Accounting Standards Update and Change in Accounting Principle [Abstract] | |
New Accounting Pronouncements | NEW ACCOUNTING PRONOUNCEMENTS Recently Adopted Pronouncements In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments , as amended. The amendments in this update have replaced the previous incurred loss impairment methodology with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information, including forecasts, to develop credit loss estimates. The ASU requires entities to use the new methodology to measure impairment of financial instruments, including accounts receivable, and may result in earlier recognition of credit losses than under previous generally accepted accounting principles. Entities must apply the new guidance as a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is adopted. The Registrants adopted the standard effective January 1, 2020. The adoption of the ASU did not have an impact on the Registrants' financial position or results of operations. Additional required disclosures have been included in Note 2 to the Consolidated Financial Statements, “Significant Accounting Policies”. In August 2018, the FASB issued ASU No. 2018-13, Fair Value Measurements (Topic 820): Disclosure Framework - Changes to the Disclosure Requirements for Fair Value Measurement . The amendments in this update modify the disclosure requirements on fair value measurements in Topic 820. The Registrants adopted the ASU effective January 1, 2020. The Registrants have updated Note 8 to the Consolidated Financial Statements, Fair Value, to incorporate the disclosure changes required by the ASU. In August 2018, the FASB issued ASU No. 2018-15, Intangibles - Goodwill and Other - Internal-Use Software (Subtopic 350-40): Customer's Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That is a Service Contract . The amendments in this update align the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software (and hosting arrangements that include an internal use software license). The Registrants adopted the standard effective January 1, 2020 using the prospective approach. The adoption of the ASU did not have an impact on the Registrants’ Consolidated Financial Statements. On a prospective basis, costs within the scope of this amendment will be accounted for consistent with any underlying service contracts. Capitalized implementation costs will be reflected in Other noncurrent assets on the Consolidated Statements of Financial Position and amortization of these costs will be reflected in Operation and maintenance within the Consolidated Statements of Operations. Cash flow activity will be reflected in the Other current and noncurrent assets and liabilities line within the Operating Activities section of the Consolidated Statements of Cash Flows. In August 2018, the FASB issued ASU No. 2018-14, Compensation - Retirement Benefits - Defined Benefit Plans (Subtopic 715-20): Disclosure Framework - Changes to the Disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans . The amendments in this update modify the disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. The Registrants adopted the ASU effective January 1, 2020. The required disclosures for this ASU will be reflected in the 2020 year-end financial statements. In October 2018, the FASB issued ASU No. 2018-17, Consolidation (Topic 810): Targeted Improvements to Related Party Guidance for Variable Interest Entities . The amendments in this update modify the requirements for determining whether fees paid to a decision maker or service provider are variable interests and require reporting entities to consider indirect interests held through related parties under common control on a proportional basis. The Registrants adopted the ASU effective January 1, 2020. The adoption of the ASU did not have a significant impact on the Registrants’ Consolidated Financial Statements. Recently Issued Pronouncements In December 2019, the FASB issued ASU No. 2019-12, Income Taxes (Topic 740) - Simplifying the Accounting for Income Taxes . The amendments in this update simplify the accounting for income taxes by removing certain exceptions, and clarifying certain requirements regarding franchise taxes, goodwill, consolidated tax expenses, and annual effective tax rate calculations. The ASU is effective for the Registrants for fiscal years beginning after December 15, 2020. The Registrants will adopt the ASU on its effective date using a modified retrospective approach. The ASU will not have a significant impact on the Registrants' Consolidated Financial Statements. In March 2020, the FASB issued ASU No. 2020-04, Reference Rate Reform (Topic 848) - Facilitation of the Effects of Reference Rate Reform on Financial Reporting . The amendments in this update provide optional expedients and exceptions for applying GAAP to contracts, hedging relationships, and other transactions affected by reference rate reform if certain criteria are met. The optional expedients are effective for the modification of existing contracts or new arrangements executed March 12, 2020 through December 31, 2022. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements. In August 2020, the FASB issued ASU No. 2020-06, Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging - Contracts in Entity's Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity's Own Equity. The amendments in this update simplify the accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts indexed to and potentially settled in an entity's own equity. The ASU is effective for the Registrants for fiscal years beginning after December 15, 2021, and interim periods therein. Early adoption is permitted. The ASU will not have a significant impact on the Registrants' Consolidated Financial Statements. |
Acquisitions
Acquisitions | 9 Months Ended |
Sep. 30, 2020 | |
Business Combinations [Abstract] | |
Acquisitions | ACQUISITIONS Power and Industrial Projects Segment Acquisition On February 18, 2020, DTE Energy closed on the purchase of an 8 MW combined heat and power generation facility from South Jersey Industries (“SJI”) that provides electricity and hot and chilled water to a hotel and casino in Atlantic City, New Jersey. Direct transaction costs primarily related to advisory fees were immaterial and are included in Operation and maintenance in DTE Energy's Consolidated Statements of Operations. The fair value of consideration provided for the acquisition was approximately $95 million 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) Contract intangibles $ 17 Property, plant, and equipment, net 76 Working capital 2 Total $ 95 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 over a period of 13 years, which is based on the number of years the assets are expected to economically contribute to the business. The pro forma financial information has not been presented for DTE Energy because the effects of the acquisition were not material to the Consolidated Statements of Operations. Electric Segment Acquisitions Effective September 12, 2019, DTE Sustainable Generation closed on the purchase of an 89 MW renewable energy project located in Michigan from Heritage Sustainable Energy in support of DTE Energy's renewable energy goals. 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 $175 million, 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) Contract intangibles $ 109 Property, plant, and equipment, net 60 Working capital 6 Total $ 175 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 useful lives ranging from 11 years to 13 years, which is based on the remaining number of years the assets are expected to economically contribute to the business. The pro forma financial information has not been presented for DTE Energy because the effects of the acquisition were not material to the Consolidated Statements of Operations. In conjunction with the above acquisition, DTE Sustainable Generation closed on a purchase and sale agreement with Heritage Sustainable Energy in January 2020 to acquire an additional renewable energy project for approximately $33 million paid in cash. Gas Storage and Pipelines Segment Acquisition On December 4, 2019, DTE Energy closed on the purchase of midstream natural gas assets in support of its strategy to continue to grow and earn competitive returns for shareholders. DTE Energy purchased 100 percent of M5 Louisiana Gathering, LLC and its wholly owned subsidiaries from Momentum Midstream and Indigo Natural Resources. The acquisition includes the Blue Union and LEAP assets which provide natural gas gathering and other midstream services to producers located primarily in Louisiana. The fair value of the consideration provided for the entities acquired was $2.74 billion and included $2.36 billion paid in cash and an estimated $380 million of contingent consideration to be paid upon completion of the LEAP gathering pipeline. A liability for the contingent consideration payment was recorded upon acquisition and adjusted each period for accretion. Refer to the Acquisition related deferred payment line in the Consolidated Statements of Financial Position for the liability balance for the respective reporting periods. Accretion expense of $1 million and $5 million was recorded for the three and nine months ended September 30, 2020, respectively. In July 2020, the LEAP gathering pipeline achieved the final milestone of its construction and consideration of $385 million was paid on July 27, 2020 in two equal installments. The acquisition was financed through the issuance of Equity Units, common stock, and Senior Notes. The acquired assets are part of DTE Energy's non-utility Gas Storage and Pipelines segment. The acquisition was accounted for using the acquisition method of accounting for business combinations. The allocation of the purchase price included in the Consolidated Statements of Financial Position is preliminary and may be revised up to one year from the date of acquisition due to adjustments in the estimated fair value of the assets acquired and the liabilities assumed. The purchase price is subject to resolution of any indemnification claims that might be deducted from the remaining $14 million of cash consideration paid and held in escrow. The excess purchase price over the fair value of net assets acquired was classified as goodwill. As of September 30, 2020, total goodwill was approximately $172 million, including $1 million resulting from working capital adjustments recorded during the nine months ended September 30, 2020. DTE Energy cannot estimate the potential for any further revisions to the purchase price allocation for the remainder of 2020. The factors contributing to the recognition of goodwill are based on various strategic benefits that are expected to be realized from the Blue Union and LEAP acquisition. The acquisition will provide DTE Energy with a platform for midstream growth and access to further investment opportunities in the Haynesville basin. The goodwill is expected to be deductible for income tax purposes. The preliminary allocation of the purchase price is based on estimated fair values of the Blue Union and LEAP assets acquired and liabilities assumed at the date of acquisition, December 4, 2019. The components of the preliminary purchase price allocation, inclusive of purchase accounting adjustments, are as follows: (In millions) Assets Cash $ 62 Accounts receivable 31 Property, plant, and equipment, net 1,035 Goodwill 172 Customer relationship intangibles 1,473 Other current assets 1 $ 2,774 Liabilities Accounts payable $ 26 Acquisition related deferred payment 380 Other current liabilities 2 Asset retirement obligations 9 $ 417 Total cash consideration $ 2,357 The intangible assets recorded as a result of the acquisition pertain to existing customer relationships, which were valued at approximately $1.47 billion as of the acquisition date. The fair value of the intangible assets acquired was estimated by applying the income approach. The income approach is based upon discounted projected future cash flows attributable to the existing contracts and agreements. The fair value measurement is based on significant unobservable inputs, including management estimates and assumptions, and thus represents a Level 3 measurement, pursuant to the applicable accounting guidance. Key estimates and inputs include revenue and expense projections and discount rates based on the risks associated with the entities. The intangible assets are amortized on a straight-line basis over a period of 40 years, which is based on the number of years the assets are expected to economically contribute to the business. The expected economic benefit incorporates existing customer contracts with a weighted-average amortization life of 13 years and expected renewal rates, based on the estimated volume and production lives of gas resources in the region. DTE Energy incurred $18 million of direct transaction costs for the year ended December 31, 2019. These costs were primarily related to advisory fees and were included in Operation and maintenance in DTE Energy's Consolidated Statements of Operations. Additionally, DTE Energy incurred $49 million of issuance costs related to the acquisition financing, of which $10 million were included in Mortgage bonds, notes, and other, and $39 million were included in Common Stock in DTE Energy's Consolidated Statements of Financial Position. DTE Energy's 2019 Consolidated Statements of Operations included Operating Revenues — Non-utility operations of $15 million and Net Income of $3 million associated with the acquired entities for the one-month period following the acquisition date, excluding the $18 million transaction costs described above. The pro forma financial information was not presented for DTE Energy because the effects of the acquisition were not material to the Consolidated Statements of Operations. |
Revenue
Revenue | 9 Months Ended |
Sep. 30, 2020 | |
Revenue from Contract with Customer [Abstract] | |
Revenue | REVENUE Disaggregation of Revenue The following is a summary of revenues disaggregated by segment for DTE Energy: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Electric (a) Residential $ 900 $ 791 $ 2,169 $ 1,839 Commercial 498 515 1,313 1,358 Industrial 157 175 434 497 Other (b) 138 39 305 251 Total Electric operating revenues (c) $ 1,693 $ 1,520 $ 4,221 $ 3,945 Gas Gas sales $ 92 $ 87 $ 655 $ 727 End User Transportation 34 35 154 157 Intermediate Transportation 15 15 57 57 Other (b) 32 18 98 102 Total Gas operating revenues (d) $ 173 $ 155 $ 964 $ 1,043 Other segment operating revenues Gas Storage and Pipelines (e) $ 204 $ 126 $ 546 $ 363 Power and Industrial Projects (f) $ 324 $ 406 $ 850 $ 1,196 Energy Trading (g) $ 1,061 $ 1,105 $ 2,714 $ 3,519 _______________________________________ (a) Revenues generally represent those of DTE Electric, except $3 million and $10 million of Other revenues related to DTE Sustainable Generation for the three and nine months ended September 30, 2020, respectively. (b) Includes revenue adjustments related to various regulatory mechanisms. (c) Includes $8 million and $5 million of other revenues outside the scope of topic 606 for the three months ended September 30, 2020 and 2019, and $18 million and $14 million for the nine months ended September 30, 2020 and 2019, respectively. (d) Includes $2 million under Alternative Revenue Programs for the nine months ended September 30, 2020 and $2 million and $7 million of other revenues for the three and nine months ended September 30, 2020, respectively, which are all outside the scope of Topic 606. For prior period, revenues include $2 million and $6 million of other revenues for the three and nine months ended September 30, 2019, respectively, which are all outside the scope of Topic 606. (e) Includes revenues outside the scope of Topic 606 primarily related to $2 million of contracts accounted for as leases for the three months ended September 30, 2020 and 2019, and $7 million for the nine months ended September 30, 2020 and 2019. (f) Includes revenues outside the scope of Topic 606 primarily related to $26 million and $33 million of contracts accounted for as leases for the three months ended September 30, 2020 and 2019, respectively, and $74 million and $94 million for the nine months ended September 30, 2020 and 2019, respectively. (g) Includes revenues outside the scope of Topic 606 primarily related to $731 million and $791 million of derivatives for the three months ended September 30, 2020 and 2019, respectively, and $1.8 billion and $2.6 billion of derivatives for the nine months ended September 30, 2020 and 2019, respectively. Deferred Revenue The following is a summary of deferred revenue activity: DTE Energy (In millions) Beginning Balance, January 1, 2020 $ 75 Increases due to cash received or receivable, excluding amounts recognized as revenue during the period 39 Revenue recognized that was included in the deferred revenue balance at the beginning of the period (42) Ending Balance, September 30, 2020 $ 72 The deferred revenues at DTE Energy generally represent amounts paid by or receivable 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 associated with 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) 2020 $ 7 2021 36 2022 7 2023 3 2024 7 2025 and thereafter 12 $ 72 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 Energy DTE Electric (In millions) 2020 $ 72 $ 2 2021 350 8 2022 294 7 2023 231 7 2024 142 8 2025 and thereafter 580 — $ 1,669 $ 32 |
Regulatory Matters
Regulatory Matters | 9 Months Ended |
Sep. 30, 2020 | |
Public Utilities, General Disclosures [Abstract] | |
Regulatory Matters | REGULATORY MATTERS 2020 COVID-19 Response In response to the COVID-19 pandemic, the MPSC issued an order on April 15, 2020 to provide guidance and direction to utilities and other stakeholders on topics including customer protections and affordability, utility accounting, regulatory activities, energy assistance, and energy waste reduction and demand response continuity. The order authorizes the deferral of uncollectible expense that is in excess of the amount used to set current rates effective March 24, 2020, the date of Michigan's executive order to "Stay Home, Stay Safe". The Registrants implemented the deferral in the second quarter 2020, and there is currently no expiration for the ability to defer these costs. Refer to Note 2 to the Consolidated Financial Statements, "Significant Accounting Policies" for the impact to uncollectible expense for the period. On July 23, 2020, the MPSC further ordered that utilities seeking to recover COVID-19 related expenses beyond uncollectible expense may make an informational filing no later than November 2, 2020. The Registrants do not plan to make a filing in response to this order, and will continue to monitor MPSC activities involving COVID-19. 2019 Electric Rate Case Filing DTE Electric filed a rate case with the MPSC on July 8, 2019 requesting an increase in base rates of $351 million based on a projected twelve-month period ending April 30, 2021. The requested increase in base rates is primarily due to an increase in net plant resulting from infrastructure and generation investments. The rate filing also requested an increase in return on equity from 10.0% to 10.5% and included projected changes in sales and operating and maintenance expenses. On May 8, 2020, the MPSC issued an order approving an annual revenue increase of $188 million for services rendered on or after May 15, 2020 and a return on equity of 9.9%. The order also disallowed $41 million of capital expenditures related to incentive compensation previously recorded during 2018-2020. The disallowance was recorded during the second quarter 2020 and is included in Asset (gains) losses and impairment, net on the Consolidated Statements of Operations for the nine months ended September 30, 2020. 2020 Accounting Applications On July 9, 2020, the MPSC approved DTE Electric's request to accelerate amortization of the regulatory liability for non-plant-related accumulated deferred income tax balances that resulted from the TCJA. DTE Electric will increase amortization by $102 million beginning in May 2021, which will fully amortize this regulatory liability by the end of 2021 instead of April 2033. The accelerated amortization will not impact customer rates and will allow DTE Electric to defer its next rate case filing previously set for July 2020 to at least March 2021. On October 26, 2020, DTE Electric filed an application with the MPSC requesting accounting authority for a one-time regulatory liability. DTE Electric is proposing to accrue a $30 million voluntary refund obligation due to certain sales increases resulting from the unusual and unprecedented electricity usage patterns driven by the COVID-19 pandemic. If approved by the end of 2020, the regulatory liability will be recognized at that time. Amortization of the regulatory liability would be used to offset the cost of service related to new plant in 2022. The regulatory liability would be amortized beginning January 1, 2022 through the earlier of new base rates or December 31, 2022. The one-time accounting treatment would not impact customer rates and would allow DTE Electric to further defer its next rate case filing from March 2021 to May 2021. Additionally, as noted in Note 2 to the Consolidated Financial Statements, "Significant Accounting Policies," DTE Electric has deferred $5 million of uncollectible expense as Regulatory assets for the nine months ended September 30, 2020 as a result of the MPSC's COVID-19 response order discussed above. If the October 26th accounting application is approved, DTE Electric would voluntarily forgo this deferral and record as expense. This action would apply only to DTE Electric in 2020 and the deferral of uncollectible expense would resume beginning in January 2021. 2019 Gas Rate Case Filing DTE Gas filed a rate case with the MPSC on November 25, 2019 requesting an increase in base rates of $204 million based on a projected twelve-month period ending September 30, 2021. The requested increase in base rates is primarily due to an increase in net plant resulting from infrastructure investments and operating and maintenance expenses. The rate filing also requests an increase in return on equity from 10.0% to 10.5% and includes projected changes in sales and working capital. |
Earnings Per Share
Earnings Per Share | 9 Months Ended |
Sep. 30, 2020 | |
Earnings Per Share [Abstract] | |
Earnings Per Share | EARNINGS PER SHARE Basic earnings per share is calculated by dividing the 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. Equity units and performance shares do not receive cash dividends; as such, these awards are not considered participating securities. The following is a reconciliation of DTE Energy's basic and diluted income per share calculation: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions, except per share amounts) Basic Earnings per Share Net Income Attributable to DTE Energy Company $ 476 $ 319 $ 1,093 $ 902 Less: Allocation of earnings to net restricted stock awards 1 1 2 2 Net income available to common shareholders — basic $ 475 $ 318 $ 1,091 $ 900 Average number of common shares outstanding — basic 193 183 192 183 Basic Earnings per Common Share $ 2.47 $ 1.74 $ 5.67 $ 4.93 Diluted Earnings per Share Net Income Attributable to DTE Energy Company $ 476 $ 319 $ 1,093 $ 902 Less: Allocation of earnings to net restricted stock awards 1 1 2 2 Net income available to common shareholders — diluted $ 475 $ 318 $ 1,091 $ 900 Average number of common shares outstanding — basic 193 183 192 183 Incremental shares attributable to: Average dilutive equity units, performance share awards, and stock options — 1 1 1 Average number of common shares outstanding — diluted 193 184 193 184 Diluted Earnings per Common Share (a) $ 2.46 $ 1.73 $ 5.66 $ 4.91 _______________________________________ (a) Equity Units excluded from the calculation of diluted EPS were approximately 10.3 million for the three and nine months ended September 30, 2020, as the dilutive stock price threshold was not met. |
Fair Value
Fair Value | 9 Months Ended |
Sep. 30, 2020 | |
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 September 30, 2020 and December 31, 2019. 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 (a) : September 30, 2020 December 31, 2019 Level Level Level Other (b) Netting (c) Net Balance Level Level Level Other (b) Netting (c) Net Balance (In millions) Assets Cash equivalents (d) $ 567 $ — $ — $ — $ — $ 567 $ 15 $ — $ — $ — $ — $ 15 Nuclear decommissioning trusts Equity securities 872 — — 141 — 1,013 1,046 — — — — 1,046 Fixed income securities 122 325 — 80 — 527 160 378 — — — 538 Private equity and other — — — 78 — 78 — — — 43 — 43 Cash equivalents 46 — — — — 46 34 — — — — 34 Other investments (e) Equity securities 49 — — — — 49 140 — — — — 140 Fixed income securities 6 — — — — 6 79 — — — — 79 Cash equivalents 98 — — — — 98 4 — — — — 4 Derivative assets Commodity contracts (f) Natural gas 126 72 42 — (194) 46 205 76 74 — (266) 89 Electricity — 103 34 — (106) 31 — 223 83 — (225) 81 Environmental & Other — 194 7 — (186) 15 — 110 3 — (110) 3 Foreign currency exchange contracts — 2 — — — 2 — 1 — — — 1 Total derivative assets 126 371 83 — (486) 94 205 410 160 — (601) 174 Total $ 1,886 $ 696 $ 83 $ 299 $ (486) $ 2,478 $ 1,683 $ 788 $ 160 $ 43 $ (601) $ 2,073 Liabilities Derivative liabilities Commodity contracts (f) Natural gas $ (118) $ (66) $ (81) $ — $ 185 $ (80) $ (221) $ (41) $ (89) $ — $ 266 $ (85) Electricity — (97) (29) — 104 (22) — (231) (67) — 225 (73) Environmental & Other (3) (168) — — 171 — — (121) — — 110 (11) Foreign currency exchange contracts — (2) — — — (2) — — — — — — Total $ (121) $ (333) $ (110) $ — $ 460 $ (104) $ (221) $ (393) $ (156) $ — $ 601 $ (169) Net Assets (Liabilities) at end of period $ 1,765 $ 363 $ (27) $ 299 $ (26) $ 2,374 $ 1,462 $ 395 $ 4 $ 43 $ — $ 1,904 Assets Current $ 679 $ 273 $ 59 $ — $ (379) $ 632 $ 218 $ 320 $ 123 $ — $ (513) $ 148 Noncurrent 1,207 423 24 299 (107) 1,846 1,465 468 37 43 (88) 1,925 Total Assets $ 1,886 $ 696 $ 83 $ 299 $ (486) $ 2,478 $ 1,683 $ 788 $ 160 $ 43 $ (601) $ 2,073 Liabilities Current $ (112) $ (243) $ (66) $ — $ 361 $ (60) $ (211) $ (300) $ (85) $ — $ 513 $ (83) Noncurrent (9) (90) (44) — 99 (44) (10) (93) (71) — 88 (86) Total Liabilities $ (121) $ (333) $ (110) $ — $ 460 $ (104) $ (221) $ (393) $ (156) $ — $ 601 $ (169) Net Assets (Liabilities) at end of period $ 1,765 $ 363 $ (27) $ 299 $ (26) $ 2,374 $ 1,462 $ 395 $ 4 $ 43 $ — $ 1,904 _______________________________________ (a) See footnotes on following page. _______________________________________ (b) Amounts represent assets valued at NAV as a practical expedient for fair value. (c) 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. (d) At September 30, 2020, the $567 million consisted of $565 million and $2 million of cash equivalents included in Cash and cash equivalents and Restricted cash on DTE Energy's Consolidated Statements of Financial Position, respectively. At December 31, 2019, the $15 million consisted of $4 million and $11 million of cash equivalents included in Cash and cash equivalents and Other investments on DTE Energy's Consolidated Statements of Financial Position, respectively. (e) Excludes cash surrender value of life insurance investments. (f) 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: September 30, 2020 December 31, 2019 Level 1 Level 2 Level 3 Other (a) Net Balance Level 1 Level 2 Level 3 Other (a) Net Balance (In millions) Assets Cash equivalents (b) $ 175 $ — $ — $ — $ 175 $ 11 $ — $ — $ — $ 11 Nuclear decommissioning trusts Equity securities 872 — — 141 1,013 1,046 — — — 1,046 Fixed income securities 122 325 — 80 527 160 378 — — 538 Private equity and other — — — 78 78 — — — 43 43 Cash equivalents 46 — — — 46 34 — — — 34 Other investments Equity securities 14 — — — 14 13 — — — 13 Cash equivalents 11 — — — 11 — — — — — Derivative assets — FTRs — — 7 — 7 — — 3 — 3 Total $ 1,240 $ 325 $ 7 $ 299 $ 1,871 $ 1,264 $ 378 $ 3 $ 43 $ 1,688 Assets Current $ 175 $ — $ 7 $ — $ 182 $ 11 $ — $ 3 $ — $ 14 Noncurrent 1,065 325 — 299 1,689 1,253 378 — 43 1,674 Total Assets $ 1,240 $ 325 $ 7 $ 299 $ 1,871 $ 1,264 $ 378 $ 3 $ 43 $ 1,688 _______________________________________ (a) Amounts represent assets valued at NAV as a practical expedient for fair value. (b) At September 30, 2020, the $175 million of cash equivalents was included in Cash and cash equivalents on DTE Electric's Consolidated Statements of Financial Position. At December 31, 2019, the $11 million of cash equivalents was included in Other investments 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 and 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 classified as NAV assets. These funds primarily invest in private equity partnerships, as well as real estate and private debt. 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 $192 million and $151 million as of September 30, 2020 and December 31, 2019, respectively. 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: Three Months Ended September 30, 2020 Three Months Ended September 30, 2019 Natural Gas Electricity Other Total Natural Gas Electricity Other Total (In millions) Net Assets (Liabilities) as of June 30 $ 20 $ 16 $ 10 $ 46 $ (10) $ 10 $ 9 $ 9 Transfers from Level 3 into Level 2 (1) — — (1) — — — — Total gains (losses) Included in earnings (80) 37 1 (42) (35) 37 — 2 Recorded in Regulatory liabilities — — 9 9 — — (3) (3) Purchases, issuances, and settlements Settlements 22 (48) (13) (39) 4 (39) (1) (36) Net Assets (Liabilities) as of September 30 $ (39) $ 5 $ 7 $ (27) $ (41) $ 8 $ 5 $ (28) Total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at September 30, 2020 and 2019 (a) $ (57) $ 11 $ (1) $ (47) $ (36) $ 15 $ (1) $ (22) _______________________________________ (a) Amounts are reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations. Nine Months Ended September 30, 2020 Nine Months Ended September 30, 2019 Natural Gas Electricity Other Total Natural Gas Electricity Other Total (In millions) Net Assets (Liabilities) as of December 31 $ (15) $ 16 $ 3 $ 4 $ (49) $ (2) $ 7 $ (44) Transfers from Level 3 into Level 2 (5) — — (5) — — — — Total gains (losses) Included in earnings (44) 90 (7) 39 (4) 47 (1) 42 Recorded in Regulatory liabilities — — 21 21 — — 3 3 Purchases, issuances, and settlements Settlements 25 (101) (10) (86) 12 (37) (4) (29) Net Assets (Liabilities) as of September 30 $ (39) $ 5 $ 7 $ (27) $ (41) $ 8 $ 5 $ (28) Total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at September 30, 2020 and 2019 (a) $ (20) $ 53 $ (17) $ 16 $ (20) $ 32 $ (6) $ 6 _______________________________________ (a) Amounts are reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — 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: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Net Assets as of beginning of period $ 10 $ 9 $ 3 $ 6 Change in fair value recorded in Regulatory liabilities 9 (3) 21 3 Purchases, issuances, and settlements Settlements (12) (1) (17) (4) Net Assets as of September 30 $ 7 $ 5 $ 7 $ 5 The amount of total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets held at September 30, 2020 and 2019 and reflected in DTE Electric's Consolidated Statements of Financial Position $ — $ (1) $ 7 $ 5 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 three and nine months ended September 30, 2020 and 2019. The following tables present the unobservable inputs related to DTE Energy's Level 3 assets and liabilities: September 30, 2020 Commodity Contracts Derivative Assets Derivative Liabilities Valuation Techniques Unobservable Input Range Weighted Average (In millions) Natural Gas $ 42 $ (81) Discounted Cash Flow Forward basis price (per MMBtu) $ (1.10) — $ 2.30 /MMBtu $ (0.06) /MMBtu Electricity $ 34 $ (29) Discounted Cash Flow Forward basis price (per MWh) $ (9) — $ 6 /MWh $ (1) /MWh December 31, 2019 Commodity Contracts Derivative Assets Derivative Liabilities Valuation Techniques Unobservable Input Range Weighted Average (In millions) Natural Gas $ 74 $ (89) Discounted Cash Flow Forward basis price (per MMBtu) $ (1.78) — $ 5.78 /MMBtu $ (0.09) /MMBtu Electricity $ 83 $ (67) Discounted Cash Flow Forward basis price (per MWh) $ (10) — $ 6 /MWh $ — /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: September 30, 2020 December 31, 2019 Carrying Fair Value Carrying Fair Value Amount Level 1 Level 2 Level 3 Amount Level 1 Level 2 Level 3 (In millions) Notes receivable — Other (a) , excluding lessor finance leases $ 112 $ — $ — $ 112 $ 184 $ — $ — $ 184 Short-term borrowings $ 988 $ — $ 988 $ — $ 828 $ — $ 828 $ — Notes payable — Other (b) $ 19 $ — $ — $ 19 $ 25 $ — $ — $ 25 Long-term debt (c) $ 18,660 $ 2,398 $ 17,213 $ 1,406 $ 16,606 $ 2,572 $ 14,207 $ 1,252 _______________________________________ (a) Current portion included in Current Assets — Other on DTE Energy's Consolidated Statements of Financial Position. (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, unamortized debt discounts, and issuance costs. Excludes finance lease obligations. The following table presents the carrying amount and fair value of financial instruments for DTE Electric: September 30, 2020 December 31, 2019 Carrying Fair Value Carrying Fair Value Amount Level 1 Level 2 Level 3 Amount Level 1 Level 2 Level 3 (In millions) Notes receivable — Other (a) $ 18 $ — $ — $ 18 $ 9 $ — $ — $ 9 Short-term borrowings — affiliates $ 104 $ — $ — $ 104 $ 97 $ — $ — $ 97 Short-term borrowings — other $ 200 $ — $ 200 $ — $ 354 $ — $ 354 $ — Notes payable — Other (b) $ 17 $ — $ — $ 17 $ 21 $ — $ — $ 21 Long-term debt (c) $ 8,235 $ — $ 9,565 $ 194 $ 7,180 $ — $ 7,916 $ 173 _______________________________________ (a) Included in Current Assets — Other and 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, unamortized debt discounts, and issuance costs. Excludes finance lease obligations. For further fair value information on financial and derivative instruments, see Note 9 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. The following table summarizes DTE Electric's fair value of the nuclear decommissioning trust fund assets: September 30, 2020 December 31, 2019 (In millions) Fermi 2 $ 1,652 $ 1,650 Fermi 1 3 3 Low-level radioactive waste 9 8 $ 1,664 $ 1,661 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: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Realized gains $ 38 $ 15 $ 172 $ 43 Realized losses $ (11) $ (8) $ (103) $ (25) Proceeds from sale of securities $ 816 $ 198 $ 2,054 $ 594 Realized gains and losses from the sale of securities and unrealized gains and losses incurred by the Fermi 2 trust are recorded to the Regulatory asset and 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: September 30, 2020 December 31, 2019 Fair Unrealized Unrealized Fair Unrealized Unrealized (In millions) Equity securities $ 1,013 $ 325 $ (28) $ 1,046 $ 396 $ (39) Fixed income securities 527 16 (1) 538 24 (1) Private equity and other 78 — — 43 — — Cash equivalents 46 — — 34 — — $ 1,664 $ 341 $ (29) $ 1,661 $ 420 $ (40) The following table summarizes the fair value of the fixed income securities held in nuclear decommissioning trust funds by contractual maturity: September 30, 2020 (In millions) Due within one year $ 92 Due after one through five years 82 Due after five through ten years 79 Due after ten years 194 $ 447 Fixed income securities held in nuclear decommissioning trust funds include $80 million of non-publicly traded commingled funds that do not have a contractual maturity date. Other Securities At September 30, 2020 and December 31, 2019, the Registrants' securities included in Other investments on the Consolidated Statements of Financial Position were comprised primarily of investments within DTE Energy's rabbi trust. The rabbi trust was established to fund certain non-qualified pension benefits, and therefore changes in market value 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. The following table summarizes DTE Energy's gains (losses) related to the trust: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Gains (losses) related to equity securities $ 2 $ 1 $ (4) $ 18 Gains (losses) related to fixed income securities — 2 (3) 9 $ 2 $ 3 $ (7) $ 27 |
Financial and Other Derivative
Financial and Other Derivative Instruments | 9 Months Ended |
Sep. 30, 2020 | |
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, certain 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 2023. 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. Gas Storage and Pipelines — This segment is primarily engaged in services related to the gathering, transportation, and storage of natural gas. Primarily fixed-priced contracts are used in the marketing and management of transportation and storage services. Generally, these contracts are not derivatives and are therefore accounted for under the accrual method. Power and Industrial Projects — This segment manages and operates energy and pulverized coal projects, a coke battery, reduced emissions fuel projects, renewable gas recovery, and power generation assets. Primarily fixed-price contracts are used in the marketing and management of the segment assets. These contracts 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 September 30, 2020 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: September 30, 2020 December 31, 2019 Derivative Derivative Liabilities Derivative Derivative Liabilities (In millions) Derivatives designated as hedging instruments Foreign currency exchange contracts $ — $ (1) $ — $ — Derivatives not designated as hedging instruments Commodity contracts Natural gas $ 240 $ (265) $ 355 $ (351) Electricity 137 (126) 306 (298) Environmental & Other 201 (171) 113 (121) Foreign currency exchange contracts 2 (1) 1 — Total derivatives not designated as hedging instruments $ 580 $ (563) $ 775 $ (770) Current $ 444 $ (421) $ 646 $ (596) Noncurrent 136 (143) 129 (174) Total derivatives $ 580 $ (564) $ 775 $ (770) The following table presents the fair value of derivative instruments for DTE Electric: September 30, 2020 December 31, 2019 (In millions) FTRs — Other current assets $ 7 $ 3 Total derivatives not designated as hedging instruments $ 7 $ 3 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 issued letters of credit of $5 million and $6 million outstanding at September 30, 2020 and December 31, 2019, respectively, 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 $1 million and $4 million at September 30, 2020 and December 31, 2019, respectively. 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: September 30, 2020 December 31, 2019 (In millions) Cash collateral netted against Derivative assets $ (26) $ — Cash collateral recorded in Accounts receivable (a) 12 13 Cash collateral recorded in Accounts payable (a) (2) (3) Total net cash collateral posted (received) $ (16) $ 10 _______________________________________ (a) Amounts are recorded net by counterparty. The following table presents the netting offsets of Derivative assets and liabilities for DTE Energy: September 30, 2020 December 31, 2019 Gross Amounts of Recognized Assets (Liabilities) Gross Amounts Offset in the Consolidated Statements of Financial Position Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position Gross Amounts of Recognized Assets (Liabilities) Gross Amounts Offset in the Consolidated Statements of Financial Position Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position (In millions) Derivative assets Commodity contracts Natural gas $ 240 $ (194) $ 46 $ 355 $ (266) $ 89 Electricity 137 (106) 31 306 (225) 81 Environmental & Other 201 (186) 15 113 (110) 3 Foreign currency exchange contracts 2 — 2 1 — 1 Total derivative assets $ 580 $ (486) $ 94 $ 775 $ (601) $ 174 Derivative liabilities Commodity contracts Natural gas $ (265) $ 185 $ (80) $ (351) $ 266 $ (85) Electricity (126) 104 (22) (298) 225 (73) Environmental & Other (171) 171 — (121) 110 (11) Foreign currency exchange contracts (2) — (2) — — — Total derivative liabilities $ (564) $ 460 $ (104) $ (770) $ 601 $ (169) 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: September 30, 2020 December 31, 2019 Derivative Assets Derivative Liabilities Derivative Assets Derivative Liabilities Current Noncurrent Current Noncurrent Current Noncurrent Current Noncurrent (In millions) Total fair value of derivatives $ 444 $ 136 $ (421) $ (143) $ 646 $ 129 $ (596) $ (174) Counterparty netting (361) (99) 361 99 (513) (88) 513 88 Collateral adjustment (18) (8) — — — — — — Total derivatives as reported $ 65 $ 29 $ (60) $ (44) $ 133 $ 41 $ (83) $ (86) 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 Derivatives Gain (Loss) Recognized in Income on Derivatives for the Three Months Ended September 30, Gain (Loss) Recognized in Income on Derivatives for the Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Commodity contracts Natural gas Operating Revenues — Non-utility operations $ (27) $ (5) $ (63) $ 4 Natural gas Fuel, purchased power, and gas — non-utility (51) (47) 28 (7) Electricity Operating Revenues — Non-utility operations 33 54 75 21 Environmental & Other Operating Revenues — Non-utility operations 2 (11) (40) (11) Foreign currency exchange contracts Operating Revenues — Non-utility operations (2) 1 — (2) Total $ (45) $ (8) $ — $ 5 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, and gas — non-utility. The following represents the cumulative gross volume of DTE Energy's derivative contracts outstanding as of September 30, 2020: Commodity Number of Units Natural gas (MMBtu) 1,739,656,507 Electricity (MWh) 28,258,929 Foreign currency exchange (CAD) 154,336,963 Renewable Energy Certificates (MWh) 7,893,076 Carbon emissions (Metric Ton) 16,451,411 Various subsidiaries of DTE Energy have entered into 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, environmental, and coal) and the provisions and maturities of the underlying transactions. As of September 30, 2020, 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 $377 million. As of September 30, 2020, DTE Energy had $472 million of derivatives in net liability positions, for which hard triggers exist. There is no 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 $445 million. The net remaining amount of $27 million is derived from the $377 million noted above. |
Long-Term Debt
Long-Term Debt | 9 Months Ended |
Sep. 30, 2020 | |
Debt Disclosure [Abstract] | |
Long-Term Debt | LONG-TERM DEBT Debt Issuances In 2020, the following debt was issued: Company Month Type Interest Rate Maturity Date Amount (In millions) DTE Electric February Mortgage Bonds (a) 2.25% 2030 $ 600 DTE Electric February Mortgage Bonds (a) 2.95% 2050 500 DTE Electric April Mortgage Bonds (b) 2.63% 2031 600 DTE Energy August Senior Notes (c) 1.05% 2025 800 DTE Gas August Mortgage Bonds (d) 2.35% 2030 125 DTE Gas August Mortgage Bonds (d) 3.20% 2050 125 $ 2,750 _______________________________________ (a) Proceeds used for the repayment of $300 million of DTE Electric's 2010 Series A 4.89% Senior Notes due 2020, repayment of short-term borrowings, capital expenditures, and for other general corporate purposes. (b) Proceeds used for the repayment of $300 million of DTE Electric's 2010 Series B 3.45% Senior Notes due 2020, repayment of $32 million of DTE Electric's 2008 Series KT Variable Rate Senior Notes due 2020, repayment of short-term borrowings, capital expenditures, and for other general corporate purposes. (c) Proceeds used for the repayment of short-term borrowings and for general corporate purposes. (d) Proceeds used for the repayment of $50 million of DTE Gas's 2008 Series I 6.36% Senior Notes due 2020 and for general corporate purposes, including capital expenditures. In March 2020, DTE Energy entered into a $200 million unsecured term loan with a maturity date of March 2022 and terms consistent with DTE Energy’s unsecured revolving credit agreements. The purpose of the loan was to enhance liquidity and reduce reliance on the commercial paper market. The loan was subject to terminate if no amounts were drawn by August 27, 2020. No amounts were drawn, therefore the loan terminated per the agreement. In October 2020, DTE Energy issued $230 million of 4.375% Junior Subordinated Debentures due October 15, 2080. Proceeds have been used for the redemption of DTE Energy's $200 million 2012 Series C 5.25% Junior Subordinated Debentures due December 1, 2062. Remaining proceeds will be used for general corporate purposes. In October 2020, DTE Energy also issued $750 million of 0.55% Senior Notes due November 1, 2022. Proceeds have been used for the repayment of DTE Energy's $500 million unsecured term loan expiring March 2021 and DTE Energy's $167 million unsecured term loan expiring June 2021. Remaining proceeds will be used for general corporate purposes. Refer to Note 11 to the Consolidated Financial Statements, "Short-term Credit Arrangements and Borrowings", for additional information regarding the term loans. Debt Redemptions In 2020, the following debt was redeemed: Company Month Type Interest Rate Maturity Date Amount (In millions) DTE Electric March Senior Notes 4.89% 2020 $ 300 DTE Electric July Senior Notes 5.63% 2020 32 DTE Electric July Senior Notes 3.45% 2020 300 DTE Gas September Senior Notes 6.36% 2020 50 $ 682 As noted above, on October 22, 2020, DTE Energy also optionally redeemed its $200 million 2012 Series C 5.25% Junior Subordinated Debentures originally due December 1, 2062. |
Short-Term Credit Arrangements
Short-Term Credit Arrangements and Borrowings | 9 Months Ended |
Sep. 30, 2020 | |
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. DTE Energy also has other facilities to support letter of credit issuance. During 2020, the Registrants have entered into a series of unsecured term loans to raise additional liquidity, including terms consistent with the unsecured revolving credit agreements. In March 2020, DTE Energy entered into a $500 million unsecured term loan expiring in March 2021, of which the full $500 million was drawn. In April 2020, DTE Electric entered into a $200 million unsecured term loan, of which the full $200 million was drawn, and a $200 million unsecured term loan, of which no amount has been drawn. Additionally, in April 2020, DTE Gas entered into a $100 million unsecured term loan, of which the full $100 million was drawn. All three loans expire in April 2021. In May 2020, DTE Lake Erie Generation, Inc., an indirect wholly-owned subsidiary of DTE Energy, entered into a C$110 million unsecured revolving credit agreement to fund construction of on-site electric generation and related infrastructure projects at a Canadian integrated steel manufacturing facility in Ontario, Canada. The revolving credit agreement is guaranteed by DTE Energy and there was C$28 million outstanding as of September 30, 2020. The revolving credit agreement expires in May 2023 and has terms consistent with DTE Energy's unsecured revolving credit agreements. In June 2020, DTE Energy entered into a $167 million unsecured term loan expiring in June 2021, of which the full amount was drawn in September 2020. The unsecured revolving credit agreements require DTE Energy, DTE Electric, and DTE Gas to maintain a total funded debt to capitalization ratio of no more than 0.65 to 1. 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 September 30, 2020, the total funded debt to total capitalization ratios for DTE Energy, DTE Electric, and DTE Gas were 0.60 to 1, 0.52 to 1, and 0.49 to 1, respectively, and were in compliance with this financial covenant. The availability under these facilities as of September 30, 2020 is shown in the following table: DTE Energy DTE Electric DTE Gas Total (In millions) Unsecured letter of credit facility, expiring in February 2021 $ 150 $ — $ — $ 150 Unsecured letter of credit facility, expiring in August 2021 110 — — 110 Unsecured term loan, expiring in March 2021 500 — — 500 Unsecured term loans, expiring in April 2021 — 400 100 500 Unsecured term loan, expiring in June 2021 167 — — 167 Unsecured Canadian revolving credit facility, expiring May 2023 83 — — 83 Unsecured revolving credit facility, expiring April 2024 1,500 500 300 2,300 2,510 900 400 3,810 Amounts outstanding at September 30, 2020 Letters of credit 212 — — 212 Unsecured term loan 667 200 100 967 Revolver borrowings 21 — — 21 900 200 100 1,200 Net availability at September 30, 2020 $ 1,610 $ 700 $ 300 $ 2,610 DTE Energy has $59 million of other outstanding letters of credit which are used for various corporate purposes and are not included in the facilities described above. These letters of credit include a $50 million uncommitted letter of credit facility entered into by DTE Energy in July 2020, of which the full amount has been drawn. The facility expires in July 2021 with an automatic renewal provision. In October 2020, DTE Energy repaid several of its unsecured term loans. As noted in Note 10 to the Consolidated Financial Statements, "Long-term Debt", DTE Energy used proceeds from the issuance of long-term debt to repay its $500 million term loan expiring March 2021 and $167 million term loan expiring June 2021. In October 2020, DTE Gas also repaid its $100 million term loan expiring April 2021. In conjunction with maintaining certain exchange traded risk management positions, DTE Energy may be required to post collateral with its clearing agents. DTE Energy has demand financing agreements with its clearing agents, including an agreement for up to $100 million with an indefinite term and an agreement for up to $150 million currently contracted through 2022 and subject to renewal. The $100 million agreement, as amended, also allows for up to $50 million of additional margin financing provided that DTE Energy posts a letter of credit for the incremental amount. Both agreements allow the right of setoff with posted collateral. At September 30, 2020, the capacity under the facilities was $300 million. The amount outstanding under the agreements was $43 million and $114 million at September 30, 2020 and December 31, 2019, respectively, and was fully offset by the posted collateral. |
Leases
Leases | 9 Months Ended |
Sep. 30, 2020 | |
Leases [Abstract] | |
Leases | LEASES Lessor During the second quarter 2020, DTE Energy executed a sale of membership interests in the REF business accounted for as a finance lease arrangement with a term of less than 2 years, resulting in a net investment in finances leases of $8 million and selling profit of $11 million. During the first quarter 2020, DTE Energy completed construction of and began operating certain energy infrastructure assets for a large industrial customer under a long-term agreement, where the assets will transfer to the customer at the end of the contract term in 2040. DTE Energy has accounted for a portion of the agreement as a finance lease arrangement, recognizing a net investment of $133 million. The components of DTE Energy’s net investment in finance leases for remaining periods were as follows: DTE Energy September 30, 2020 (In millions) 2020 $ 8 2021 24 2022 20 2023 19 2024 19 2025 and Thereafter 273 Total minimum future lease receipts 363 Residual value of leased pipeline 19 Less unearned income 201 Net investment in finance lease 181 Less current portion 10 $ 171 Interest income recognized under finance leases was $4 million and $2 million for the three months ended September 30, 2020 and 2019, respectively, and $12 million and $4 million for the nine months ended September 30, 2020 and 2019, respectively. DTE Energy’s lease income associated with operating leases was as follows: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Fixed payments $ 17 $ 17 $ 50 $ 51 Variable payments 43 40 82 92 $ 60 $ 57 $ 132 $ 143 |
Leases | LEASES Lessor During the second quarter 2020, DTE Energy executed a sale of membership interests in the REF business accounted for as a finance lease arrangement with a term of less than 2 years, resulting in a net investment in finances leases of $8 million and selling profit of $11 million. During the first quarter 2020, DTE Energy completed construction of and began operating certain energy infrastructure assets for a large industrial customer under a long-term agreement, where the assets will transfer to the customer at the end of the contract term in 2040. DTE Energy has accounted for a portion of the agreement as a finance lease arrangement, recognizing a net investment of $133 million. The components of DTE Energy’s net investment in finance leases for remaining periods were as follows: DTE Energy September 30, 2020 (In millions) 2020 $ 8 2021 24 2022 20 2023 19 2024 19 2025 and Thereafter 273 Total minimum future lease receipts 363 Residual value of leased pipeline 19 Less unearned income 201 Net investment in finance lease 181 Less current portion 10 $ 171 Interest income recognized under finance leases was $4 million and $2 million for the three months ended September 30, 2020 and 2019, respectively, and $12 million and $4 million for the nine months ended September 30, 2020 and 2019, respectively. DTE Energy’s lease income associated with operating leases was as follows: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Fixed payments $ 17 $ 17 $ 50 $ 51 Variable payments 43 40 82 92 $ 60 $ 57 $ 132 $ 143 |
Leases | LEASES Lessor During the second quarter 2020, DTE Energy executed a sale of membership interests in the REF business accounted for as a finance lease arrangement with a term of less than 2 years, resulting in a net investment in finances leases of $8 million and selling profit of $11 million. During the first quarter 2020, DTE Energy completed construction of and began operating certain energy infrastructure assets for a large industrial customer under a long-term agreement, where the assets will transfer to the customer at the end of the contract term in 2040. DTE Energy has accounted for a portion of the agreement as a finance lease arrangement, recognizing a net investment of $133 million. The components of DTE Energy’s net investment in finance leases for remaining periods were as follows: DTE Energy September 30, 2020 (In millions) 2020 $ 8 2021 24 2022 20 2023 19 2024 19 2025 and Thereafter 273 Total minimum future lease receipts 363 Residual value of leased pipeline 19 Less unearned income 201 Net investment in finance lease 181 Less current portion 10 $ 171 Interest income recognized under finance leases was $4 million and $2 million for the three months ended September 30, 2020 and 2019, respectively, and $12 million and $4 million for the nine months ended September 30, 2020 and 2019, respectively. DTE Energy’s lease income associated with operating leases was as follows: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Fixed payments $ 17 $ 17 $ 50 $ 51 Variable payments 43 40 82 92 $ 60 $ 57 $ 132 $ 143 |
Commitments and Contingencies
Commitments and Contingencies | 9 Months Ended |
Sep. 30, 2020 | |
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 SO 2 and NO X . 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 SO 2 , NO X , mercury, and other emissions. Additional rulemakings may occur over the next few years which could require additional controls for SO 2 , NO X , and other hazardous air pollutants. The EPA proposed revised air quality standards for ground level ozone in November 2014 and specifically requested comments on the form and level of the ozone standards. The standards were finalized in October 2015. The State of Michigan recommended to the EPA in October 2016 which areas of the state are not attaining the new standard. On April 30, 2018, the EPA finalized the State of Michigan's recommended marginal non-attainment designation for southeast Michigan. The State is required to develop and implement a plan to address the southeast Michigan ozone non-attainment area by 2021. The Registrants cannot predict the scope and associated financial impact of the State's plan to address the ozone non-attainment area at this time. In July 2009, the Registrants received a NOV/FOV from the EPA alleging, among other things, that five DTE Electric power plants violated New Source Performance standards, Prevention of Significant Deterioration requirements, and operating permit requirements under the Clean Air Act. In June 2010, the EPA issued a NOV/FOV making similar allegations related to a project and outage at Unit 2 of the Monroe Power Plant. In March 2013, DTE Energy received a supplemental NOV from the EPA relating to the July 2009 NOV/FOV. The supplemental NOV alleged additional violations relating to the New Source Review provisions under the Clean Air Act, among other things. In August 2010, the U.S. Department of Justice, at the request of the EPA, brought a civil suit in the U.S. District Court for the Eastern District of Michigan against DTE Energy and DTE Electric, related to the June 2010 NOV/FOV and the outage work performed at Unit 2 of the Monroe Power Plant. In August 2011, the U.S. District Court judge granted DTE Energy's motion for summary judgment in the civil case, dismissing the case and entering judgment in favor of DTE Energy and DTE Electric. In October 2011, the EPA filed a Notice of Appeal to the Court of Appeals for the Sixth Circuit. In March 2013, the Court of Appeals remanded the case to the U.S. District Court for review of the procedural component of the New Source Review notification requirements. In September 2013, the EPA filed a motion seeking leave to amend their complaint regarding the June 2010 NOV/FOV adding additional claims related to outage work performed at the Trenton Channel and Belle River Power Plants as well as additional claims related to work performed at the Monroe Power Plant. In March 2014, the U.S. District Court judge again granted DTE Energy's motion for summary judgment dismissing the civil case related to Monroe Unit 2. In April 2014, the U.S. District Court judge granted motions filed by the EPA and the Sierra Club to amend their New Source Review complaint adding additional claims for Monroe Units 1, 2, and 3, Belle River Units 1 and 2, and Trenton Channel Unit 9. In October 2014, the EPA and the U.S. Department of Justice filed a notice of appeal of the U.S. District Court judge's dismissal of the Monroe Unit 2 case. The amended New Source Review claims were all stayed pending resolution of the appeal by the Court of Appeals for the Sixth Circuit. On January 10, 2017, a divided panel of the Court reversed the decision of the U.S. District Court. On May 8, 2017, DTE Energy and DTE Electric filed a motion to stay the mandate pending filing of a petition for writ of certiorari with the U.S. Supreme Court. The Sixth Circuit granted the motion on May 16, 2017, staying the claims in the U.S. District Court until the U.S. Supreme Court disposes of the case. DTE Electric and DTE Energy filed a petition for writ of certiorari on July 31, 2017. On December 11, 2017, the U.S. Supreme Court denied certiorari. As a result of the Supreme Court electing not to review the matter, the case was sent back to the U.S. District Court for further proceedings and on June 14, 2018 the case was stayed pending settlement negotiations. In May 2020, the Registrants, the United States, and the Sierra Club reached a settlement, which was memorialized in the form of a Consent Decree and a separate settlement agreement between the Registrants and Sierra Club. The Consent Decree was submitted and received by the U.S. District Court and the public comment period ended on June 14, 2020. The Consent Decree was entered with the U.S. District Court with an effective date of July 23, 2020 and DTE Electric subsequently paid a civil penalty of $2 million. As of September 30, 2020, an additional $5 million remains accrued for the settlement. The U.S. District Court is still reviewing the Sierra Club Consent Decree and a final decision is expected in the fourth quarter of 2020. The Registrants do not expect the final settlement to have a material financial impact. The Registrants believe that the plants and generating units identified by the EPA and the Sierra Club have complied with all applicable federal environmental regulations. DTE Electric is required to retire, repower, refuel, or retrofit units at four power plants by the dates set forth in the Consent Decree and implement a supplemental environmental project. The Registrants do not expect the outcome of this matter to have a material impact on their Consolidated Financial Statements. The EPA has implemented regulatory actions under the Clean Air Act to address emissions of GHGs from the utility sector and other sectors of the economy. Among these actions, in 2015 the EPA finalized performance standards for emissions of carbon dioxide from new and existing fossil-fuel fired EGUs. The performance standards for existing EGUs, known as the EPA Clean Power Plan, were challenged by petitioners and stayed by the U.S. Supreme Court in February 2016 pending final review by the courts. On October 10, 2017, the EPA, under a new administration, proposed to rescind the Clean Power Plan, and in August 2018, the EPA proposed revised emission guidelines for GHGs from existing EGUs. On June 19, 2019, the EPA Administrator officially repealed the Clean Power Plan and finalized its replacement, named the ACE rule. The ACE Rule requires the state of Michigan to submit a plan in 2022 that includes GHG standards for existing coal-fired power plant units in Michigan. These final rules do not impact DTE Energy's commitments for its electric utility operations to reduce carbon emissions 32% by the early 2020s, 50% by 2030, and 80% by 2040 from the 2005 carbon emissions levels, or its goal of net zero emissions for its electric utility operations by 2050. In addition to the GHG standards for existing EGUs, in December 2018, the EPA issued proposed revisions to the carbon dioxide performance standards for new, modified, or reconstructed fossil-fuel fired EGUs. The carbon standards for new sources are not expected to have a material impact on DTE Electric, since DTE Electric has no plans to build new coal-fired generation and any potential new gas generation will be able to comply with the standards. 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. 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 through 2025, subject to the results of future rulemakings. Water — In response to an EPA regulation, DTE Electric was required to examine alternatives for reducing the environmental impacts of the cooling water intake structures at several of its facilities. Based on the results of completed studies and expected future studies, DTE Electric may be required to install technologies to reduce the impacts of the water intake structures. A final rule became effective in October 2014. The final rule requires 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 initiated the process of completing the required studies. Final compliance for the installation of any required technology will be determined by the state on a case by case, site specific basis. DTE Electric is currently evaluating the compliance options and working with the State of Michigan on evaluating whether any controls are needed. These evaluations/studies may require modifications to some existing intake structures. It is not possible to quantify the impact of this rulemaking at this time. 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. Cleanup of one of the MGP sites is complete, and the site is closed. The investigations have revealed contamination related to the by-products of gas manufacturing at each MGP site. 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 September 30, 2020 and December 31, 2019, DTE Electric had $6 million and $8 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 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 was revised in October 2016, July 2018, and September 2020. 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 owns and operates three permitted engineered coal ash storage facilities to dispose of coal ash from coal-fired power plants and operates a number of smaller impoundments at its power plants subject to certain provisions in the CCR rule. At certain facilities, the rule currently requires ongoing sampling and testing of monitoring wells, compliance with groundwater standards, and the closure of basins at the end of the useful life of the associated power plant. DTE Electric has estimated the impact of the current rule to be $629 million of capital expenditures. On September 28, 2020, the CCR rule "A Holistic Approach to Closure Part A: Deadline to Initiate Closure and Enhancing Public Access to Information" became effective and establishes April 11, 2021 as the new deadline for all unlined impoundments (including units previously classified as "clay-lined") to initiate closure. Additionally, the rule amends certain reporting requirements and CCR website requirements. On March 3, 2020, an additional proposed revision to the CCR Rule was published in the Federal Register that provides a process to determine if certain unlined impoundments consist of an alternative liner system that may be as protective as the current liners specified in the CCR rule, and therefore may continue to operate. DTE Electric is currently evaluating both the final September 28, 2020 rule and the proposed CCR rule, including the alternative liner system demonstration for our clay lined impoundments, to determine any changes to DTE Electric's plans in the operation and closure of coal ash impoundments. At the State level, legislation was signed by the Governor in December 2018 and provides for further regulation of the CCR program in Michigan. Additionally, the bill 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. In November 2015, the EPA finalized the ELG Rule for the steam electric power generating industry which requires additional controls to be installed between 2018 and 2023. 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 has issued a NPDES permit for the Belle River Power Plant establishing a compliance deadline of December 31, 2021. No new permits that would require ELG compliance have been issued for other facilities, consequently no compliance timelines have been established. On April 12, 2017, the EPA granted a petition for reconsideration of the 2015 ELG Rule. The EPA also signed an administrative stay of the ELG Rule’s compliance deadlines for fly ash transport water, bottom ash transport water, and flue gas desulfurization (FGD) wastewater, among others. On June 6, 2017, the EPA published in the Federal Register a proposed rule (Postponement Rule) to postpone certain applicable deadlines within the 2015 ELG rule. The Postponement Rule was published on September 18, 2017. The Postponement Rule nullified the administrative stay but also extended the earliest compliance deadlines for only FGD wastewater and bottom ash transport water until November 1, 2020 in order for the EPA to propose and finalize a new ruling. On August 31, 2020, the EPA released the final version of the ELG Reconsideration Rule which revised the regulations from the 2015 ELG rule. The Reconsideration Rule revises requirements for two specific waste streams produced by steam electric power plants: FGD wastewater and bottom ash transport water. The Reconsideration Rule also provides additional compliance opportunities by finalizing low utilization and cessation of coal burning subcategories. The Reconsideration Rule provides 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. DTE Electric is currently evaluating compliance strategies, technologies and system designs for both FGD wastewater and bottom ash transport water system to achieve compliance with the final rule. DTE Gas Air — In June 2020, DTE Energy expanded its net zero goal to include its gas utility operations by committing to reduce greenhouse gas emissions to net zero by 2050 from procurement of natural gas through delivery. In addition, DTE Gas committed to partner with customers to help them reduce GHG emissions through energy efficiency and participation in a voluntary emissions offset program. Further details of the DTE Gas net zero goal will emerge as the company evaluates strategies and technologies for reducing emissions. 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 of the MGP sites is complete, and the sites are closed. DTE Gas has also completed partial closure of four 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 September 30, 2020 and December 31, 2019, DTE Gas had $24 million and $25 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. 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 a finding of violation to 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. EES Coke evaluated the EPA's alleged violations and believes that the permits approved by EGLE complied with the Clean Air Act. Discussions with the EPA are ongoing. At the present time, DTE Energy cannot predict the outcome or financial impact of this FOV. Other In 2010, the EPA finalized a new one-hour SO 2 ambient air quality standard that requires states to submit plans and associated timelines for non-attainment areas that demonstrate attainment with the new SO 2 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 SO 2 and modeled concentrations exceeding the National Ambient Air Quality Standards for SO 2 . Phase 3 addresses smaller sources of SO 2 with modeled or monitored exceedances of the new SO 2 standard. Michigan's Phase 1 non-attainment area includes DTE Energy facilities in southwest Detroit and areas of Wayne County. Modeling runs by EGLE suggest that emission reductions may be required by significant sources of SO 2 emissions in these areas, including DTE Electric power plants and DTE Energy's Michigan coke battery facility. As part of the SIP process, DTE Energy has worked with EGLE to develop air permits reflecting significant SO 2 emission reductions that, in combination with other non-DTE Energy sources' emission reduction strategies, will help the state attain the standard and sustain its attainment. Since several non-DTE Energy sources are also part of the proposed compliance plan, DTE Energy is unable to determine the full impact of the final required emissions reductions on DTE's facilities at this time. Michigan's Phase 2 non-attainment area includes DTE Electric facilities in St. Clair County. SIP submittal and EPA approval describing the control strategy and timeline for demonstrating compliance with the new SO 2 standard is the next step in the process and is expected to be completed in 2020. DTE Energy is unable to determine the full impact of the SIP strategy. Synthetic Fuel Guarantees DTE Energy discontinued the operations of its synthetic fuel production facilities throughout the United States as of December 31, 2007. DTE Energy provided certain guarantees and indemnities in conjunction with the sales of interests in its synfuel facilities. The guarantees cover potential commercial, environmental, oil price, 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 September 30, 2020 was approximately $400 million. Payment under these guarantees is considered remote. REF Guarantees DTE Energy has provided certain guarantees and indemnities in conjunction with the sales of interests in or lease of its 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 September 30, 2020 was $543 million. Payments under these guarantees are considered remote. NEXUS Guarantees NEXUS is party to certain 15-year capacity agreements for the transportation of natural gas with DTE Gas and Texas Eastern Transmission, LP, an unrelated third party. In conjunction with these agreements, DTE Energy provided certain guarantees on behalf of NEXUS to DTE Gas and Texas Eastern Transmission, LP, with maximum potential payments totaling $226 million and $360 million at September 30, 2020, respectively; each representing 50% of all payment obligations due and payable by NEXUS. Each guarantee terminates at the earlier of (i) such time as all of the guaranteed obligations have been fully performed, or (ii) two months following the end of the primary term of the capacity agreements in 2033. The amount of each guarantee decreases annually as payments are made by NEXUS to each of the aforementioned counterparties. NEXUS is also party to certain 15-year capacity agreements for the transportation of natural gas with Vector, an equity method investee of DTE Energy. Pursuant to the terms of those agreements, in October 2018, DTE Energy executed a guarantee agreement with Vector, with a maximum potential payment totaling $7 million at September 30, 2020, representing 50% of the first-year payment obligations due and payable by NEXUS. The guarantee terminates at the earlier of (i) such time as all of the guaranteed obligations have been fully performed or (ii) 15 years from the date DTE Energy entered into the guarantee. Should NEXUS fail to perform under the terms of these agreements, DTE Energy is required to perform on its behalf. 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. Finally, the Registrants may provide indirect guarantees for the indebtedness of others. DTE Energy’s guarantees are not individually material with maximum potential payments totaling $50 million at September 30, 2020. 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 September 30, 2020, DTE Energy had $125 million of performance bonds outstanding, including $69 million for DTE Electric. In the event that such 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. Vector Line of Credit In July 2019, DTE Energy, as lender, entered into a revolving term credit facility with Vector, as borrower, in the amount of C$70 million. The credit facility was executed in response to the passage of Canadian regulations requiring oil and gas pipelines to demonstrate their financial ability to respond to a catastrophic event and exists for the sole purpose of satisfying these regulations. Vector may only draw upon the facility if the funds are required to respond to a catastrophic event. The maximum potential payment under the line of credit at September 30, 2020 is $52 million. The funding of a loan under the terms of the credit facility is considered remote. Labor Contracts There are several bargaining units for DTE Energy subsidiaries' approximate 5,200 represented employees, including DTE Electric's approximate 2,800 represented employees. The majority of the represented employees are under contracts that expire in 2021 and 2022. Purchase Commitments Utility capital expenditures, expenditures for non-utility businesses, and contributions to equity method investees will be approximately $4.5 billion and $2.6 billion in 2020 for DTE Energy and DTE Electric, respectively. The Registrants have made certain commitments in connection with the estimated 2020 annual capital expenditures and contributions to equity method investees. Bankruptcies DTE Energy's Power and Industrial Projects segment holds ownership interests in, and operates, five generating plants that sell electric output from renewable sources under long-term power purchase agreements with PG&E. PG&E filed for Chapter 11 bankruptcy protection on January 29, 2019. PG&E emerged from Chapter 11 bankruptcy effective July 1, 2020. DTE's renewable power purchase agreements were assumed under PG&E's Reorganization Plan and payment has been received for all past due receivables related to these agreements. COVID-19 Pandemic DTE Energy is actively monitoring the impact of the COVID-19 pandemic on supply chains, markets, counterparties, and customers, and any related impacts on operating costs, customer demand, and recoverability of assets that could materially impact the Registrants' financial results. Impacts from the COVID-19 pandemic for the three and nine months ended September 30, 2020 include a reduction in DTE Electric sales volumes from commercial and industrial customers and an increase in residential customer sales volumes. This shift contributed to a net reduction in DTE Electric sales volumes for the three and nine months ended September 30, 2020, but the impact to earnings has been mitigated by favorable rate mix. Operation and maintenance expense has also been impacted by COVID-19, primarily at DTE Electric, due to higher costs for personal protective equipment and other health and safety related costs, including shift premiums and related expenses associated with the sequestration of certain employees critical to continued operations. For non-utility businesses, COVID-19 has primarily impacted the Power and Industrial Projects segment, contributing to lower production in the REF business and lower demand in the Steel business. These impacts were most significant in March and April 2020 when government orders to cease non-essential business activity resulted in temporary shut-down of certain operations. While these impacts have adversely affected Operating revenues and Other income from REF entities, Net income has not been significantly impacted due to related decreases in Operating expenses. Finally, as discussed in Note 2, "Significant Accounting Policies", the allowance for doubtful accounts was increased at our utilities due to additional risk relating to COVID-19. However, the impact of these increases has not been material. In consideration of the above factors and all other current and expected impacts to the Registrants' performance and cash flows resulting from the COVID-19 pandemic, there have been no material adjustments or reserves deemed necessary to the Consolidated Financial Statements as of September 30, 2020. The Registrants cannot predict the future impacts of the COVID-19 pandemic on the Consolidated Financial Statements, as developments involving COVID-19 and its related effects on economic and operating conditions remain highly uncertain. 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 6 and 9 to the Consolidated Financial Statements, "Regulatory Matters" and "Financial and Other Derivative Instruments," respectively. |
Retirement Benefits and Trustee
Retirement Benefits and Trusteed Assets | 9 Months Ended |
Sep. 30, 2020 | |
Retirement Benefits [Abstract] | |
Retirement Benefits and Trusteed Assets | RETIREMENT BENEFITS AND TRUSTEED ASSETS The following tables detail the components of net periodic benefit costs (credits) for pension benefits and other postretirement benefits for DTE Energy: Pension Benefits Other Postretirement Benefits Three Months Ended September 30, 2020 2019 2020 2019 (In millions) Service cost $ 25 $ 21 $ 7 $ 5 Interest cost 46 55 14 18 Expected return on plan assets (84) (82) (32) (30) Amortization of: Net actuarial loss 43 33 4 3 Prior service credit — — (5) (3) Settlements 2 — — — Net periodic benefit cost (credit) $ 32 $ 27 $ (12) $ (7) Pension Benefits Other Postretirement Benefits Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Service cost $ 74 $ 63 $ 20 $ 16 Interest cost 139 164 42 53 Expected return on plan assets (250) (244) (96) (92) Amortization of: Net actuarial loss 129 99 12 9 Prior service credit — — (15) (7) Settlements 2 — — — Net periodic benefit cost (credit) $ 94 $ 82 $ (37) $ (21) DTE Electric participates in various plans that provide pension and other postretirement benefits for DTE Energy and its affiliates. The plans are sponsored by DTE Energy's subsidiary, DTE Energy Corporate Services, 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 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. In addition, the service cost and non-service cost components are presented in Operation and maintenance in DTE Electric's Consolidated Statements of Operations. The same non-service cost components are presented in Other (Income) and Deductions — Non-operating retirement benefits, net in DTE Energy's Consolidated Statements of Operations. Plan participants of all plans are solely DTE Energy and affiliate participants. 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 capital expenditures and operating and maintenance expense were $28 million and $23 million for the three months ended September 30, 2020 and 2019, respectively, and $79 million and $68 million for the nine months ended September 30, 2020 and 2019, respectively. These amounts include recognized contractual termination benefit charges, curtailment gains, and settlement charges. The following tables detail the components of net periodic benefit costs (credits) for other postretirement benefits for DTE Electric: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) (In millions) Service cost $ 5 $ 4 $ 15 $ 12 Interest cost 11 13 32 40 Expected return on plan assets (21) (21) (65) (63) Amortization of: Net actuarial loss 2 1 8 3 Prior service credit (3) (1) (10) (5) Net periodic benefit credit $ (6) $ (4) $ (20) $ (13) Pension and Other Postretirement Contributions For the nine months ended September 30, 2020, DTE Energy made contributions of $84 million to its qualified pension plans, including $82 million of common stock and $2 million of cash contributions. Details of the contribution of common stock to the DTE Energy Company Affiliates Employee Benefit Plans Master Trust are as follows: Date Number of Shares Price per Share Amount (In millions) September 8, 2020 694,444 $ 118.08 $ 82 The above contribution was made on behalf of DTE Electric and DTE Gas, for which DTE Electric and DTE Gas paid DTE Energy cash consideration of $60 million and $22 million, respectively, in September 2020. DTE Energy is currently assessing whether any additional contributions will be made to its pension plans in 2020. If any further contributions are made, they are not expected to be material to the Consolidated Financial Statements. No contributions are anticipated for DTE Energy's postretirement benefit plans in 2020. |
Segment and Related Information
Segment and Related Information | 9 Months Ended |
Sep. 30, 2020 | |
Segment Reporting [Abstract] | |
Segment and Related Information | SEGMENT AND RELATED INFORMATION DTE Energy sets strategic goals, allocates resources, and evaluates performance based on the following structure: Electric segment consists principally of DTE Electric, which is engaged in the generation, purchase, distribution, and sale of electricity to approximately 2.2 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 1.3 million residential, commercial, and industrial customers throughout Michigan and the sale of storage and transportation capacity. Gas Storage and Pipelines is primarily engaged in services related to the gathering, transportation, and storage of natural gas. Power and Industrial Projects is comprised primarily of projects that deliver energy and utility-type products and services to industrial, commercial, and institutional customers, produce reduced emissions fuel, and sell electricity and pipeline-quality gas from renewable energy projects. Energy Trading consists of energy marketing and trading operations. Corporate and Other includes various holding company activities, holds certain non-utility debt, and holds energy-related investments. 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 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. Inter-segment billing for goods and services exchanged between segments is based upon tariffed or market-based prices of the provider and primarily consists of the sale of reduced emissions fuel, power sales, and natural gas sales in the following segments: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Electric $ 16 $ 16 $ 46 $ 43 Gas 4 3 12 8 Gas Storage and Pipelines 8 11 17 17 Power and Industrial Projects 134 160 308 462 Energy Trading 9 4 23 16 Corporate and Other 1 1 2 2 $ 172 $ 195 $ 408 $ 548 Financial data of DTE Energy's business segments follows: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Operating Revenues — Utility operations Electric $ 1,690 $ 1,520 $ 4,211 $ 3,945 Gas 173 155 964 1,043 Operating Revenues — Non-utility operations Electric 3 — 10 — Gas Storage and Pipelines 204 126 546 363 Power and Industrial Projects 324 406 850 1,196 Energy Trading 1,061 1,105 2,714 3,519 Corporate and Other 1 2 2 3 Reconciliation and Eliminations (172) (195) (408) (548) Total $ 3,284 $ 3,119 $ 8,889 $ 9,521 Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Net Income (Loss) Attributable to DTE Energy by Segment: Electric $ 398 $ 307 $ 675 $ 587 Gas (20) (38) 102 121 Gas Storage and Pipelines 104 60 246 158 Power and Industrial Projects 47 49 102 104 Energy Trading (28) (14) 5 12 Corporate and Other (25) (45) (37) (80) Net Income Attributable to DTE Energy Company $ 476 $ 319 $ 1,093 $ 902 |
Related Party Transactions
Related Party Transactions | 9 Months Ended |
Sep. 30, 2020 | |
Related Party Transactions [Abstract] | |
Related Party Transactions | RELATED PARTY TRANSACTIONS DTE Energy enters into related party transactions with certain equity method investees, primarily NEXUS. DTE Gas is party to a 15-year capacity lease agreement with NEXUS for the transportation of natural gas. Under the lease agreement, DTE Gas provides firm pipeline capacity in the DTE Gas system in order for NEXUS to provide service to its customers from an interconnect between NEXUS and DTE Gas. DTE Gas charges NEXUS a fixed daily pipeline reservation charge for this capacity. DTE Electric and DTE Gas are also party to respective 20-year and 15-year service agreements with NEXUS for the transportation of natural gas. Under the service agreements, NEXUS provides firm pipeline capacity to transport natural gas to DTE Electric and to service DTE Gas customers. DTE Electric and DTE Gas incur a firm daily pipeline reservation charge, which is recovered through the respective PSCR and GCR mechanisms. DTE Energy Trading also enters into related party transactions with NEXUS for the transportation of natural gas. The following table summarizes the amounts resulting from these transactions included in the Consolidated Statements of Operations: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Operating Revenues — Utility operations DTE Gas $ 8 $ 8 $ 24 $ 24 Fuel, purchased power, and gas — utility DTE Electric $ 2 $ 2 $ 6 $ 6 DTE Gas $ 2 $ 2 $ 14 $ 15 Fuel, purchased power, and gas — non-utility DTE Energy Trading $ 7 $ 2 $ 20 $ 5 Other related party transactions with equity method investees include transactions with Vector Pipeline and Millennium Pipeline. These transactions were not material for the three and nine months ended September 30, 2020 and 2019 . |
Subsequent Event
Subsequent Event | 9 Months Ended |
Sep. 30, 2020 | |
Subsequent Events [Abstract] | |
Subsequent Event | SUBSEQUENT EVENTOn October 27, 2020, DTE Energy announced that its Board of Directors has authorized management to pursue a plan to spin-off the DTE Midstream business. DTE Energy expects to complete the separation by mid-year 2021, subject to final approval by its Board of Directors, the Form 10 registration statement being declared effective by the Securities and Exchange Commission, regulatory approvals, and satisfaction of other conditions. DTE Energy shareholder approval is not required to effect the separation transaction. Upon closing of the transaction, DTE Energy shareholders will own shares of both DTE Energy and the new Midstream company. The planned separation transaction is intended to be a tax-free spin to DTE Energy shareholders for U.S. federal income tax purposes. There can be no assurance that any separation transaction will ultimately occur or, if one does occur, of its terms or timing. |
Significant Accounting Polici_2
Significant Accounting Policies (Policies) | 9 Months Ended |
Sep. 30, 2020 | |
Accounting Policies [Abstract] | |
Basis of Presentation | Basis of Presentation The Consolidated Financial Statements should be read in conjunction with the Combined Notes to Consolidated Financial Statements included in the combined DTE Energy and DTE Electric 2019 Annual Report on Form 10-K. 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 Consolidated Financial Statements are unaudited but, in the Registrants' opinions, include all adjustments necessary to present a fair statement of the results for the interim periods. All adjustments are of a normal recurring nature, except as otherwise disclosed in these Consolidated Financial Statements and Combined Notes to Consolidated Financial Statements. Financial results for this interim period are not necessarily indicative of results that may be expected for any other interim period or for the fiscal year ending December 31, 2020. 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. |
Reclassification | Certain prior year balances for DTE Electric 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 cost method is used. 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 DTE Energy's Power and Industrial Projects 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. DTE Energy currently owns an 85% interest in SGG, which owns and operates midstream natural gas assets. SGG has contracts through which certain construction risk is designed to pass-through to the customers, with DTE Energy retaining operational and customer default risk. SGG is a VIE with DTE Energy as the primary beneficiary. The Registrants have variable interests in NEXUS, which include DTE Energy's 50% ownership interest and DTE Electric's transportation services contract. NEXUS is a joint venture which owns a 256-mile pipeline to transport Utica and Marcellus shale gas to Ohio, Michigan, and Ontario market centers. NEXUS also owns Generation Pipeline, LLC, a 23-mile regulated pipeline system located in northern Ohio, which was acquired in September 2019. NEXUS is a VIE as it has insufficient equity at risk to finance its activities. The Registrants are not the primary beneficiaries, as the power to direct significant activities is shared between the owners of the equity interests. DTE Energy accounts for its ownership interest in NEXUS 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, including the transportation services contract with NEXUS. As of September 30, 2020, 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 September 30, 2020, 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. The maximum risk exposure for consolidated VIEs is reflected on the Registrants' Consolidated Statements of Financial Position and, for DTE Energy, in Note 13 to the Consolidated Financial Statements, "Commitments and Contingencies," related to the REF guarantees and indemnities. For non-consolidated VIEs, the maximum risk exposure of the Registrants is generally limited to their investment, notes receivable, future funding commitments, and amounts which DTE Energy has guaranteed. See Note 13 to the Consolidated Financial Statements, "Commitments and Contingencies," for further discussion of the NEXUS guarantee arrangements. |
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. DTE Energy releases income tax effects from accumulated other comprehensive income when the circumstances upon which they are premised cease to exist. |
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 remaining maturities of three months or less. Restricted cash consists of funds held in separate bank accounts to satisfy contractual obligations to fund certain construction projects and guarantee performance. Restricted cash designated for payments within one year is classified as a Current Asset. |
Financing Receivables | Financing Receivables 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, classified by internal grade of credit risk. The related credit quality indicators and risk ratings utilized to develop the internal grades have been updated through September 30, 2020. DTE Energy DTE Electric Year of origination 2020 2019 2018 and prior Total 2020 and prior (In millions) Notes receivable Internal grade 1 $ — $ 18 $ 9 $ 27 $ 18 Internal grade 2 60 19 6 85 — Total notes receivable (a) $ 60 $ 37 $ 15 $ 112 $ 18 Net investment in leases Net investment in leases, internal grade 1 $ 8 $ — $ 40 $ 48 $ — Net investment in leases, internal grade 2 132 — 1 133 — Total net investment in leases (a) $ 140 $ — $ 41 $ 181 $ — _______________________________________ (a) For DTE Energy, included in Current Assets — Other and Other Assets — Notes Receivable on the Consolidated Statements of Financial Position. For DTE Electric, included in Current Assets — Other and 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, or financing receivables, for DTE Energy are primarily comprised of finance lease receivables and loans that are included in Notes Receivable and Other current assets on DTE Energy's Consolidated Statements of Financial Position. Notes receivable, or financing receivables, for DTE Electric are primarily comprised of loans. Notes receivable are typically considered delinquent when payment is not received for periods ranging from 60 to 120 days. The Registrants cease accruing interest (nonaccrual status), consider a note receivable impaired, and establish an allowance for credit loss when it is probable that all principal and interest amounts due will not be collected 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. DTE Energy has off balance sheet exposure in the form of a revolving credit facility. Refer to Note 13, "Commitments and Contingencies," for additional information. In determining the level of credit reserve needed, DTE considers the likelihood of funding in addition to the other factors noted above. A reserve may be established when it is likely that funding will occur. 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. |
Recently Adopted and Recently Issued Pronouncements | Recently Adopted Pronouncements In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments , as amended. The amendments in this update have replaced the previous incurred loss impairment methodology with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information, including forecasts, to develop credit loss estimates. The ASU requires entities to use the new methodology to measure impairment of financial instruments, including accounts receivable, and may result in earlier recognition of credit losses than under previous generally accepted accounting principles. Entities must apply the new guidance as a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is adopted. The Registrants adopted the standard effective January 1, 2020. The adoption of the ASU did not have an impact on the Registrants' financial position or results of operations. Additional required disclosures have been included in Note 2 to the Consolidated Financial Statements, “Significant Accounting Policies”. In August 2018, the FASB issued ASU No. 2018-13, Fair Value Measurements (Topic 820): Disclosure Framework - Changes to the Disclosure Requirements for Fair Value Measurement . The amendments in this update modify the disclosure requirements on fair value measurements in Topic 820. The Registrants adopted the ASU effective January 1, 2020. The Registrants have updated Note 8 to the Consolidated Financial Statements, Fair Value, to incorporate the disclosure changes required by the ASU. In August 2018, the FASB issued ASU No. 2018-15, Intangibles - Goodwill and Other - Internal-Use Software (Subtopic 350-40): Customer's Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That is a Service Contract . The amendments in this update align the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software (and hosting arrangements that include an internal use software license). The Registrants adopted the standard effective January 1, 2020 using the prospective approach. The adoption of the ASU did not have an impact on the Registrants’ Consolidated Financial Statements. On a prospective basis, costs within the scope of this amendment will be accounted for consistent with any underlying service contracts. Capitalized implementation costs will be reflected in Other noncurrent assets on the Consolidated Statements of Financial Position and amortization of these costs will be reflected in Operation and maintenance within the Consolidated Statements of Operations. Cash flow activity will be reflected in the Other current and noncurrent assets and liabilities line within the Operating Activities section of the Consolidated Statements of Cash Flows. In August 2018, the FASB issued ASU No. 2018-14, Compensation - Retirement Benefits - Defined Benefit Plans (Subtopic 715-20): Disclosure Framework - Changes to the Disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans . The amendments in this update modify the disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. The Registrants adopted the ASU effective January 1, 2020. The required disclosures for this ASU will be reflected in the 2020 year-end financial statements. In October 2018, the FASB issued ASU No. 2018-17, Consolidation (Topic 810): Targeted Improvements to Related Party Guidance for Variable Interest Entities . The amendments in this update modify the requirements for determining whether fees paid to a decision maker or service provider are variable interests and require reporting entities to consider indirect interests held through related parties under common control on a proportional basis. The Registrants adopted the ASU effective January 1, 2020. The adoption of the ASU did not have a significant impact on the Registrants’ Consolidated Financial Statements. Recently Issued Pronouncements In December 2019, the FASB issued ASU No. 2019-12, Income Taxes (Topic 740) - Simplifying the Accounting for Income Taxes . The amendments in this update simplify the accounting for income taxes by removing certain exceptions, and clarifying certain requirements regarding franchise taxes, goodwill, consolidated tax expenses, and annual effective tax rate calculations. The ASU is effective for the Registrants for fiscal years beginning after December 15, 2020. The Registrants will adopt the ASU on its effective date using a modified retrospective approach. The ASU will not have a significant impact on the Registrants' Consolidated Financial Statements. In March 2020, the FASB issued ASU No. 2020-04, Reference Rate Reform (Topic 848) - Facilitation of the Effects of Reference Rate Reform on Financial Reporting . The amendments in this update provide optional expedients and exceptions for applying GAAP to contracts, hedging relationships, and other transactions affected by reference rate reform if certain criteria are met. The optional expedients are effective for the modification of existing contracts or new arrangements executed March 12, 2020 through December 31, 2022. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements. In August 2020, the FASB issued ASU No. 2020-06, Debt - Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging - Contracts in Entity's Own Equity (Subtopic 815-40): Accounting for Convertible Instruments and Contracts in an Entity's Own Equity. The amendments in this update simplify the accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts indexed to and potentially settled in an entity's own equity. The ASU is effective for the Registrants for fiscal years beginning after December 15, 2021, and interim periods therein. Early adoption is permitted. The ASU will not have a significant impact on the Registrants' Consolidated Financial Statements. |
Fair Value Measurement | 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 September 30, 2020 and December 31, 2019. 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 classified as NAV assets. These funds primarily invest in private equity partnerships, as well as real estate and private debt. 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 $192 million and $151 million as of September 30, 2020 and December 31, 2019, respectively. 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 | 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, certain 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 2023. 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. Gas Storage and Pipelines — This segment is primarily engaged in services related to the gathering, transportation, and storage of natural gas. Primarily fixed-priced contracts are used in the marketing and management of transportation and storage services. Generally, these contracts are not derivatives and are therefore accounted for under the accrual method. Power and Industrial Projects — This segment manages and operates energy and pulverized coal projects, a coke battery, reduced emissions fuel projects, renewable gas recovery, and power generation assets. Primarily fixed-price contracts are used in the marketing and management of the segment assets. These contracts 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 September 30, 2020 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. |
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 issued letters of credit of $5 million and $6 million outstanding at September 30, 2020 and December 31, 2019, respectively, 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 $1 million and $4 million at September 30, 2020 and December 31, 2019, respectively. 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, Derivatives Not Designated or Qualifying as Hedges | 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, and gas — non-utility. |
Income Tax | 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 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. |
Organization and Basis of Pre_2
Organization and Basis of Presentation (Tables) | 9 Months Ended |
Sep. 30, 2020 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Schedule of Variable Interest Entities | The following table summarizes the major Consolidated Statements of Financial Position items for consolidated VIEs as of September 30, 2020 and December 31, 2019. 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. 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 below. Amounts for DTE Energy's consolidated VIEs are as follows: September 30, 2020 December 31, 2019 SGG (a) Other Total SGG (a) Other Total (In millions) ASSETS Cash and cash equivalents $ 33 $ 22 $ 55 $ 16 $ 11 $ 27 Accounts receivable 7 18 25 8 19 27 Inventories — 102 102 — 74 74 Property, plant, and equipment, net 404 25 429 410 33 443 Goodwill 25 — 25 25 — 25 Intangible assets 531 — 531 542 — 542 Other current and long-term assets 1 19 20 2 — 2 $ 1,001 $ 186 $ 1,187 $ 1,003 $ 137 $ 1,140 LIABILITIES Accounts payable and accrued current liabilities $ — $ 19 $ 19 $ 2 $ 13 $ 15 Short-term borrowings — 21 21 — — — Other current and long-term liabilities 6 4 10 7 7 14 $ 6 $ 44 $ 50 $ 9 $ 20 $ 29 _____________________________________ (a) Amounts shown are 100% of SGG's assets and liabilities, of which DTE Energy owns 85% at September 30, 2020 and December 31, 2019. |
Summary of Amounts for Non-Consolidated Variable Interest Entities | Amounts for DTE Energy's non-consolidated VIEs are as follows: September 30, 2020 December 31, 2019 (In millions) Investments in equity method investees $ 1,505 $ 1,503 Notes receivable $ 40 $ 21 Future funding commitments $ 36 $ 63 |
Significant Accounting Polici_3
Significant Accounting Policies (Tables) | 9 Months Ended |
Sep. 30, 2020 | |
Accounting Policies [Abstract] | |
Schedule of Other Income | The following is a summary of DTE Energy's Other income: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Equity earnings of equity method investees $ 37 $ 34 $ 96 $ 77 Income from REF entities 43 40 95 96 Gains from equity and fixed income securities 2 3 24 27 Contract services 7 7 20 21 Gas Storage and Pipelines post-acquisition settlement 20 — 20 — Allowance for equity funds used during construction 6 5 19 18 Other 5 9 12 20 $ 120 $ 98 $ 286 $ 259 The following is a summary of DTE Electric's Other income: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Gains from equity and fixed income securities allocated from DTE Energy $ 2 $ 3 $ 24 $ 27 Contract services 7 7 20 23 Allowance for equity funds used during construction 6 5 18 17 Other 3 5 6 11 $ 18 $ 20 $ 68 $ 78 |
Schedule of Effective Tax Rates | The interim effective tax rates of the Registrants are as follows: Effective Tax Rate Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 DTE Energy 12 % 13 % 10 % 12 % DTE Electric 13 % 16 % 12 % 16 % |
Schedule of Financing Receivables Classified by Internal Grade of Credit Risk | The following represents the Registrants' financing receivables by year of origination, classified by internal grade of credit risk. The related credit quality indicators and risk ratings utilized to develop the internal grades have been updated through September 30, 2020. DTE Energy DTE Electric Year of origination 2020 2019 2018 and prior Total 2020 and prior (In millions) Notes receivable Internal grade 1 $ — $ 18 $ 9 $ 27 $ 18 Internal grade 2 60 19 6 85 — Total notes receivable (a) $ 60 $ 37 $ 15 $ 112 $ 18 Net investment in leases Net investment in leases, internal grade 1 $ 8 $ — $ 40 $ 48 $ — Net investment in leases, internal grade 2 132 — 1 133 — Total net investment in leases (a) $ 140 $ — $ 41 $ 181 $ — _______________________________________ (a) For DTE Energy, included in Current Assets — Other and Other Assets — Notes Receivable on the Consolidated Statements of Financial Position. For DTE Electric, included in Current Assets — Other and Other Assets — Other on the Consolidated Statements of Financial Position. |
Schedule of Roll-Forward of Activity for Financing Receivables Credit Loss Reserves | The following table presents a roll-forward of the activity for the Registrants' financing receivables credit loss reserves as of September 30, 2020. DTE Energy DTE Electric Trade accounts receivable Other receivables Total Trade and other accounts receivable (In millions) Beginning reserve balance, January 1, 2020 $ 87 $ 4 $ 91 $ 46 Current period provision 73 2 75 47 Write-offs charged against allowance (117) (3) (120) (68) Recoveries of amounts previously written off 41 — 41 24 Ending reserve balance, September 30, 2020 $ 84 $ 3 $ 87 $ 49 |
Acquisitions (Tables)
Acquisitions (Tables) | 9 Months Ended |
Sep. 30, 2020 | |
Business Combinations [Abstract] | |
Schedule of Final Purchase Price Allocation | 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) Contract intangibles $ 17 Property, plant, and equipment, net 76 Working capital 2 Total $ 95 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) Contract intangibles $ 109 Property, plant, and equipment, net 60 Working capital 6 Total $ 175 (In millions) Assets Cash $ 62 Accounts receivable 31 Property, plant, and equipment, net 1,035 Goodwill 172 Customer relationship intangibles 1,473 Other current assets 1 $ 2,774 Liabilities Accounts payable $ 26 Acquisition related deferred payment 380 Other current liabilities 2 Asset retirement obligations 9 $ 417 Total cash consideration $ 2,357 |
Revenue (Tables)
Revenue (Tables) | 9 Months Ended |
Sep. 30, 2020 | |
Revenue from Contract with Customer [Abstract] | |
Disaggregation of Revenue | The following is a summary of revenues disaggregated by segment for DTE Energy: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Electric (a) Residential $ 900 $ 791 $ 2,169 $ 1,839 Commercial 498 515 1,313 1,358 Industrial 157 175 434 497 Other (b) 138 39 305 251 Total Electric operating revenues (c) $ 1,693 $ 1,520 $ 4,221 $ 3,945 Gas Gas sales $ 92 $ 87 $ 655 $ 727 End User Transportation 34 35 154 157 Intermediate Transportation 15 15 57 57 Other (b) 32 18 98 102 Total Gas operating revenues (d) $ 173 $ 155 $ 964 $ 1,043 Other segment operating revenues Gas Storage and Pipelines (e) $ 204 $ 126 $ 546 $ 363 Power and Industrial Projects (f) $ 324 $ 406 $ 850 $ 1,196 Energy Trading (g) $ 1,061 $ 1,105 $ 2,714 $ 3,519 _______________________________________ (a) Revenues generally represent those of DTE Electric, except $3 million and $10 million of Other revenues related to DTE Sustainable Generation for the three and nine months ended September 30, 2020, respectively. (b) Includes revenue adjustments related to various regulatory mechanisms. (c) Includes $8 million and $5 million of other revenues outside the scope of topic 606 for the three months ended September 30, 2020 and 2019, and $18 million and $14 million for the nine months ended September 30, 2020 and 2019, respectively. (d) Includes $2 million under Alternative Revenue Programs for the nine months ended September 30, 2020 and $2 million and $7 million of other revenues for the three and nine months ended September 30, 2020, respectively, which are all outside the scope of Topic 606. For prior period, revenues include $2 million and $6 million of other revenues for the three and nine months ended September 30, 2019, respectively, which are all outside the scope of Topic 606. (e) Includes revenues outside the scope of Topic 606 primarily related to $2 million of contracts accounted for as leases for the three months ended September 30, 2020 and 2019, and $7 million for the nine months ended September 30, 2020 and 2019. (f) Includes revenues outside the scope of Topic 606 primarily related to $26 million and $33 million of contracts accounted for as leases for the three months ended September 30, 2020 and 2019, respectively, and $74 million and $94 million for the nine months ended September 30, 2020 and 2019, respectively. (g) Includes revenues outside the scope of Topic 606 primarily related to $731 million and $791 million of derivatives for the three months ended September 30, 2020 and 2019, respectively, and $1.8 billion and $2.6 billion of derivatives for the nine months ended September 30, 2020 and 2019, respectively. |
Summary of Deferred Revenue Activity | The following is a summary of deferred revenue activity: DTE Energy (In millions) Beginning Balance, January 1, 2020 $ 75 Increases due to cash received or receivable, excluding amounts recognized as revenue during the period 39 Revenue recognized that was included in the deferred revenue balance at the beginning of the period (42) Ending Balance, September 30, 2020 $ 72 |
Deferred Revenue Amounts Expected to be Recognized as Revenue in Future Periods | 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) 2020 $ 7 2021 36 2022 7 2023 3 2024 7 2025 and thereafter 12 $ 72 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 Energy DTE Electric (In millions) 2020 $ 72 $ 2 2021 350 8 2022 294 7 2023 231 7 2024 142 8 2025 and thereafter 580 — $ 1,669 $ 32 |
Earnings Per Share (Tables)
Earnings Per Share (Tables) | 9 Months Ended |
Sep. 30, 2020 | |
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: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions, except per share amounts) Basic Earnings per Share Net Income Attributable to DTE Energy Company $ 476 $ 319 $ 1,093 $ 902 Less: Allocation of earnings to net restricted stock awards 1 1 2 2 Net income available to common shareholders — basic $ 475 $ 318 $ 1,091 $ 900 Average number of common shares outstanding — basic 193 183 192 183 Basic Earnings per Common Share $ 2.47 $ 1.74 $ 5.67 $ 4.93 Diluted Earnings per Share Net Income Attributable to DTE Energy Company $ 476 $ 319 $ 1,093 $ 902 Less: Allocation of earnings to net restricted stock awards 1 1 2 2 Net income available to common shareholders — diluted $ 475 $ 318 $ 1,091 $ 900 Average number of common shares outstanding — basic 193 183 192 183 Incremental shares attributable to: Average dilutive equity units, performance share awards, and stock options — 1 1 1 Average number of common shares outstanding — diluted 193 184 193 184 Diluted Earnings per Common Share (a) $ 2.46 $ 1.73 $ 5.66 $ 4.91 _______________________________________ (a) Equity Units excluded from the calculation of diluted EPS were approximately 10.3 million for the three and nine months ended September 30, 2020, as the dilutive stock price threshold was not met. |
Fair Value (Tables)
Fair Value (Tables) | 9 Months Ended |
Sep. 30, 2020 | |
Fair Value Disclosures [Abstract] | |
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 (a) : September 30, 2020 December 31, 2019 Level Level Level Other (b) Netting (c) Net Balance Level Level Level Other (b) Netting (c) Net Balance (In millions) Assets Cash equivalents (d) $ 567 $ — $ — $ — $ — $ 567 $ 15 $ — $ — $ — $ — $ 15 Nuclear decommissioning trusts Equity securities 872 — — 141 — 1,013 1,046 — — — — 1,046 Fixed income securities 122 325 — 80 — 527 160 378 — — — 538 Private equity and other — — — 78 — 78 — — — 43 — 43 Cash equivalents 46 — — — — 46 34 — — — — 34 Other investments (e) Equity securities 49 — — — — 49 140 — — — — 140 Fixed income securities 6 — — — — 6 79 — — — — 79 Cash equivalents 98 — — — — 98 4 — — — — 4 Derivative assets Commodity contracts (f) Natural gas 126 72 42 — (194) 46 205 76 74 — (266) 89 Electricity — 103 34 — (106) 31 — 223 83 — (225) 81 Environmental & Other — 194 7 — (186) 15 — 110 3 — (110) 3 Foreign currency exchange contracts — 2 — — — 2 — 1 — — — 1 Total derivative assets 126 371 83 — (486) 94 205 410 160 — (601) 174 Total $ 1,886 $ 696 $ 83 $ 299 $ (486) $ 2,478 $ 1,683 $ 788 $ 160 $ 43 $ (601) $ 2,073 Liabilities Derivative liabilities Commodity contracts (f) Natural gas $ (118) $ (66) $ (81) $ — $ 185 $ (80) $ (221) $ (41) $ (89) $ — $ 266 $ (85) Electricity — (97) (29) — 104 (22) — (231) (67) — 225 (73) Environmental & Other (3) (168) — — 171 — — (121) — — 110 (11) Foreign currency exchange contracts — (2) — — — (2) — — — — — — Total $ (121) $ (333) $ (110) $ — $ 460 $ (104) $ (221) $ (393) $ (156) $ — $ 601 $ (169) Net Assets (Liabilities) at end of period $ 1,765 $ 363 $ (27) $ 299 $ (26) $ 2,374 $ 1,462 $ 395 $ 4 $ 43 $ — $ 1,904 Assets Current $ 679 $ 273 $ 59 $ — $ (379) $ 632 $ 218 $ 320 $ 123 $ — $ (513) $ 148 Noncurrent 1,207 423 24 299 (107) 1,846 1,465 468 37 43 (88) 1,925 Total Assets $ 1,886 $ 696 $ 83 $ 299 $ (486) $ 2,478 $ 1,683 $ 788 $ 160 $ 43 $ (601) $ 2,073 Liabilities Current $ (112) $ (243) $ (66) $ — $ 361 $ (60) $ (211) $ (300) $ (85) $ — $ 513 $ (83) Noncurrent (9) (90) (44) — 99 (44) (10) (93) (71) — 88 (86) Total Liabilities $ (121) $ (333) $ (110) $ — $ 460 $ (104) $ (221) $ (393) $ (156) $ — $ 601 $ (169) Net Assets (Liabilities) at end of period $ 1,765 $ 363 $ (27) $ 299 $ (26) $ 2,374 $ 1,462 $ 395 $ 4 $ 43 $ — $ 1,904 _______________________________________ (a) See footnotes on following page. _______________________________________ (b) Amounts represent assets valued at NAV as a practical expedient for fair value. (c) 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. (d) At September 30, 2020, the $567 million consisted of $565 million and $2 million of cash equivalents included in Cash and cash equivalents and Restricted cash on DTE Energy's Consolidated Statements of Financial Position, respectively. At December 31, 2019, the $15 million consisted of $4 million and $11 million of cash equivalents included in Cash and cash equivalents and Other investments on DTE Energy's Consolidated Statements of Financial Position, respectively. (e) Excludes cash surrender value of life insurance investments. (f) 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: September 30, 2020 December 31, 2019 Level 1 Level 2 Level 3 Other (a) Net Balance Level 1 Level 2 Level 3 Other (a) Net Balance (In millions) Assets Cash equivalents (b) $ 175 $ — $ — $ — $ 175 $ 11 $ — $ — $ — $ 11 Nuclear decommissioning trusts Equity securities 872 — — 141 1,013 1,046 — — — 1,046 Fixed income securities 122 325 — 80 527 160 378 — — 538 Private equity and other — — — 78 78 — — — 43 43 Cash equivalents 46 — — — 46 34 — — — 34 Other investments Equity securities 14 — — — 14 13 — — — 13 Cash equivalents 11 — — — 11 — — — — — Derivative assets — FTRs — — 7 — 7 — — 3 — 3 Total $ 1,240 $ 325 $ 7 $ 299 $ 1,871 $ 1,264 $ 378 $ 3 $ 43 $ 1,688 Assets Current $ 175 $ — $ 7 $ — $ 182 $ 11 $ — $ 3 $ — $ 14 Noncurrent 1,065 325 — 299 1,689 1,253 378 — 43 1,674 Total Assets $ 1,240 $ 325 $ 7 $ 299 $ 1,871 $ 1,264 $ 378 $ 3 $ 43 $ 1,688 _______________________________________ (a) Amounts represent assets valued at NAV as a practical expedient for fair value. (b) At September 30, 2020, the $175 million of cash equivalents was included in Cash and cash equivalents on DTE Electric's Consolidated Statements of Financial Position. At December 31, 2019, the $11 million of cash equivalents was included in Other investments on DTE Electric's Consolidated Statements of Financial Position. |
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: Three Months Ended September 30, 2020 Three Months Ended September 30, 2019 Natural Gas Electricity Other Total Natural Gas Electricity Other Total (In millions) Net Assets (Liabilities) as of June 30 $ 20 $ 16 $ 10 $ 46 $ (10) $ 10 $ 9 $ 9 Transfers from Level 3 into Level 2 (1) — — (1) — — — — Total gains (losses) Included in earnings (80) 37 1 (42) (35) 37 — 2 Recorded in Regulatory liabilities — — 9 9 — — (3) (3) Purchases, issuances, and settlements Settlements 22 (48) (13) (39) 4 (39) (1) (36) Net Assets (Liabilities) as of September 30 $ (39) $ 5 $ 7 $ (27) $ (41) $ 8 $ 5 $ (28) Total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at September 30, 2020 and 2019 (a) $ (57) $ 11 $ (1) $ (47) $ (36) $ 15 $ (1) $ (22) _______________________________________ (a) Amounts are reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations. Nine Months Ended September 30, 2020 Nine Months Ended September 30, 2019 Natural Gas Electricity Other Total Natural Gas Electricity Other Total (In millions) Net Assets (Liabilities) as of December 31 $ (15) $ 16 $ 3 $ 4 $ (49) $ (2) $ 7 $ (44) Transfers from Level 3 into Level 2 (5) — — (5) — — — — Total gains (losses) Included in earnings (44) 90 (7) 39 (4) 47 (1) 42 Recorded in Regulatory liabilities — — 21 21 — — 3 3 Purchases, issuances, and settlements Settlements 25 (101) (10) (86) 12 (37) (4) (29) Net Assets (Liabilities) as of September 30 $ (39) $ 5 $ 7 $ (27) $ (41) $ 8 $ 5 $ (28) Total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at September 30, 2020 and 2019 (a) $ (20) $ 53 $ (17) $ 16 $ (20) $ 32 $ (6) $ 6 _______________________________________ (a) Amounts are reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — 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: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Net Assets as of beginning of period $ 10 $ 9 $ 3 $ 6 Change in fair value recorded in Regulatory liabilities 9 (3) 21 3 Purchases, issuances, and settlements Settlements (12) (1) (17) (4) Net Assets as of September 30 $ 7 $ 5 $ 7 $ 5 The amount of total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets held at September 30, 2020 and 2019 and reflected in DTE Electric's Consolidated Statements of Financial Position $ — $ (1) $ 7 $ 5 |
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: September 30, 2020 Commodity Contracts Derivative Assets Derivative Liabilities Valuation Techniques Unobservable Input Range Weighted Average (In millions) Natural Gas $ 42 $ (81) Discounted Cash Flow Forward basis price (per MMBtu) $ (1.10) — $ 2.30 /MMBtu $ (0.06) /MMBtu Electricity $ 34 $ (29) Discounted Cash Flow Forward basis price (per MWh) $ (9) — $ 6 /MWh $ (1) /MWh December 31, 2019 Commodity Contracts Derivative Assets Derivative Liabilities Valuation Techniques Unobservable Input Range Weighted Average (In millions) Natural Gas $ 74 $ (89) Discounted Cash Flow Forward basis price (per MMBtu) $ (1.78) — $ 5.78 /MMBtu $ (0.09) /MMBtu Electricity $ 83 $ (67) Discounted Cash Flow Forward basis price (per MWh) $ (10) — $ 6 /MWh $ — /MWh |
Carrying Amount of Fair Value of Financial Instruments | The following table presents the carrying amount and fair value of financial instruments for DTE Energy: September 30, 2020 December 31, 2019 Carrying Fair Value Carrying Fair Value Amount Level 1 Level 2 Level 3 Amount Level 1 Level 2 Level 3 (In millions) Notes receivable — Other (a) , excluding lessor finance leases $ 112 $ — $ — $ 112 $ 184 $ — $ — $ 184 Short-term borrowings $ 988 $ — $ 988 $ — $ 828 $ — $ 828 $ — Notes payable — Other (b) $ 19 $ — $ — $ 19 $ 25 $ — $ — $ 25 Long-term debt (c) $ 18,660 $ 2,398 $ 17,213 $ 1,406 $ 16,606 $ 2,572 $ 14,207 $ 1,252 _______________________________________ (a) Current portion included in Current Assets — Other on DTE Energy's Consolidated Statements of Financial Position. (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, unamortized debt discounts, and issuance costs. Excludes finance lease obligations. The following table presents the carrying amount and fair value of financial instruments for DTE Electric: September 30, 2020 December 31, 2019 Carrying Fair Value Carrying Fair Value Amount Level 1 Level 2 Level 3 Amount Level 1 Level 2 Level 3 (In millions) Notes receivable — Other (a) $ 18 $ — $ — $ 18 $ 9 $ — $ — $ 9 Short-term borrowings — affiliates $ 104 $ — $ — $ 104 $ 97 $ — $ — $ 97 Short-term borrowings — other $ 200 $ — $ 200 $ — $ 354 $ — $ 354 $ — Notes payable — Other (b) $ 17 $ — $ — $ 17 $ 21 $ — $ — $ 21 Long-term debt (c) $ 8,235 $ — $ 9,565 $ 194 $ 7,180 $ — $ 7,916 $ 173 _______________________________________ (a) Included in Current Assets — Other and 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, unamortized debt discounts, and issuance costs. Excludes finance lease obligations. |
Fair Value of Nuclear Decommissioning Trust Fund Assets | The following table summarizes DTE Electric's fair value of the nuclear decommissioning trust fund assets: September 30, 2020 December 31, 2019 (In millions) Fermi 2 $ 1,652 $ 1,650 Fermi 1 3 3 Low-level radioactive waste 9 8 $ 1,664 $ 1,661 |
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: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Realized gains $ 38 $ 15 $ 172 $ 43 Realized losses $ (11) $ (8) $ (103) $ (25) Proceeds from sale of securities $ 816 $ 198 $ 2,054 $ 594 |
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: September 30, 2020 December 31, 2019 Fair Unrealized Unrealized Fair Unrealized Unrealized (In millions) Equity securities $ 1,013 $ 325 $ (28) $ 1,046 $ 396 $ (39) Fixed income securities 527 16 (1) 538 24 (1) Private equity and other 78 — — 43 — — Cash equivalents 46 — — 34 — — $ 1,664 $ 341 $ (29) $ 1,661 $ 420 $ (40) |
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: September 30, 2020 (In millions) Due within one year $ 92 Due after one through five years 82 Due after five through ten years 79 Due after ten years 194 $ 447 |
Summary of Gains (Losses) Related to the Trust | The following table summarizes DTE Energy's gains (losses) related to the trust: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Gains (losses) related to equity securities $ 2 $ 1 $ (4) $ 18 Gains (losses) related to fixed income securities — 2 (3) 9 $ 2 $ 3 $ (7) $ 27 |
Financial and Other Derivativ_2
Financial and Other Derivative Instruments (Tables) | 9 Months Ended |
Sep. 30, 2020 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Fair Value of Derivative Instruments | The following table presents the fair value of derivative instruments for DTE Energy: September 30, 2020 December 31, 2019 Derivative Derivative Liabilities Derivative Derivative Liabilities (In millions) Derivatives designated as hedging instruments Foreign currency exchange contracts $ — $ (1) $ — $ — Derivatives not designated as hedging instruments Commodity contracts Natural gas $ 240 $ (265) $ 355 $ (351) Electricity 137 (126) 306 (298) Environmental & Other 201 (171) 113 (121) Foreign currency exchange contracts 2 (1) 1 — Total derivatives not designated as hedging instruments $ 580 $ (563) $ 775 $ (770) Current $ 444 $ (421) $ 646 $ (596) Noncurrent 136 (143) 129 (174) Total derivatives $ 580 $ (564) $ 775 $ (770) The following table presents the fair value of derivative instruments for DTE Electric: September 30, 2020 December 31, 2019 (In millions) FTRs — Other current assets $ 7 $ 3 Total derivatives not designated as hedging instruments $ 7 $ 3 |
Netting Offsets of Derivative Assets | The following table presents net cash collateral offsetting arrangements for DTE Energy: September 30, 2020 December 31, 2019 (In millions) Cash collateral netted against Derivative assets $ (26) $ — Cash collateral recorded in Accounts receivable (a) 12 13 Cash collateral recorded in Accounts payable (a) (2) (3) Total net cash collateral posted (received) $ (16) $ 10 _______________________________________ (a) Amounts are recorded net by counterparty. The following table presents the netting offsets of Derivative assets and liabilities for DTE Energy: September 30, 2020 December 31, 2019 Gross Amounts of Recognized Assets (Liabilities) Gross Amounts Offset in the Consolidated Statements of Financial Position Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position Gross Amounts of Recognized Assets (Liabilities) Gross Amounts Offset in the Consolidated Statements of Financial Position Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position (In millions) Derivative assets Commodity contracts Natural gas $ 240 $ (194) $ 46 $ 355 $ (266) $ 89 Electricity 137 (106) 31 306 (225) 81 Environmental & Other 201 (186) 15 113 (110) 3 Foreign currency exchange contracts 2 — 2 1 — 1 Total derivative assets $ 580 $ (486) $ 94 $ 775 $ (601) $ 174 Derivative liabilities Commodity contracts Natural gas $ (265) $ 185 $ (80) $ (351) $ 266 $ (85) Electricity (126) 104 (22) (298) 225 (73) Environmental & Other (171) 171 — (121) 110 (11) Foreign currency exchange contracts (2) — (2) — — — Total derivative liabilities $ (564) $ 460 $ (104) $ (770) $ 601 $ (169) |
Netting Offsets of Derivative Liabilities | The following table presents net cash collateral offsetting arrangements for DTE Energy: September 30, 2020 December 31, 2019 (In millions) Cash collateral netted against Derivative assets $ (26) $ — Cash collateral recorded in Accounts receivable (a) 12 13 Cash collateral recorded in Accounts payable (a) (2) (3) Total net cash collateral posted (received) $ (16) $ 10 _______________________________________ (a) Amounts are recorded net by counterparty. The following table presents the netting offsets of Derivative assets and liabilities for DTE Energy: September 30, 2020 December 31, 2019 Gross Amounts of Recognized Assets (Liabilities) Gross Amounts Offset in the Consolidated Statements of Financial Position Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position Gross Amounts of Recognized Assets (Liabilities) Gross Amounts Offset in the Consolidated Statements of Financial Position Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position (In millions) Derivative assets Commodity contracts Natural gas $ 240 $ (194) $ 46 $ 355 $ (266) $ 89 Electricity 137 (106) 31 306 (225) 81 Environmental & Other 201 (186) 15 113 (110) 3 Foreign currency exchange contracts 2 — 2 1 — 1 Total derivative assets $ 580 $ (486) $ 94 $ 775 $ (601) $ 174 Derivative liabilities Commodity contracts Natural gas $ (265) $ 185 $ (80) $ (351) $ 266 $ (85) Electricity (126) 104 (22) (298) 225 (73) Environmental & Other (171) 171 — (121) 110 (11) Foreign currency exchange contracts (2) — (2) — — — Total derivative liabilities $ (564) $ 460 $ (104) $ (770) $ 601 $ (169) |
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: September 30, 2020 December 31, 2019 Derivative Assets Derivative Liabilities Derivative Assets Derivative Liabilities Current Noncurrent Current Noncurrent Current Noncurrent Current Noncurrent (In millions) Total fair value of derivatives $ 444 $ 136 $ (421) $ (143) $ 646 $ 129 $ (596) $ (174) Counterparty netting (361) (99) 361 99 (513) (88) 513 88 Collateral adjustment (18) (8) — — — — — — Total derivatives as reported $ 65 $ 29 $ (60) $ (44) $ 133 $ 41 $ (83) $ (86) |
Gain (Loss) Recognized in Income on Derivatives | 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 Derivatives Gain (Loss) Recognized in Income on Derivatives for the Three Months Ended September 30, Gain (Loss) Recognized in Income on Derivatives for the Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Commodity contracts Natural gas Operating Revenues — Non-utility operations $ (27) $ (5) $ (63) $ 4 Natural gas Fuel, purchased power, and gas — non-utility (51) (47) 28 (7) Electricity Operating Revenues — Non-utility operations 33 54 75 21 Environmental & Other Operating Revenues — Non-utility operations 2 (11) (40) (11) Foreign currency exchange contracts Operating Revenues — Non-utility operations (2) 1 — (2) Total $ (45) $ (8) $ — $ 5 |
Volume of Commodity Contracts | The following represents the cumulative gross volume of DTE Energy's derivative contracts outstanding as of September 30, 2020: Commodity Number of Units Natural gas (MMBtu) 1,739,656,507 Electricity (MWh) 28,258,929 Foreign currency exchange (CAD) 154,336,963 Renewable Energy Certificates (MWh) 7,893,076 Carbon emissions (Metric Ton) 16,451,411 |
Long-Term Debt (Tables)
Long-Term Debt (Tables) | 9 Months Ended |
Sep. 30, 2020 | |
Debt Disclosure [Abstract] | |
Schedule of Issued Debt | In 2020, the following debt was issued: Company Month Type Interest Rate Maturity Date Amount (In millions) DTE Electric February Mortgage Bonds (a) 2.25% 2030 $ 600 DTE Electric February Mortgage Bonds (a) 2.95% 2050 500 DTE Electric April Mortgage Bonds (b) 2.63% 2031 600 DTE Energy August Senior Notes (c) 1.05% 2025 800 DTE Gas August Mortgage Bonds (d) 2.35% 2030 125 DTE Gas August Mortgage Bonds (d) 3.20% 2050 125 $ 2,750 _______________________________________ (a) Proceeds used for the repayment of $300 million of DTE Electric's 2010 Series A 4.89% Senior Notes due 2020, repayment of short-term borrowings, capital expenditures, and for other general corporate purposes. (b) Proceeds used for the repayment of $300 million of DTE Electric's 2010 Series B 3.45% Senior Notes due 2020, repayment of $32 million of DTE Electric's 2008 Series KT Variable Rate Senior Notes due 2020, repayment of short-term borrowings, capital expenditures, and for other general corporate purposes. (c) Proceeds used for the repayment of short-term borrowings and for general corporate purposes. (d) Proceeds used for the repayment of $50 million of DTE Gas's 2008 Series I 6.36% Senior Notes due 2020 and for general corporate purposes, including capital expenditures. |
Schedule of Debt Redeemed | In 2020, the following debt was redeemed: Company Month Type Interest Rate Maturity Date Amount (In millions) DTE Electric March Senior Notes 4.89% 2020 $ 300 DTE Electric July Senior Notes 5.63% 2020 32 DTE Electric July Senior Notes 3.45% 2020 300 DTE Gas September Senior Notes 6.36% 2020 50 $ 682 |
Short-Term Credit Arrangement_2
Short-Term Credit Arrangements and Borrowings (Tables) | 9 Months Ended |
Sep. 30, 2020 | |
Short-term Debt [Abstract] | |
Schedule of Line of Credit Facilities | The availability under these facilities as of September 30, 2020 is shown in the following table: DTE Energy DTE Electric DTE Gas Total (In millions) Unsecured letter of credit facility, expiring in February 2021 $ 150 $ — $ — $ 150 Unsecured letter of credit facility, expiring in August 2021 110 — — 110 Unsecured term loan, expiring in March 2021 500 — — 500 Unsecured term loans, expiring in April 2021 — 400 100 500 Unsecured term loan, expiring in June 2021 167 — — 167 Unsecured Canadian revolving credit facility, expiring May 2023 83 — — 83 Unsecured revolving credit facility, expiring April 2024 1,500 500 300 2,300 2,510 900 400 3,810 Amounts outstanding at September 30, 2020 Letters of credit 212 — — 212 Unsecured term loan 667 200 100 967 Revolver borrowings 21 — — 21 900 200 100 1,200 Net availability at September 30, 2020 $ 1,610 $ 700 $ 300 $ 2,610 |
Leases (Tables)
Leases (Tables) | 9 Months Ended |
Sep. 30, 2020 | |
Leases [Abstract] | |
Components of Net Investment in Finance Leases | The components of DTE Energy’s net investment in finance leases for remaining periods were as follows: DTE Energy September 30, 2020 (In millions) 2020 $ 8 2021 24 2022 20 2023 19 2024 19 2025 and Thereafter 273 Total minimum future lease receipts 363 Residual value of leased pipeline 19 Less unearned income 201 Net investment in finance lease 181 Less current portion 10 $ 171 |
Schedule of Lease Income Associated with Operating Leases | DTE Energy’s lease income associated with operating leases was as follows: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Fixed payments $ 17 $ 17 $ 50 $ 51 Variable payments 43 40 82 92 $ 60 $ 57 $ 132 $ 143 |
Retirement Benefits and Trust_2
Retirement Benefits and Trusteed Assets (Tables) | 9 Months Ended |
Sep. 30, 2020 | |
Retirement Benefits [Abstract] | |
Schedule of Net Periodic Benefit Costs (Credits) | The following tables detail the components of net periodic benefit costs (credits) for pension benefits and other postretirement benefits for DTE Energy: Pension Benefits Other Postretirement Benefits Three Months Ended September 30, 2020 2019 2020 2019 (In millions) Service cost $ 25 $ 21 $ 7 $ 5 Interest cost 46 55 14 18 Expected return on plan assets (84) (82) (32) (30) Amortization of: Net actuarial loss 43 33 4 3 Prior service credit — — (5) (3) Settlements 2 — — — Net periodic benefit cost (credit) $ 32 $ 27 $ (12) $ (7) Pension Benefits Other Postretirement Benefits Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Service cost $ 74 $ 63 $ 20 $ 16 Interest cost 139 164 42 53 Expected return on plan assets (250) (244) (96) (92) Amortization of: Net actuarial loss 129 99 12 9 Prior service credit — — (15) (7) Settlements 2 — — — Net periodic benefit cost (credit) $ 94 $ 82 $ (37) $ (21) The following tables detail the components of net periodic benefit costs (credits) for other postretirement benefits for DTE Electric: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) (In millions) Service cost $ 5 $ 4 $ 15 $ 12 Interest cost 11 13 32 40 Expected return on plan assets (21) (21) (65) (63) Amortization of: Net actuarial loss 2 1 8 3 Prior service credit (3) (1) (10) (5) Net periodic benefit credit $ (6) $ (4) $ (20) $ (13) |
Schedule of the Contribution of Common Stock to the DTE Energy Company Affiliates Employee Benefit Plans Master Trust | Details of the contribution of common stock to the DTE Energy Company Affiliates Employee Benefit Plans Master Trust are as follows: Date Number of Shares Price per Share Amount (In millions) September 8, 2020 694,444 $ 118.08 $ 82 |
Segment and Related Informati_2
Segment and Related Information (Tables) | 9 Months Ended |
Sep. 30, 2020 | |
Segment Reporting [Abstract] | |
Schedule of Segment Reporting Information, by Segment | Inter-segment billing for goods and services exchanged between segments is based upon tariffed or market-based prices of the provider and primarily consists of the sale of reduced emissions fuel, power sales, and natural gas sales in the following segments: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Electric $ 16 $ 16 $ 46 $ 43 Gas 4 3 12 8 Gas Storage and Pipelines 8 11 17 17 Power and Industrial Projects 134 160 308 462 Energy Trading 9 4 23 16 Corporate and Other 1 1 2 2 $ 172 $ 195 $ 408 $ 548 Financial data of DTE Energy's business segments follows: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Operating Revenues — Utility operations Electric $ 1,690 $ 1,520 $ 4,211 $ 3,945 Gas 173 155 964 1,043 Operating Revenues — Non-utility operations Electric 3 — 10 — Gas Storage and Pipelines 204 126 546 363 Power and Industrial Projects 324 406 850 1,196 Energy Trading 1,061 1,105 2,714 3,519 Corporate and Other 1 2 2 3 Reconciliation and Eliminations (172) (195) (408) (548) Total $ 3,284 $ 3,119 $ 8,889 $ 9,521 Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Net Income (Loss) Attributable to DTE Energy by Segment: Electric $ 398 $ 307 $ 675 $ 587 Gas (20) (38) 102 121 Gas Storage and Pipelines 104 60 246 158 Power and Industrial Projects 47 49 102 104 Energy Trading (28) (14) 5 12 Corporate and Other (25) (45) (37) (80) Net Income Attributable to DTE Energy Company $ 476 $ 319 $ 1,093 $ 902 |
Related Party Transactions (Tab
Related Party Transactions (Tables) | 9 Months Ended |
Sep. 30, 2020 | |
Related Party Transactions [Abstract] | |
Schedule of Related Party Transactions | The following table summarizes the amounts resulting from these transactions included in the Consolidated Statements of Operations: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In millions) Operating Revenues — Utility operations DTE Gas $ 8 $ 8 $ 24 $ 24 Fuel, purchased power, and gas — utility DTE Electric $ 2 $ 2 $ 6 $ 6 DTE Gas $ 2 $ 2 $ 14 $ 15 Fuel, purchased power, and gas — non-utility DTE Energy Trading $ 7 $ 2 $ 20 $ 5 |
Organization and Basis of Pre_3
Organization and Basis of Presentation (Details Textuals) customer in Millions | Sep. 30, 2020USD ($)customer |
Error Corrections and Prior Period Adjustments Restatement [Line Items] | |
Number of electric utility customers | customer | 2.2 |
Number of gas utility customers | customer | 1.3 |
Significant potential exposure | $ | $ 0 |
DTE Electric | |
Error Corrections and Prior Period Adjustments Restatement [Line Items] | |
Significant potential exposure | $ | $ 0 |
NEXUS pipeline | |
Error Corrections and Prior Period Adjustments Restatement [Line Items] | |
Ownership interest | 50.00% |
SGG | Midstream Natural Gas Assets | |
Error Corrections and Prior Period Adjustments Restatement [Line Items] | |
Percent of assets acquired | 85.00% |
Organization and Basis of Pre_4
Organization and Basis of Presentation (Consolidated Variable Interest Entities) (Details) - USD ($) $ in Millions | 8 Months Ended | 9 Months Ended |
Dec. 31, 2019 | Sep. 30, 2020 | |
ASSETS | ||
Cash and cash equivalents | $ 93 | $ 945 |
Accounts receivable | 1,642 | 1,419 |
Property, plant, and equipment, net | 25,317 | 27,159 |
Goodwill | 2,464 | 2,465 |
Total Assets | 41,882 | 44,439 |
LIABILITIES | ||
Short-term borrowings | 828 | 988 |
Total | ||
ASSETS | ||
Cash and cash equivalents | 27 | 55 |
Accounts receivable | 27 | 25 |
Inventories | 74 | 102 |
Property, plant, and equipment, net | 443 | 429 |
Goodwill | 25 | 25 |
Intangible assets | 542 | 531 |
Other current and long-term assets | 2 | 20 |
Total Assets | 1,140 | 1,187 |
LIABILITIES | ||
Accounts payable and accrued current liabilities | 15 | 19 |
Short-term borrowings | 0 | 21 |
Other current and long-term liabilities | 14 | 10 |
Total liabilities | 29 | 50 |
SGG | ||
ASSETS | ||
Cash and cash equivalents | 16 | 33 |
Accounts receivable | 8 | 7 |
Inventories | 0 | 0 |
Property, plant, and equipment, net | 410 | 404 |
Goodwill | 25 | 25 |
Intangible assets | 542 | 531 |
Other current and long-term assets | 2 | 1 |
Total Assets | 1,003 | 1,001 |
LIABILITIES | ||
Accounts payable and accrued current liabilities | 2 | 0 |
Short-term borrowings | 0 | 0 |
Other current and long-term liabilities | 7 | 6 |
Total liabilities | $ 9 | $ 6 |
VIE ownership and non-ownership percentage | 100.00% | |
VIE ownership percentage | 85.00% | 85.00% |
Other | ||
ASSETS | ||
Cash and cash equivalents | $ 11 | $ 22 |
Accounts receivable | 19 | 18 |
Inventories | 74 | 102 |
Property, plant, and equipment, net | 33 | 25 |
Goodwill | 0 | 0 |
Intangible assets | 0 | 0 |
Other current and long-term assets | 0 | 19 |
Total Assets | 137 | 186 |
LIABILITIES | ||
Accounts payable and accrued current liabilities | 13 | 19 |
Short-term borrowings | 0 | 21 |
Other current and long-term liabilities | 7 | 4 |
Total liabilities | $ 20 | $ 44 |
Organization and Basis of Pre_5
Organization and Basis of Presentation (Non-Consolidated Variable Interest Entities) (Details) - USD ($) $ in Millions | Sep. 30, 2020 | Dec. 31, 2019 |
Variable Interest Entity [Line Items] | ||
Investments in equity method investees | $ 1,865 | $ 1,862 |
Notes receivable | 255 | 202 |
Variable interest entity, non-consolidated | ||
Variable Interest Entity [Line Items] | ||
Investments in equity method investees | 1,505 | 1,503 |
Notes receivable | 40 | 21 |
Future funding commitments | $ 36 | $ 63 |
Significant Accounting Polici_4
Significant Accounting Policies (Other Income) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | |
Schedule of Other Nonoperating Income, by Component [Line Items] | ||||
Equity earnings of equity method investees | $ 37 | $ 34 | $ 96 | $ 77 |
Income from REF entities | 43 | 40 | 95 | 96 |
Gains from equity and fixed income securities | 2 | 3 | 24 | 27 |
Contract services | 7 | 7 | 20 | 21 |
Gas Storage and Pipelines post-acquisition settlement | 20 | 0 | 20 | 0 |
Allowance for equity funds used during construction | 6 | 5 | 19 | 18 |
Other | 5 | 9 | 12 | 20 |
Total other income | 120 | 98 | 286 | 259 |
DTE Electric | ||||
Schedule of Other Nonoperating Income, by Component [Line Items] | ||||
Gains from equity and fixed income securities | 2 | 3 | 24 | 27 |
Contract services | 7 | 7 | 20 | 23 |
Allowance for equity funds used during construction | 6 | 5 | 18 | 17 |
Other | 3 | 5 | 6 | 11 |
Total other income | $ 18 | $ 20 | $ 68 | $ 78 |
Significant Accounting Polici_5
Significant Accounting Policies (Details Textuals) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | |||||||
Sep. 30, 2020 | Jun. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | Dec. 31, 2019 | Dec. 31, 2018 | Mar. 31, 2020 | Jun. 30, 2019 | Mar. 31, 2019 | |
Significant Accounting Policies [Line Items] | ||||||||||
Reclassification of income tax effects | $ 12,488 | $ 11,892 | $ 10,904 | $ 12,488 | $ 10,904 | $ 11,836 | $ 10,717 | $ 11,988 | $ 10,569 | $ 11,020 |
Implementation of ASU | us-gaap:AccountingStandardsUpdate201802Member | us-gaap:AccountingStandardsUpdate201802Member | ||||||||
Effective tax rate increase (decrease) | (1.00%) | (2.00%) | ||||||||
Amortization of TCJA regulatory liability | 2.00% | 2.00% | ||||||||
Annual production tax credit increase (decrease) | (1.00%) | (3.00%) | ||||||||
Carryback of 2018 net operating loss due to the CARES Act | 3.00% | |||||||||
Unrecognized compensation cost | $ 84 | $ 84 | ||||||||
Recognition period (in years) | 1 year 4 months 28 days | |||||||||
Uncollectible expense adjusted for regulatory deferrals | 22 | 28 | $ 70 | 81 | ||||||
CARES Act | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
Reduction in Income Tax Expense due to carryback of 2018 net operating loss to 2013 | 34 | |||||||||
Claim for employee retention credits | 6 | |||||||||
Deferral of employer payroll taxes | $ 32 | |||||||||
CARES Act, AMT Credit Refund | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
AMT credit received from U.S. Treasury | 220 | |||||||||
Immediate Refund of 2018 Remaining AMT Credit Balance | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
AMT credit received from U.S. Treasury | 153 | |||||||||
Immediate Refund of AMT Credit Generated by Carrying Back 2018 Net Operating Loss to 2013 | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
AMT credit received from U.S. Treasury | $ 67 | |||||||||
Minimum | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
Notes receivable considered delinquent period | 60 days | |||||||||
Maximum | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
Notes receivable considered delinquent period | 120 days | |||||||||
Unbilled Revenues | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
Specific review of probable future collections based on receivable balances, threshold duration | 30 days | |||||||||
DTE Electric and DTE Gas | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
Receivables due date | 21 days | |||||||||
Threshold period past due for write-off of trade accounts receivable | 150 days | |||||||||
DTE Electric | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
Effective tax rate increase (decrease) | (3.00%) | (4.00%) | ||||||||
Amortization of TCJA regulatory liability | 3.00% | 3.00% | ||||||||
Annual production tax credit increase (decrease) | 1.00% | |||||||||
Uncollectible expense adjusted for regulatory deferrals | $ 16 | 17 | $ 42 | 47 | ||||||
DTE Electric | COVID-19 Pandemic | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
Uncollectible expense deferred as a Regulatory asset | (1) | 5 | ||||||||
DTE Electric | CARES Act | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
Claim for employee retention credits | 3 | |||||||||
Deferral of employer payroll taxes | 17 | |||||||||
DTE Electric | DTE Energy | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
Income tax payable | 5 | 5 | ||||||||
Income tax receivable | $ 14 | |||||||||
Allocated costs | 12 | 9 | 28 | 33 | ||||||
DTE Gas | COVID-19 Pandemic | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
Uncollectible expense deferred as a Regulatory asset | (1) | 1 | ||||||||
Accumulated Other Comprehensive Income (Loss) | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
Reclassification of income tax effects | (138) | (141) | (146) | (138) | (146) | (148) | $ (120) | (145) | (146) | (143) |
Retained Earnings | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
Reclassification of income tax effects | $ 7,092 | $ 6,618 | $ 6,516 | $ 7,092 | $ 6,516 | $ 6,587 | 6,112 | $ 6,732 | $ 6,198 | $ 6,364 |
Implementation of ASU | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
Reclassification of income tax effects | 0 | |||||||||
Implementation of ASU | Accumulated Other Comprehensive Income (Loss) | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
Reclassification of income tax effects | (25) | |||||||||
Implementation of ASU | Retained Earnings | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
Reclassification of income tax effects | 25 | |||||||||
ASU No. 2018-02 | Implementation of ASU | Accumulated Other Comprehensive Income (Loss) | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
Reclassification of income tax effects | (25) | |||||||||
ASU No. 2018-02 | Implementation of ASU | Retained Earnings | ||||||||||
Significant Accounting Policies [Line Items] | ||||||||||
Reclassification of income tax effects | $ 25 |
Significant Accounting Polici_6
Significant Accounting Policies (Income Taxes) (Details) | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | |
Schedule of Income Taxes [Line Items] | ||||
Effective Tax Rate | 12.00% | 13.00% | 10.00% | 12.00% |
DTE Electric | ||||
Schedule of Income Taxes [Line Items] | ||||
Effective Tax Rate | 13.00% | 16.00% | 12.00% | 16.00% |
Significant Accounting Polici_7
Significant Accounting Policies (Financing Receivables Classified by Internal Grade of Credit Risk) (Details) $ in Millions | Sep. 30, 2020USD ($) |
Notes receivable | |
Financing Receivable, Credit Quality Indicator [Line Items] | |
2020 | $ 60 |
2019 | 37 |
2018 and prior | 15 |
Total | 112 |
Notes receivable | Internal grade 1 | |
Financing Receivable, Credit Quality Indicator [Line Items] | |
2020 | 0 |
2019 | 18 |
2018 and prior | 9 |
Total | 27 |
Notes receivable | Internal grade 2 | |
Financing Receivable, Credit Quality Indicator [Line Items] | |
2020 | 60 |
2019 | 19 |
2018 and prior | 6 |
Total | 85 |
Net investment in leases | |
Financing Receivable, Credit Quality Indicator [Line Items] | |
2020 | 140 |
2019 | 0 |
2018 and prior | 41 |
Total | 181 |
Net investment in leases | Internal grade 1 | |
Financing Receivable, Credit Quality Indicator [Line Items] | |
2020 | 8 |
2019 | 0 |
2018 and prior | 40 |
Total | 48 |
Net investment in leases | Internal grade 2 | |
Financing Receivable, Credit Quality Indicator [Line Items] | |
2020 | 132 |
2019 | 0 |
2018 and prior | 1 |
Total | 133 |
DTE Electric | Notes receivable | |
Financing Receivable, Credit Quality Indicator [Line Items] | |
Total | 18 |
DTE Electric | Notes receivable | Internal grade 1 | |
Financing Receivable, Credit Quality Indicator [Line Items] | |
Total | 18 |
DTE Electric | Notes receivable | Internal grade 2 | |
Financing Receivable, Credit Quality Indicator [Line Items] | |
Total | 0 |
DTE Electric | Net investment in leases | |
Financing Receivable, Credit Quality Indicator [Line Items] | |
Total | 0 |
DTE Electric | Net investment in leases | Internal grade 1 | |
Financing Receivable, Credit Quality Indicator [Line Items] | |
Total | 0 |
DTE Electric | Net investment in leases | Internal grade 2 | |
Financing Receivable, Credit Quality Indicator [Line Items] | |
Total | $ 0 |
Significant Accounting Polici_8
Significant Accounting Policies (Roll-Forward of Activity for Financing Receivables Credit Loss Reserves) (Details) $ in Millions | 9 Months Ended |
Sep. 30, 2020USD ($) | |
Financing Receivable, Allowance for Credit Loss [Roll Forward] | |
Beginning balance | $ 91 |
Current period provision | 75 |
Write-offs charged against allowance | (120) |
Recoveries of amounts previously written off | 41 |
Ending balance | 87 |
Trade accounts receivable | |
Financing Receivable, Allowance for Credit Loss [Roll Forward] | |
Beginning balance | 87 |
Current period provision | 73 |
Write-offs charged against allowance | (117) |
Recoveries of amounts previously written off | 41 |
Ending balance | 84 |
Other receivables | |
Financing Receivable, Allowance for Credit Loss [Roll Forward] | |
Beginning balance | 4 |
Current period provision | 2 |
Write-offs charged against allowance | (3) |
Recoveries of amounts previously written off | 0 |
Ending balance | 3 |
DTE Electric | |
Financing Receivable, Allowance for Credit Loss [Roll Forward] | |
Beginning balance | 46 |
Current period provision | 47 |
Write-offs charged against allowance | (68) |
Recoveries of amounts previously written off | 24 |
Ending balance | $ 49 |
Acquisitions (Details Textuals)
Acquisitions (Details Textuals) $ in Millions | Jul. 27, 2020USD ($)installment | Feb. 18, 2020USD ($)MW | Dec. 04, 2019USD ($) | Sep. 12, 2019USD ($)MW | Jan. 31, 2020USD ($) | Dec. 31, 2019USD ($) | Sep. 30, 2020USD ($) | Jun. 30, 2020USD ($) | Mar. 31, 2020USD ($) | Sep. 30, 2019USD ($) | Jun. 30, 2019USD ($) | Mar. 31, 2019USD ($) | Sep. 30, 2020USD ($) | Sep. 30, 2019USD ($) |
Business Acquisition [Line Items] | ||||||||||||||
Consideration paid for entity acquired, paid in cash | $ 126 | $ 174 | ||||||||||||
Goodwill | $ 2,464 | $ 2,465 | 2,465 | |||||||||||
Operating Revenues — Non-utility operations | 1,440 | $ 1,463 | 3,770 | 4,584 | ||||||||||
Net Income | 477 | $ 277 | $ 342 | $ 317 | $ 179 | $ 408 | 1,096 | $ 904 | ||||||
Power and Industrial Projects | South Jersey Industries, Combined Heat and Power Generation Facility | ||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||
Amount of power associated with purchase of renewable energy project | MW | 8 | |||||||||||||
Consideration paid for entity acquired, paid in cash | $ 95 | |||||||||||||
Power and Industrial Projects | South Jersey Industries, Combined Heat and Power Generation Facility | Contract intangibles | ||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||
Intangible assets, amortization period | 13 years | |||||||||||||
Intangible assets recorded as a result of acquisition | $ 17 | |||||||||||||
Electric | Heritage Sustainable Energy, Renewable Energy Project | DTE Sustainable Generation | ||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||
Amount of power associated with purchase of renewable energy project | MW | 89 | |||||||||||||
Total consideration provided for acquired entity | $ 175 | |||||||||||||
Electric | Heritage Sustainable Energy, Renewable Energy Project | DTE Sustainable Generation | Contract intangibles | ||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||
Intangible assets recorded as a result of acquisition | $ 109 | |||||||||||||
Electric | Heritage Sustainable Energy, Renewable Energy Project | DTE Sustainable Generation | Contract intangibles | Minimum | ||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||
Intangible assets, amortization period | 11 years | |||||||||||||
Electric | Heritage Sustainable Energy, Renewable Energy Project | DTE Sustainable Generation | Contract intangibles | Maximum | ||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||
Intangible assets, amortization period | 13 years | |||||||||||||
Electric | Heritage Sustainable Energy, Additional Renewable Energy Project | DTE Sustainable Generation | ||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||
Consideration paid for entity acquired, paid in cash | $ 33 | |||||||||||||
Gas Storage and Pipelines | Blue Union and LEAP | ||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||
Consideration paid for entity acquired, paid in cash | $ 2,360 | |||||||||||||
Total consideration provided for acquired entity | $ 2,740 | |||||||||||||
Percent of assets acquired | 100.00% | |||||||||||||
Contingent consideration to be paid upon completion | $ 380 | |||||||||||||
Accretion expense related to liability for contingent consideration payment | 1 | 5 | ||||||||||||
Payment of consideration upon achievement of final milestone | $ 385 | |||||||||||||
Number of equal payment installments made upon achievement of final milestone | installment | 2 | |||||||||||||
Remaining cash consideration paid and held in escrow | 14 | |||||||||||||
Goodwill | $ 172 | $ 172 | 172 | |||||||||||
Goodwill, working capital adjustments | $ 1 | |||||||||||||
Direct transaction costs incurred | 18 | |||||||||||||
Issuance costs related to acquisition financing | 49 | |||||||||||||
Operating Revenues — Non-utility operations | 15 | |||||||||||||
Net Income | 3 | |||||||||||||
Gas Storage and Pipelines | Blue Union and LEAP | Mortgage bonds, notes, and other | ||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||
Issuance costs related to acquisition financing | 10 | |||||||||||||
Gas Storage and Pipelines | Blue Union and LEAP | Common Stock | ||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||
Issuance costs related to acquisition financing | $ 39 | |||||||||||||
Gas Storage and Pipelines | Blue Union and LEAP | Customer relationships | ||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||
Intangible assets, amortization period | 40 years | |||||||||||||
Intangible assets recorded as a result of acquisition | $ 1,473 | |||||||||||||
Existing intangible asset weighted-average amortization life | 13 years |
Acquisitions (Purchase Price Al
Acquisitions (Purchase Price Allocation - Power and Industrial Segment Acquisition) (Details) - Power and Industrial Projects - South Jersey Industries, Combined Heat and Power Generation Facility $ in Millions | Feb. 18, 2020USD ($) |
Business Acquisition [Line Items] | |
Property, plant, and equipment, net | $ 76 |
Working capital | 2 |
Total | 95 |
Contract intangibles | |
Business Acquisition [Line Items] | |
Contract intangibles | $ 17 |
Acquisitions (Purchase Price _2
Acquisitions (Purchase Price Allocation - Electric Segment Acquisition) (Details) - DTE Sustainable Generation - Electric - Heritage Sustainable Energy, Renewable Energy Project $ in Millions | Sep. 12, 2019USD ($) |
Business Acquisition [Line Items] | |
Property, plant, and equipment, net | $ 60 |
Working capital | 6 |
Total | 175 |
Contract intangibles | |
Business Acquisition [Line Items] | |
Contract intangibles | $ 109 |
Acquisitions (Purchase Price _3
Acquisitions (Purchase Price Allocation - Gas Storage and Pipelines Segment Acquisition) (Details) - USD ($) $ in Millions | Sep. 30, 2020 | Dec. 31, 2019 | Dec. 04, 2019 |
Assets | |||
Goodwill | $ 2,465 | $ 2,464 | |
Gas Storage and Pipelines | Blue Union and LEAP | |||
Assets | |||
Cash | $ 62 | ||
Accounts receivable | 31 | ||
Property, plant, and equipment, net | 1,035 | ||
Goodwill | $ 172 | 172 | |
Other current assets | 1 | ||
Total assets | 2,774 | ||
Liabilities | |||
Accounts payable | 26 | ||
Acquisition related deferred payment | 380 | ||
Other current liabilities | 2 | ||
Asset retirement obligations | 9 | ||
Total liabilities | 417 | ||
Total cash consideration | 2,357 | ||
Gas Storage and Pipelines | Customer relationships | Blue Union and LEAP | |||
Assets | |||
Customer relationship intangibles | $ 1,473 |
Revenue (Disaggregation of Reve
Revenue (Disaggregation of Revenue) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | |
Disaggregation of Revenue [Line Items] | ||||
Revenues | $ 3,284 | $ 3,119 | $ 8,889 | $ 9,521 |
Lease revenue outside scope of Topic 606 | 60 | 57 | 132 | 143 |
Electric | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 1,693 | 1,520 | 4,221 | 3,945 |
Other revenues outside scope of topic 606 | 8 | 5 | 18 | 14 |
Electric | Residential | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 900 | 791 | 2,169 | 1,839 |
Electric | Commercial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 498 | 515 | 1,313 | 1,358 |
Electric | Industrial | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 157 | 175 | 434 | 497 |
Electric | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 138 | 39 | 305 | 251 |
Electric | Other | DTE Sustainable Generation | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 3 | 10 | ||
Gas | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 173 | 155 | 964 | 1,043 |
Other revenues outside scope of topic 606 | 2 | 2 | 7 | 6 |
Alternative Revenue Program revenues outside scope of Topic 606 | 2 | |||
Gas | Other | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 32 | 18 | 98 | 102 |
Gas | Gas sales | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 92 | 87 | 655 | 727 |
Gas | End User Transportation | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 34 | 35 | 154 | 157 |
Gas | Intermediate Transportation | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 15 | 15 | 57 | 57 |
Gas Storage and Pipelines | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 204 | 126 | 546 | 363 |
Lease revenue outside scope of Topic 606 | 2 | 2 | 7 | 7 |
Power and Industrial Projects | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 324 | 406 | 850 | 1,196 |
Lease revenue outside scope of Topic 606 | 26 | 33 | 74 | 94 |
Energy Trading | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenues | 1,061 | 1,105 | 2,714 | 3,519 |
Gain (loss) on derivative outside scope of Topic 606 | $ 731 | $ 791 | $ 1,800 | $ 2,600 |
Revenue (Deferred Revenue) (Det
Revenue (Deferred Revenue) (Details) $ in Millions | 9 Months Ended |
Sep. 30, 2020USD ($) | |
Contract Liability [Roll Forward] | |
Beginning Balance | $ 75 |
Increases due to cash received or receivable, excluding amounts recognized as revenue during the period | 39 |
Revenue recognized that was included in the deferred revenue balance at the beginning of the period | (42) |
Ending Balance | $ 72 |
Revenue (Expected Recognition o
Revenue (Expected Recognition of Deferred Revenue) (Details) $ in Millions | Sep. 30, 2020USD ($) |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 72 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-10-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 7 |
Remaining performance obligation, expected timing of satisfaction | 3 months |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 36 |
Remaining performance obligation, expected timing of satisfaction | 1 year |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 7 |
Remaining performance obligation, expected timing of satisfaction | 1 year |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 3 |
Remaining performance obligation, expected timing of satisfaction | 1 year |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 7 |
Remaining performance obligation, expected timing of satisfaction | 1 year |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 12 |
Remaining performance obligation, expected timing of satisfaction |
Revenue (Expected Timing of Per
Revenue (Expected Timing of Performance Obligation Satisfaction) (Details) $ in Millions | Sep. 30, 2020USD ($) |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 72 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-10-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 7 |
Remaining performance obligation, expected timing of satisfaction | 3 months |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 36 |
Remaining performance obligation, expected timing of satisfaction | 1 year |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 7 |
Remaining performance obligation, expected timing of satisfaction | 1 year |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 3 |
Remaining performance obligation, expected timing of satisfaction | 1 year |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 7 |
Remaining performance obligation, expected timing of satisfaction | 1 year |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 12 |
Remaining performance obligation, expected timing of satisfaction | |
Fixed-price Contract | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 1,669 |
Fixed-price Contract | DTE Electric | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | 32 |
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-10-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 72 |
Remaining performance obligation, expected timing of satisfaction | 3 months |
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-10-01 | DTE Electric | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 2 |
Remaining performance obligation, expected timing of satisfaction | 3 months |
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 350 |
Remaining performance obligation, expected timing of satisfaction | 1 year |
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | DTE Electric | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 8 |
Remaining performance obligation, expected timing of satisfaction | 1 year |
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 294 |
Remaining performance obligation, expected timing of satisfaction | 1 year |
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | DTE Electric | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 7 |
Remaining performance obligation, expected timing of satisfaction | 1 year |
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 231 |
Remaining performance obligation, expected timing of satisfaction | 1 year |
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | DTE Electric | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 7 |
Remaining performance obligation, expected timing of satisfaction | 1 year |
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 142 |
Remaining performance obligation, expected timing of satisfaction | 1 year |
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | DTE Electric | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 8 |
Remaining performance obligation, expected timing of satisfaction | 1 year |
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 580 |
Remaining performance obligation, expected timing of satisfaction | |
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | DTE Electric | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Remaining performance obligation | $ 0 |
Remaining performance obligation, expected timing of satisfaction |
Regulatory Matters (Details Tex
Regulatory Matters (Details Textuals) - USD ($) $ in Millions | Jul. 17, 2020 | May 08, 2020 | Nov. 25, 2019 | Jul. 08, 2019 | Sep. 30, 2020 | Jun. 30, 2020 | Sep. 30, 2020 | Dec. 31, 2020 | Jul. 09, 2020 |
DTE Electric | COVID-19 Pandemic | |||||||||
Public Utilities, General Disclosures [Line Items] | |||||||||
Uncollectible expense deferred as a Regulatory asset | $ (1) | $ 5 | |||||||
DTE Electric | COVID-19 Pandemic | Forecast | |||||||||
Public Utilities, General Disclosures [Line Items] | |||||||||
Proposed regulatory liability | $ 30 | ||||||||
DTE Electric | MPSC | 2019 Electric Rate Case Filing | |||||||||
Public Utilities, General Disclosures [Line Items] | |||||||||
Requested rate increase | $ 351 | ||||||||
Return on equity percent | 9.90% | 10.00% | |||||||
Return on equity requested percent | 10.50% | ||||||||
Approved rate increase | $ 188 | ||||||||
Disallowed cost, capital expenditures related to incentive compensation | $ 41 | ||||||||
Regulatory liability for non-plant-related accumulated deferred income tax balances that resulted from the TCJA, accelerated amortization approved | $ 102 | ||||||||
DTE Gas | COVID-19 Pandemic | |||||||||
Public Utilities, General Disclosures [Line Items] | |||||||||
Uncollectible expense deferred as a Regulatory asset | $ (1) | $ 1 | |||||||
DTE Gas | MPSC | 2019 Gas Rate Case Filing | |||||||||
Public Utilities, General Disclosures [Line Items] | |||||||||
Requested rate increase | $ 204 | ||||||||
Return on equity percent | 9.90% | 10.00% | |||||||
Return on equity requested percent | 10.50% | ||||||||
Approved rate increase | $ 110 | ||||||||
Disallowed cost, capital expenditures related to incentive compensation | $ 14 | ||||||||
Regulatory liability for non-plant-related accumulated deferred income tax balances that resulted from the TCJA, accelerated amortization approved | 20 | ||||||||
Net increase to customers due to rate increase | $ 51 |
Earnings Per Share (Details)
Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | |
Basic Earnings per Share | ||||
Net Income Attributable to DTE Energy Company | $ 476 | $ 319 | $ 1,093 | $ 902 |
Less: Allocation of earnings to net restricted stock awards | 1 | 1 | 2 | 2 |
Net income available to common shareholders — basic | $ 475 | $ 318 | $ 1,091 | $ 900 |
Average number of common shares outstanding — basic (in shares) | 193 | 183 | 192 | 183 |
Basic Earnings per Common Share (in dollars per share) | $ 2.47 | $ 1.74 | $ 5.67 | $ 4.93 |
Diluted Earnings per Share | ||||
Net Income Attributable to DTE Energy Company | $ 476 | $ 319 | $ 1,093 | $ 902 |
Less: Allocation of earnings to net restricted stock awards | 1 | 1 | 2 | 2 |
Net income available to common shareholders — diluted | $ 475 | $ 318 | $ 1,091 | $ 900 |
Average number of common shares outstanding — basic (in shares) | 193 | 183 | 192 | 183 |
Incremental shares attributable to: | ||||
Average dilutive equity units, performance share awards, and stock options (in shares) | 0 | 1 | 1 | 1 |
Average number of common shares outstanding — diluted (in shares) | 193 | 184 | 193 | 184 |
Diluted Earnings per Common Share (in dollars per share) | $ 2.46 | $ 1.73 | $ 5.66 | $ 4.91 |
Antidilutive securities excluded from computation of earnings per share (in shares) | 10.3 | 10.3 |
Fair Value (Assets and Liabilit
Fair Value (Assets and Liabilities Recorded at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions | Sep. 30, 2020 | Dec. 31, 2019 |
Derivative assets | ||
Derivative assets, gross | $ 580 | $ 775 |
Derivative asset, netting | (486) | (601) |
Derivative assets, net | 94 | 174 |
Derivative liabilities | ||
Derivative liabilities, gross | (564) | (770) |
Derivative liability, netting | 460 | 601 |
Derivative liabilities, net | (104) | (169) |
Current liabilities | ||
Derivative liabilities | ||
Derivative liabilities, gross | (421) | (596) |
Noncurrent liabilities | ||
Derivative liabilities | ||
Derivative liabilities, gross | (143) | (174) |
Natural gas | ||
Derivative assets | ||
Derivative assets, gross | 240 | 355 |
Derivative asset, netting | (194) | (266) |
Derivative assets, net | 46 | 89 |
Derivative liabilities | ||
Derivative liabilities, gross | (265) | (351) |
Derivative liability, netting | 185 | 266 |
Derivative liabilities, net | (80) | (85) |
Electricity | ||
Derivative assets | ||
Derivative assets, gross | 137 | 306 |
Derivative asset, netting | (106) | (225) |
Derivative assets, net | 31 | 81 |
Derivative liabilities | ||
Derivative liabilities, gross | (126) | (298) |
Derivative liability, netting | 104 | 225 |
Derivative liabilities, net | (22) | (73) |
Environmental & Other | ||
Derivative assets | ||
Derivative assets, gross | 201 | 113 |
Derivative asset, netting | (186) | (110) |
Derivative assets, net | 15 | 3 |
Derivative liabilities | ||
Derivative liabilities, gross | (171) | (121) |
Derivative liability, netting | 171 | 110 |
Derivative liabilities, net | 0 | (11) |
Foreign currency exchange contracts | ||
Derivative assets | ||
Derivative assets, gross | 2 | 1 |
Derivative asset, netting | 0 | 0 |
Derivative assets, net | 2 | 1 |
Derivative liabilities | ||
Derivative liabilities, gross | (2) | 0 |
Derivative liability, netting | 0 | 0 |
Derivative liabilities, net | (2) | 0 |
Recurring | ||
Assets | ||
Cash equivalents | 567 | 15 |
Derivative assets | ||
Derivative asset, netting | (486) | (601) |
Derivative assets, net | 94 | 174 |
Total assets | 2,478 | 2,073 |
Derivative liabilities | ||
Derivative liability, netting | 460 | 601 |
Derivative liabilities, net | (104) | (169) |
Net Assets (Liabilities) at end of period | 2,374 | 1,904 |
Net Assets at end of period, netting | (26) | 0 |
Recurring | DTE Electric | ||
Assets | ||
Cash equivalents | 175 | 11 |
Derivative assets | ||
Total assets | 1,871 | 1,688 |
Recurring | Current assets | ||
Derivative assets | ||
Derivative asset, netting | (379) | (513) |
Total assets | 632 | 148 |
Recurring | Current assets | DTE Electric | ||
Derivative assets | ||
Total assets | 182 | 14 |
Recurring | Noncurrent assets | ||
Derivative assets | ||
Derivative asset, netting | (107) | (88) |
Total assets | 1,846 | 1,925 |
Recurring | Noncurrent assets | DTE Electric | ||
Derivative assets | ||
Total assets | 1,689 | 1,674 |
Recurring | Current liabilities | ||
Derivative liabilities | ||
Derivative liability, netting | 361 | 513 |
Derivative liabilities, net | (60) | (83) |
Recurring | Noncurrent liabilities | ||
Derivative liabilities | ||
Derivative liability, netting | 99 | 88 |
Derivative liabilities, net | (44) | (86) |
Recurring | Cash and cash equivalents | ||
Assets | ||
Cash equivalents | 565 | 4 |
Recurring | Cash and cash equivalents | DTE Electric | ||
Assets | ||
Cash equivalents | 175 | |
Recurring | Restricted cash | ||
Assets | ||
Cash equivalents | 2 | |
Recurring | Other | ||
Assets | ||
Cash equivalents | 11 | |
Recurring | Other | DTE Electric | ||
Assets | ||
Cash equivalents | 11 | |
Recurring | Natural gas | ||
Derivative assets | ||
Derivative asset, netting | (194) | (266) |
Derivative assets, net | 46 | 89 |
Derivative liabilities | ||
Derivative liability, netting | 185 | 266 |
Derivative liabilities, net | (80) | (85) |
Recurring | Electricity | ||
Derivative assets | ||
Derivative asset, netting | (106) | (225) |
Derivative assets, net | 31 | 81 |
Derivative liabilities | ||
Derivative liability, netting | 104 | 225 |
Derivative liabilities, net | (22) | (73) |
Recurring | Environmental & Other | ||
Derivative assets | ||
Derivative asset, netting | (186) | (110) |
Derivative assets, net | 15 | 3 |
Derivative liabilities | ||
Derivative liability, netting | 171 | 110 |
Derivative liabilities, net | 0 | (11) |
Recurring | Foreign currency exchange contracts | ||
Derivative assets | ||
Derivative asset, netting | 0 | 0 |
Derivative assets, net | 2 | 1 |
Derivative liabilities | ||
Derivative liability, netting | 0 | 0 |
Derivative liabilities, net | (2) | 0 |
Recurring | Derivative assets — FTRs | DTE Electric | ||
Derivative assets | ||
Derivative assets, net | 7 | 3 |
Recurring | Cash equivalents | ||
Assets | ||
Nuclear decommissioning trusts | 46 | 34 |
Other investments | 98 | 4 |
Recurring | Cash equivalents | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | 46 | 34 |
Other investments | 11 | 0 |
Recurring | Private equity and other | ||
Assets | ||
Nuclear decommissioning trusts | 78 | 43 |
Recurring | Private equity and other | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | 78 | 43 |
Recurring | Equity securities | ||
Assets | ||
Nuclear decommissioning trusts | 1,013 | 1,046 |
Other investments | 49 | 140 |
Recurring | Equity securities | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | 1,013 | 1,046 |
Other investments | 14 | 13 |
Recurring | Fixed income securities | ||
Assets | ||
Nuclear decommissioning trusts | 527 | 538 |
Other investments | 6 | 79 |
Recurring | Fixed income securities | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | 527 | 538 |
Recurring | Level 1 | ||
Assets | ||
Cash equivalents | 567 | 15 |
Derivative assets | ||
Derivative assets, gross | 126 | 205 |
Total assets | 1,886 | 1,683 |
Derivative liabilities | ||
Derivative liabilities, gross | (121) | (221) |
Net Assets (Liabilities) at end of period | 1,765 | 1,462 |
Recurring | Level 1 | DTE Electric | ||
Assets | ||
Cash equivalents | 175 | 11 |
Derivative assets | ||
Total assets | 1,240 | 1,264 |
Recurring | Level 1 | Current assets | ||
Derivative assets | ||
Total assets | 679 | 218 |
Recurring | Level 1 | Current assets | DTE Electric | ||
Derivative assets | ||
Total assets | 175 | 11 |
Recurring | Level 1 | Noncurrent assets | ||
Derivative assets | ||
Total assets | 1,207 | 1,465 |
Recurring | Level 1 | Noncurrent assets | DTE Electric | ||
Derivative assets | ||
Total assets | 1,065 | 1,253 |
Recurring | Level 1 | Current liabilities | ||
Derivative liabilities | ||
Derivative liabilities, gross | (112) | (211) |
Recurring | Level 1 | Noncurrent liabilities | ||
Derivative liabilities | ||
Derivative liabilities, gross | (9) | (10) |
Recurring | Level 1 | Natural gas | ||
Derivative assets | ||
Derivative assets, gross | 126 | 205 |
Derivative liabilities | ||
Derivative liabilities, gross | (118) | (221) |
Recurring | Level 1 | Electricity | ||
Derivative assets | ||
Derivative assets, gross | 0 | 0 |
Derivative liabilities | ||
Derivative liabilities, gross | 0 | 0 |
Recurring | Level 1 | Environmental & Other | ||
Derivative assets | ||
Derivative assets, gross | 0 | 0 |
Derivative liabilities | ||
Derivative liabilities, gross | (3) | 0 |
Recurring | Level 1 | Foreign currency exchange contracts | ||
Derivative assets | ||
Derivative assets, gross | 0 | 0 |
Derivative liabilities | ||
Derivative liabilities, gross | 0 | 0 |
Recurring | Level 1 | Derivative assets — FTRs | DTE Electric | ||
Derivative assets | ||
Derivative assets, net | 0 | 0 |
Recurring | Level 1 | Cash equivalents | ||
Assets | ||
Nuclear decommissioning trusts | 46 | 34 |
Other investments | 98 | 4 |
Recurring | Level 1 | Cash equivalents | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | 46 | 34 |
Other investments | 11 | 0 |
Recurring | Level 1 | Private equity and other | ||
Assets | ||
Nuclear decommissioning trusts | 0 | 0 |
Recurring | Level 1 | Private equity and other | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | 0 | 0 |
Recurring | Level 1 | Equity securities | ||
Assets | ||
Nuclear decommissioning trusts | 872 | 1,046 |
Other investments | 49 | 140 |
Recurring | Level 1 | Equity securities | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | 872 | 1,046 |
Other investments | 14 | 13 |
Recurring | Level 1 | Fixed income securities | ||
Assets | ||
Nuclear decommissioning trusts | 122 | 160 |
Other investments | 6 | 79 |
Recurring | Level 1 | Fixed income securities | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | 122 | 160 |
Recurring | Level 2 | ||
Assets | ||
Cash equivalents | 0 | 0 |
Derivative assets | ||
Derivative assets, gross | 371 | 410 |
Total assets | 696 | 788 |
Derivative liabilities | ||
Derivative liabilities, gross | (333) | (393) |
Net Assets (Liabilities) at end of period | 363 | 395 |
Recurring | Level 2 | DTE Electric | ||
Assets | ||
Cash equivalents | 0 | 0 |
Derivative assets | ||
Total assets | 325 | 378 |
Recurring | Level 2 | Current assets | ||
Derivative assets | ||
Total assets | 273 | 320 |
Recurring | Level 2 | Current assets | DTE Electric | ||
Derivative assets | ||
Total assets | 0 | 0 |
Recurring | Level 2 | Noncurrent assets | ||
Derivative assets | ||
Total assets | 423 | 468 |
Recurring | Level 2 | Noncurrent assets | DTE Electric | ||
Derivative assets | ||
Total assets | 325 | 378 |
Recurring | Level 2 | Current liabilities | ||
Derivative liabilities | ||
Derivative liabilities, gross | (243) | (300) |
Recurring | Level 2 | Noncurrent liabilities | ||
Derivative liabilities | ||
Derivative liabilities, gross | (90) | (93) |
Recurring | Level 2 | Natural gas | ||
Derivative assets | ||
Derivative assets, gross | 72 | 76 |
Derivative liabilities | ||
Derivative liabilities, gross | (66) | (41) |
Recurring | Level 2 | Electricity | ||
Derivative assets | ||
Derivative assets, gross | 103 | 223 |
Derivative liabilities | ||
Derivative liabilities, gross | (97) | (231) |
Recurring | Level 2 | Environmental & Other | ||
Derivative assets | ||
Derivative assets, gross | 194 | 110 |
Derivative liabilities | ||
Derivative liabilities, gross | (168) | (121) |
Recurring | Level 2 | Foreign currency exchange contracts | ||
Derivative assets | ||
Derivative assets, gross | 2 | 1 |
Derivative liabilities | ||
Derivative liabilities, gross | (2) | 0 |
Recurring | Level 2 | Derivative assets — FTRs | DTE Electric | ||
Derivative assets | ||
Derivative assets, net | 0 | 0 |
Recurring | Level 2 | Cash equivalents | ||
Assets | ||
Nuclear decommissioning trusts | 0 | 0 |
Other investments | 0 | 0 |
Recurring | Level 2 | Cash equivalents | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | 0 | 0 |
Other investments | 0 | 0 |
Recurring | Level 2 | Private equity and other | ||
Assets | ||
Nuclear decommissioning trusts | 0 | 0 |
Recurring | Level 2 | Private equity and other | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | 0 | 0 |
Recurring | Level 2 | Equity securities | ||
Assets | ||
Nuclear decommissioning trusts | 0 | 0 |
Other investments | 0 | 0 |
Recurring | Level 2 | Equity securities | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | 0 | 0 |
Other investments | 0 | 0 |
Recurring | Level 2 | Fixed income securities | ||
Assets | ||
Nuclear decommissioning trusts | 325 | 378 |
Other investments | 0 | 0 |
Recurring | Level 2 | Fixed income securities | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | 325 | 378 |
Recurring | Level 3 | ||
Assets | ||
Cash equivalents | 0 | 0 |
Derivative assets | ||
Derivative assets, gross | 83 | 160 |
Total assets | 83 | 160 |
Derivative liabilities | ||
Derivative liabilities, gross | (110) | (156) |
Net Assets (Liabilities) at end of period | (27) | 4 |
Recurring | Level 3 | DTE Electric | ||
Assets | ||
Cash equivalents | 0 | 0 |
Derivative assets | ||
Total assets | 7 | 3 |
Recurring | Level 3 | Current assets | ||
Derivative assets | ||
Total assets | 59 | 123 |
Recurring | Level 3 | Current assets | DTE Electric | ||
Derivative assets | ||
Total assets | 7 | 3 |
Recurring | Level 3 | Noncurrent assets | ||
Derivative assets | ||
Total assets | 24 | 37 |
Recurring | Level 3 | Noncurrent assets | DTE Electric | ||
Derivative assets | ||
Total assets | 0 | 0 |
Recurring | Level 3 | Current liabilities | ||
Derivative liabilities | ||
Derivative liabilities, gross | (66) | (85) |
Recurring | Level 3 | Noncurrent liabilities | ||
Derivative liabilities | ||
Derivative liabilities, gross | (44) | (71) |
Recurring | Level 3 | Natural gas | ||
Derivative assets | ||
Derivative assets, gross | 42 | 74 |
Derivative liabilities | ||
Derivative liabilities, gross | (81) | (89) |
Recurring | Level 3 | Electricity | ||
Derivative assets | ||
Derivative assets, gross | 34 | 83 |
Derivative liabilities | ||
Derivative liabilities, gross | (29) | (67) |
Recurring | Level 3 | Environmental & Other | ||
Derivative assets | ||
Derivative assets, gross | 7 | 3 |
Derivative liabilities | ||
Derivative liabilities, gross | 0 | 0 |
Recurring | Level 3 | Foreign currency exchange contracts | ||
Derivative assets | ||
Derivative assets, gross | 0 | 0 |
Derivative liabilities | ||
Derivative liabilities, gross | 0 | 0 |
Recurring | Level 3 | Derivative assets — FTRs | DTE Electric | ||
Derivative assets | ||
Derivative assets, net | 7 | 3 |
Recurring | Level 3 | Cash equivalents | ||
Assets | ||
Nuclear decommissioning trusts | 0 | 0 |
Other investments | 0 | 0 |
Recurring | Level 3 | Cash equivalents | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | 0 | 0 |
Other investments | 0 | 0 |
Recurring | Level 3 | Private equity and other | ||
Assets | ||
Nuclear decommissioning trusts | 0 | 0 |
Recurring | Level 3 | Private equity and other | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | 0 | 0 |
Recurring | Level 3 | Equity securities | ||
Assets | ||
Nuclear decommissioning trusts | 0 | 0 |
Other investments | 0 | 0 |
Recurring | Level 3 | Equity securities | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | 0 | 0 |
Other investments | 0 | 0 |
Recurring | Level 3 | Fixed income securities | ||
Assets | ||
Nuclear decommissioning trusts | 0 | 0 |
Other investments | 0 | 0 |
Recurring | Level 3 | Fixed income securities | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | 0 | 0 |
Recurring | Other | ||
Derivative assets | ||
Total assets | 299 | 43 |
Derivative liabilities | ||
Net Assets (Liabilities) at end of period | 299 | 43 |
Recurring | Other | DTE Electric | ||
Derivative assets | ||
Total assets | 299 | 43 |
Recurring | Other | Noncurrent assets | ||
Derivative assets | ||
Total assets | 299 | 43 |
Recurring | Other | Noncurrent assets | DTE Electric | ||
Derivative assets | ||
Total assets | 299 | 43 |
Recurring | Other | Private equity and other | ||
Assets | ||
Nuclear decommissioning trusts | 78 | 43 |
Recurring | Other | Private equity and other | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | 78 | $ 43 |
Recurring | Other | Equity securities | ||
Assets | ||
Nuclear decommissioning trusts | 141 | |
Recurring | Other | Equity securities | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | 141 | |
Recurring | Other | Fixed income securities | ||
Assets | ||
Nuclear decommissioning trusts | 80 | |
Recurring | Other | Fixed income securities | DTE Electric | ||
Assets | ||
Nuclear decommissioning trusts | $ 80 |
Fair Value (Details Textuals)
Fair Value (Details Textuals) - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2020 | Dec. 31, 2019 | |
Nuclear decommissioning trust fund | Fixed income securities | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Securities with no contractual maturity date | $ 80 | |
Equity or debt securities | Minimum | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Investments, redemption notice period | 7 days | |
Equity or debt securities | Maximum | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Investments, redemption notice period | 65 days | |
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 | $ 192 | $ 151 |
Private equity and other | Minimum | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Investments classified as NAV assets, general contractual durations | 7 years | |
Private equity and other | Maximum | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Investments classified as NAV assets, general contractual durations | 12 years |
Fair Value (Reconciliation of L
Fair Value (Reconciliation of Level 3 Assets and Liabilities at Fair Value on a Recurring Basis) (Details) - Recurring - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward] | ||||
Net Assets (Liabilities) as of beginning of period | $ 46 | $ 9 | $ 4 | $ (44) |
Transfers from Level 3 into Level 2 | (1) | 0 | (5) | 0 |
Total gains (losses) | ||||
Included in earnings | (42) | 2 | 39 | 42 |
Recorded in/Change in fair value recorded in Regulatory liabilities | 9 | (3) | 21 | 3 |
Purchases, issuances, and settlements | ||||
Settlements | (39) | (36) | (86) | (29) |
Net Assets (Liabilities) as of end of period | (27) | (28) | (27) | (28) |
Total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at September 30, 2020 and 2019 | (47) | (22) | 16 | 6 |
DTE Electric | ||||
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward] | ||||
Net Assets (Liabilities) as of beginning of period | 10 | 9 | 3 | 6 |
Total gains (losses) | ||||
Recorded in/Change in fair value recorded in Regulatory liabilities | 9 | (3) | 21 | 3 |
Purchases, issuances, and settlements | ||||
Settlements | (12) | (1) | (17) | (4) |
Net Assets (Liabilities) as of end of period | 7 | 5 | 7 | 5 |
The amount of total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets held at September 30, 2020 and 2019 and reflected in DTE Electric's Consolidated Statements of Financial Position | 0 | (1) | 7 | 5 |
Natural gas | ||||
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward] | ||||
Net Assets (Liabilities) as of beginning of period | 20 | (10) | (15) | (49) |
Transfers from Level 3 into Level 2 | (1) | 0 | (5) | 0 |
Total gains (losses) | ||||
Included in earnings | (80) | (35) | (44) | (4) |
Recorded in/Change in fair value recorded in Regulatory liabilities | 0 | 0 | 0 | 0 |
Purchases, issuances, and settlements | ||||
Settlements | 22 | 4 | 25 | 12 |
Net Assets (Liabilities) as of end of period | (39) | (41) | (39) | (41) |
Total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at September 30, 2020 and 2019 | (57) | (36) | (20) | (20) |
Electricity | ||||
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward] | ||||
Net Assets (Liabilities) as of beginning of period | 16 | 10 | 16 | (2) |
Transfers from Level 3 into Level 2 | 0 | 0 | 0 | 0 |
Total gains (losses) | ||||
Included in earnings | 37 | 37 | 90 | 47 |
Recorded in/Change in fair value recorded in Regulatory liabilities | 0 | 0 | 0 | 0 |
Purchases, issuances, and settlements | ||||
Settlements | (48) | (39) | (101) | (37) |
Net Assets (Liabilities) as of end of period | 5 | 8 | 5 | 8 |
Total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at September 30, 2020 and 2019 | 11 | 15 | 53 | 32 |
Other | ||||
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward] | ||||
Net Assets (Liabilities) as of beginning of period | 10 | 9 | 3 | 7 |
Transfers from Level 3 into Level 2 | 0 | 0 | 0 | 0 |
Total gains (losses) | ||||
Included in earnings | 1 | 0 | (7) | (1) |
Recorded in/Change in fair value recorded in Regulatory liabilities | 9 | (3) | 21 | 3 |
Purchases, issuances, and settlements | ||||
Settlements | (13) | (1) | (10) | (4) |
Net Assets (Liabilities) as of end of period | 7 | 5 | 7 | 5 |
Total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at September 30, 2020 and 2019 | $ (1) | $ (1) | $ (17) | $ (6) |
Fair Value (Unobservable Inputs
Fair Value (Unobservable Inputs related to Level 3 Assets and Liabilities) (Details) $ in Millions | Sep. 30, 2020USD ($)MWhMMBTU | Dec. 31, 2019USD ($)MMBTUMWh |
Unobservable Inputs Valuation Techniques [Line Items] | ||
Derivative Assets | $ 580 | $ 775 |
Derivative Liabilities | (564) | (770) |
Recurring | Level 3 | ||
Unobservable Inputs Valuation Techniques [Line Items] | ||
Derivative Assets | 83 | 160 |
Derivative Liabilities | (110) | (156) |
Natural gas | ||
Unobservable Inputs Valuation Techniques [Line Items] | ||
Derivative Assets | 240 | 355 |
Derivative Liabilities | (265) | (351) |
Natural gas | Recurring | Level 3 | ||
Unobservable Inputs Valuation Techniques [Line Items] | ||
Derivative Assets | 42 | 74 |
Derivative Liabilities | (81) | (89) |
Electricity | ||
Unobservable Inputs Valuation Techniques [Line Items] | ||
Derivative Assets | 137 | 306 |
Derivative Liabilities | (126) | (298) |
Electricity | Recurring | Level 3 | ||
Unobservable Inputs Valuation Techniques [Line Items] | ||
Derivative Assets | 34 | 83 |
Derivative Liabilities | $ (29) | $ (67) |
Forward basis price | Natural gas | Minimum | Discounted Cash Flow | Level 3 | ||
Unobservable Inputs Valuation Techniques [Line Items] | ||
Forward basis price | MMBTU | (1.10) | (1.78) |
Forward basis price | Natural gas | Maximum | Discounted Cash Flow | Level 3 | ||
Unobservable Inputs Valuation Techniques [Line Items] | ||
Forward basis price | MMBTU | 2.30 | 5.78 |
Forward basis price | Natural gas | Weighted Average | Discounted Cash Flow | Level 3 | ||
Unobservable Inputs Valuation Techniques [Line Items] | ||
Forward basis price | MMBTU | (0.06) | (0.09) |
Forward basis price | Electricity | Minimum | Discounted Cash Flow | Level 3 | ||
Unobservable Inputs Valuation Techniques [Line Items] | ||
Forward basis price | MWh | (9) | (10) |
Forward basis price | Electricity | Maximum | Discounted Cash Flow | Level 3 | ||
Unobservable Inputs Valuation Techniques [Line Items] | ||
Forward basis price | MWh | 6 | 6 |
Forward basis price | Electricity | Weighted Average | Discounted Cash Flow | Level 3 | ||
Unobservable Inputs Valuation Techniques [Line Items] | ||
Forward basis price | MWh | (1) | 0 |
Fair Value (Fair Value of Finan
Fair Value (Fair Value of Financial Instruments) (Details) - USD ($) $ in Millions | Sep. 30, 2020 | Dec. 31, 2019 |
Carrying amount | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Notes receivable — Other | $ 112 | $ 184 |
Short-term borrowings | 988 | 828 |
Notes payable — Other | 19 | 25 |
Long-term debt | 18,660 | 16,606 |
Carrying amount | DTE Electric | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Notes receivable — Other | 18 | 9 |
Short-term borrowings | 200 | 354 |
Notes payable — Other | 17 | 21 |
Long-term debt | 8,235 | 7,180 |
Carrying amount | DTE Electric | Affiliates | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Short-term borrowings | 104 | 97 |
Fair value | Level 1 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Notes receivable — Other | 0 | 0 |
Short-term borrowings | 0 | 0 |
Notes payable — Other | 0 | 0 |
Long-term debt | 2,398 | 2,572 |
Fair value | Level 1 | DTE Electric | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Notes receivable — Other | 0 | 0 |
Short-term borrowings | 0 | 0 |
Notes payable — Other | 0 | 0 |
Long-term debt | 0 | 0 |
Fair value | Level 1 | DTE Electric | Affiliates | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Short-term borrowings | 0 | 0 |
Fair value | Level 2 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Notes receivable — Other | 0 | 0 |
Short-term borrowings | 988 | 828 |
Notes payable — Other | 0 | 0 |
Long-term debt | 17,213 | 14,207 |
Fair value | Level 2 | DTE Electric | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Notes receivable — Other | 0 | 0 |
Short-term borrowings | 200 | 354 |
Notes payable — Other | 0 | 0 |
Long-term debt | 9,565 | 7,916 |
Fair value | Level 2 | DTE Electric | Affiliates | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Short-term borrowings | 0 | 0 |
Fair value | Level 3 | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Notes receivable — Other | 112 | 184 |
Short-term borrowings | 0 | 0 |
Notes payable — Other | 19 | 25 |
Long-term debt | 1,406 | 1,252 |
Fair value | Level 3 | DTE Electric | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Notes receivable — Other | 18 | 9 |
Short-term borrowings | 0 | 0 |
Notes payable — Other | 17 | 21 |
Long-term debt | 194 | 173 |
Fair value | Level 3 | DTE Electric | Affiliates | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ||
Short-term borrowings | $ 104 | $ 97 |
Fair Value (Fair Value of Nucle
Fair Value (Fair Value of Nuclear Decommissioning Trust Fund Assets) (Details) - USD ($) $ in Millions | Sep. 30, 2020 | Dec. 31, 2019 |
Debt Securities, Available-for-sale [Line Items] | ||
Nuclear decommissioning trust funds | $ 1,664 | $ 1,661 |
DTE Electric | ||
Debt Securities, Available-for-sale [Line Items] | ||
Nuclear decommissioning trust funds | 1,664 | 1,661 |
DTE Electric | Nuclear decommissioning trust fund | ||
Debt Securities, Available-for-sale [Line Items] | ||
Nuclear decommissioning trust funds | 1,664 | 1,661 |
DTE Electric | Nuclear decommissioning trust fund | Fermi 2 | ||
Debt Securities, Available-for-sale [Line Items] | ||
Nuclear decommissioning trust funds | 1,652 | 1,650 |
DTE Electric | Nuclear decommissioning trust fund | Fermi 1 | ||
Debt Securities, Available-for-sale [Line Items] | ||
Nuclear decommissioning trust funds | 3 | 3 |
DTE Electric | Nuclear decommissioning trust fund | Low-level radioactive waste | ||
Debt Securities, Available-for-sale [Line Items] | ||
Nuclear decommissioning trust funds | $ 9 | $ 8 |
Fair Value (Gains and Losses an
Fair Value (Gains and Losses and Proceeds from the Sale of Securities by the Nuclear Decommissioning Trust Funds) (Details) - DTE Electric - Nuclear decommissioning trust fund - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | |
Debt Securities, Available-for-sale [Line Items] | ||||
Realized gains | $ 38 | $ 15 | $ 172 | $ 43 |
Realized losses | (11) | (8) | (103) | (25) |
Proceeds from sale of securities | $ 816 | $ 198 | $ 2,054 | $ 594 |
Fair Value (Fair Value and Unre
Fair Value (Fair Value and Unrealized Gains and Losses for the Nuclear Decommissioning Trust Funds) (Details) - DTE Electric - Nuclear decommissioning trust fund - USD ($) $ in Millions | Sep. 30, 2020 | Dec. 31, 2019 |
Debt Securities, Available-for-sale [Line Items] | ||
Fair Value | $ 1,664 | $ 1,661 |
Fixed income securities, fair value | 527 | 538 |
Private equity and other, fair value | 78 | 43 |
Cash equivalents, fair value | 46 | 34 |
Unrealized Gains | 341 | 420 |
Fixed income securities, unrealized gains | 16 | 24 |
Unrealized Losses | (29) | (40) |
Fixed income securities, unrealized losses | (1) | (1) |
Equity securities | ||
Debt Securities, Available-for-sale [Line Items] | ||
Fair Value | 1,013 | 1,046 |
Unrealized Gains | 325 | 396 |
Unrealized Losses | $ (28) | $ (39) |
Fair Value (Fair Value of Fixed
Fair Value (Fair Value of Fixed Income Securities Held in Nuclear Decommissioning Trust Funds (Details) - Fixed income securities - Nuclear decommissioning trust fund $ in Millions | Sep. 30, 2020USD ($) |
Debt Securities, Available-for-sale [Line Items] | |
Due within one year | $ 92 |
Due after one through five years | 82 |
Due after five through ten years | 79 |
Due after ten years | 194 |
Available-for-sale securities total | $ 447 |
Fair Value (Gains (Losses) Rela
Fair Value (Gains (Losses) Related to the Trust) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | |
Rabbi Trust | ||||
Schedule of Investments [Line Items] | ||||
Gains (losses) related to the Trust | $ 2 | $ 3 | $ (7) | $ 27 |
Equity securities | ||||
Schedule of Investments [Line Items] | ||||
Gains (losses) related to the Trust | 2 | 1 | (4) | 18 |
Fixed income securities | ||||
Schedule of Investments [Line Items] | ||||
Gains (losses) related to the Trust | $ 0 | $ 2 | $ (3) | $ 9 |
Financial and Other Derivativ_3
Financial and Other Derivative Instruments (Fair Value of Derivative Instruments) (Details) - USD ($) $ in Millions | Sep. 30, 2020 | Dec. 31, 2019 |
Derivatives, Fair Value [Line Items] | ||
Derivative Assets | $ 580 | $ 775 |
Derivative Liabilities | (564) | (770) |
Current derivative assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Assets | 444 | 646 |
Current derivative liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Liabilities | (421) | (596) |
Noncurrent derivative assets | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Assets | 136 | 129 |
Noncurrent derivative liabilities | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Liabilities | (143) | (174) |
Foreign currency exchange contracts | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Assets | 2 | 1 |
Derivative Liabilities | (2) | 0 |
Natural gas | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Assets | 240 | 355 |
Derivative Liabilities | (265) | (351) |
Electricity | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Assets | 137 | 306 |
Derivative Liabilities | (126) | (298) |
Environmental & Other | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Assets | 201 | 113 |
Derivative Liabilities | (171) | (121) |
Derivatives designated as hedging instruments | Foreign currency exchange contracts | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Assets | 0 | 0 |
Derivative Liabilities | (1) | 0 |
Derivatives not designated as hedging instruments | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Assets | 580 | 775 |
Derivative Liabilities | (563) | (770) |
Derivatives not designated as hedging instruments | DTE Electric | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Assets | 7 | 3 |
Derivatives not designated as hedging instruments | Foreign currency exchange contracts | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Assets | 2 | 1 |
Derivative Liabilities | (1) | 0 |
Derivatives not designated as hedging instruments | Natural gas | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Assets | 240 | 355 |
Derivative Liabilities | (265) | (351) |
Derivatives not designated as hedging instruments | Electricity | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Assets | 137 | 306 |
Derivative Liabilities | (126) | (298) |
Derivatives not designated as hedging instruments | Environmental & Other | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Assets | 201 | 113 |
Derivative Liabilities | (171) | (121) |
Derivatives not designated as hedging instruments | FTRs — Other current assets | DTE Electric | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Assets | $ 7 | $ 3 |
Financial and Other Derivativ_4
Financial and Other Derivative Instruments (Details Textuals) - USD ($) | Sep. 30, 2020 | Dec. 31, 2019 |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | ||
Letters of credit that could be used to offset net derivative liabilities | $ 5,000,000 | $ 6,000,000 |
Letters of credit received that could be used to offset net derivative assets | 1,000,000 | $ 4,000,000 |
Contractual obligation to post collateral in event of downgrade to below investment grade | 377,000,000 | |
Derivative net liability position aggregate fair value | 472,000,000 | |
Collateral already posted fair value | 0 | |
Derivative net asset position, fair value | 445,000,000 | |
Remaining amount of offsets to derivative net liability positions for hard and soft trigger provisions | $ 27,000,000 |
Financial and Other Derivativ_5
Financial and Other Derivative Instruments (Net Cash Collateral Offsetting Arrangements) (Details) - USD ($) $ in Millions | Sep. 30, 2020 | Dec. 31, 2019 |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | ||
Cash collateral netted against Derivative assets | $ (26) | $ 0 |
Cash collateral recorded in Accounts receivable | 12 | 13 |
Cash collateral recorded in Accounts payable | (2) | (3) |
Total net cash collateral posted (received) | $ (16) | $ 10 |
Financial and Other Derivativ_6
Financial and Other Derivative Instruments (Netting Offsets of Derivative Assets and Liabilities) (Details) - USD ($) $ in Millions | Sep. 30, 2020 | Dec. 31, 2019 |
Derivative assets | ||
Gross Amounts of Recognized Assets (Liabilities) | $ 580 | $ 775 |
Gross Amounts Offset in the Consolidated Statements of Financial Position | (486) | (601) |
Derivative assets, net | 94 | 174 |
Derivative liabilities | ||
Gross Amounts of Recognized Assets (Liabilities) | (564) | (770) |
Gross Amounts Offset in the Consolidated Statements of Financial Position | 460 | 601 |
Derivative liabilities, net | (104) | (169) |
Natural gas | ||
Derivative assets | ||
Gross Amounts of Recognized Assets (Liabilities) | 240 | 355 |
Gross Amounts Offset in the Consolidated Statements of Financial Position | (194) | (266) |
Derivative assets, net | 46 | 89 |
Derivative liabilities | ||
Gross Amounts of Recognized Assets (Liabilities) | (265) | (351) |
Gross Amounts Offset in the Consolidated Statements of Financial Position | 185 | 266 |
Derivative liabilities, net | (80) | (85) |
Electricity | ||
Derivative assets | ||
Gross Amounts of Recognized Assets (Liabilities) | 137 | 306 |
Gross Amounts Offset in the Consolidated Statements of Financial Position | (106) | (225) |
Derivative assets, net | 31 | 81 |
Derivative liabilities | ||
Gross Amounts of Recognized Assets (Liabilities) | (126) | (298) |
Gross Amounts Offset in the Consolidated Statements of Financial Position | 104 | 225 |
Derivative liabilities, net | (22) | (73) |
Environmental & Other | ||
Derivative assets | ||
Gross Amounts of Recognized Assets (Liabilities) | 201 | 113 |
Gross Amounts Offset in the Consolidated Statements of Financial Position | (186) | (110) |
Derivative assets, net | 15 | 3 |
Derivative liabilities | ||
Gross Amounts of Recognized Assets (Liabilities) | (171) | (121) |
Gross Amounts Offset in the Consolidated Statements of Financial Position | 171 | 110 |
Derivative liabilities, net | 0 | (11) |
Foreign currency exchange contracts | ||
Derivative assets | ||
Gross Amounts of Recognized Assets (Liabilities) | 2 | 1 |
Gross Amounts Offset in the Consolidated Statements of Financial Position | 0 | 0 |
Derivative assets, net | 2 | 1 |
Derivative liabilities | ||
Gross Amounts of Recognized Assets (Liabilities) | (2) | 0 |
Gross Amounts Offset in the Consolidated Statements of Financial Position | 0 | 0 |
Derivative liabilities, net | $ (2) | $ 0 |
Financial and Other Derivativ_7
Financial and Other Derivative Instruments (Netting Offsets Reconciliation to Balance Sheet) (Details) - USD ($) $ in Millions | Sep. 30, 2020 | Dec. 31, 2019 |
Derivative Assets | ||
Derivative Assets | $ 580 | $ 775 |
Collateral adjustment | (26) | 0 |
Derivative assets, current | 65 | 133 |
Derivative assets, noncurrent | 29 | 41 |
Derivative Liabilities | ||
Derivative Liabilities | (564) | (770) |
Derivative liabilities, current | (60) | (83) |
Derivative liabilities, noncurrent | (44) | (86) |
Current derivative assets | ||
Derivative Assets | ||
Derivative Assets | 444 | 646 |
Counterparty netting | (361) | (513) |
Collateral adjustment | (18) | 0 |
Derivative assets, current | 65 | 133 |
Noncurrent derivative assets | ||
Derivative Assets | ||
Derivative Assets | 136 | 129 |
Counterparty netting | (99) | (88) |
Collateral adjustment | (8) | 0 |
Derivative assets, noncurrent | 29 | 41 |
Current derivative liabilities | ||
Derivative Liabilities | ||
Derivative Liabilities | (421) | (596) |
Counterparty netting | 361 | 513 |
Collateral adjustment | 0 | 0 |
Derivative liabilities, current | (60) | (83) |
Noncurrent derivative liabilities | ||
Derivative Liabilities | ||
Derivative Liabilities | (143) | (174) |
Counterparty netting | 99 | 88 |
Collateral adjustment | 0 | 0 |
Derivative liabilities, noncurrent | $ (44) | $ (86) |
Financial and Other Derivativ_8
Financial and Other Derivative Instruments (Effect of Derivatives not Designated as Hedging Instruments on the Consolidated Statement of Operations) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | |
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain (Loss) Recognized in Income on Derivatives | $ (45) | $ (8) | $ 0 | $ 5 |
Natural gas | Operating Revenues — Non-utility operations | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain (Loss) Recognized in Income on Derivatives | (27) | (5) | (63) | 4 |
Natural gas | Fuel, purchased power, and gas — non-utility | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain (Loss) Recognized in Income on Derivatives | (51) | (47) | 28 | (7) |
Electricity | Operating Revenues — Non-utility operations | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain (Loss) Recognized in Income on Derivatives | 33 | 54 | 75 | 21 |
Environmental & Other | Operating Revenues — Non-utility operations | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain (Loss) Recognized in Income on Derivatives | 2 | (11) | (40) | (11) |
Foreign currency exchange contracts | Operating Revenues — Non-utility operations | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain (Loss) Recognized in Income on Derivatives | $ (2) | $ 1 | $ 0 | $ (2) |
Financial and Other Derivativ_9
Financial and Other Derivative Instruments (Cumulative Gross Volume of Derivative Contracts Outstanding) (Details) | 9 Months Ended |
Sep. 30, 2020CAD ($)MWhMMBTUT | |
Natural gas (MMBtu) | |
Derivative [Line Items] | |
Commodity, energy measures | MMBTU | 1,739,656,507 |
Electricity (MWh) | |
Derivative [Line Items] | |
Commodity, energy measures | 28,258,929 |
Foreign currency exchange (CAD) | |
Derivative [Line Items] | |
Commodity, monetary measure | $ | $ 154,336,963 |
Renewable Energy Certificates (MWh) | |
Derivative [Line Items] | |
Commodity, energy measures | 7,893,076 |
Carbon emissions (Metric Ton) | |
Derivative [Line Items] | |
Commodity, mass measure | T | 16,451,411 |
Long-Term Debt (Schedule of Iss
Long-Term Debt (Schedule of Issued Debt) (Details) | 9 Months Ended |
Sep. 30, 2020USD ($) | |
Debt Instrument [Line Items] | |
Debt issued | $ 2,750,000,000 |
Repayment of debt | $ 682,000,000 |
Senior Notes | August 2020 1.05% Mortgage Bonds Maturing 2025 | |
Debt Instrument [Line Items] | |
Interest rate | 1.05% |
Debt issued | $ 800,000,000 |
DTE Electric | Mortgage Bonds | February 2020 2.25% Mortgage Bonds Maturing 2030 | |
Debt Instrument [Line Items] | |
Interest rate | 2.25% |
Debt issued | $ 600,000,000 |
DTE Electric | Mortgage Bonds | February 2020 2.95% Mortgage Bonds Maturing 2050 | |
Debt Instrument [Line Items] | |
Interest rate | 2.95% |
Debt issued | $ 500,000,000 |
DTE Electric | Mortgage Bonds | April 2020 2.63% Mortgage Bonds Maturing 2031 | |
Debt Instrument [Line Items] | |
Interest rate | 2.63% |
Debt issued | $ 600,000,000 |
DTE Electric | Senior Notes | 4.89% Senior Notes Maturing 2020 | |
Debt Instrument [Line Items] | |
Interest rate | 4.89% |
Repayment of debt | $ 300,000,000 |
DTE Electric | Senior Notes | 2010 Series B 3.45% Senior Notes Due 2020 | |
Debt Instrument [Line Items] | |
Interest rate | 3.45% |
Repayment of debt | $ 300,000,000 |
DTE Electric | Senior Notes | 2008 Series KT Variable Rate Senior Notes Due 2020 | |
Debt Instrument [Line Items] | |
Repayment of debt | $ 32,000,000 |
DTE Electric | Senior Notes | 6.36% Senior Notes Maturing 2020 | |
Debt Instrument [Line Items] | |
Interest rate | 6.36% |
Repayment of debt | $ 50,000,000 |
DTE Gas | Mortgage Bonds | August 2020 2.35% Mortgage Bonds Maturing 2030 | |
Debt Instrument [Line Items] | |
Interest rate | 2.35% |
Debt issued | $ 125,000,000 |
DTE Gas | Mortgage Bonds | August 2020 3.20% Mortgage Bonds Maturing 2050 | |
Debt Instrument [Line Items] | |
Interest rate | 3.20% |
Debt issued | $ 125,000,000 |
DTE Gas | Senior Notes | 6.36% Senior Notes Maturing 2020 | |
Debt Instrument [Line Items] | |
Interest rate | 6.36% |
Repayment of debt | $ 50,000,000 |
Long-Term Debt (Details Textual
Long-Term Debt (Details Textuals) - USD ($) | Oct. 22, 2020 | Oct. 27, 2020 | Sep. 30, 2020 | Sep. 30, 2020 | Sep. 30, 2019 | Jun. 30, 2020 | Mar. 31, 2020 |
Debt Instrument [Line Items] | |||||||
Face amount of loan | $ 2,750,000,000 | $ 2,750,000,000 | |||||
Amount drawn down on loan | 2,724,000,000 | $ 1,433,000,000 | |||||
Repayment of debt | $ 682,000,000 | ||||||
Unsecured Term Loan Maturing in March 2022 | Unsecured term loan | |||||||
Debt Instrument [Line Items] | |||||||
Face amount of loan | $ 200,000,000 | ||||||
Amount drawn down on loan | $ 0 | ||||||
October 2020 4.375% Junior Subordinated Debentures Due 2080 | Junior Subordinated Debentures | Subsequent Event | |||||||
Debt Instrument [Line Items] | |||||||
Face amount of loan | $ 230,000,000 | ||||||
Interest rate | 4.375% | ||||||
Series C, 2012, 5.25% Junior Subordinated Debentures Due 2062 [Member] | Junior Subordinated Debentures | Subsequent Event | |||||||
Debt Instrument [Line Items] | |||||||
Interest rate | 5.25% | ||||||
Repayment of debt | $ 200,000,000 | ||||||
October 2020 0.55% Senior Notes Maturing 2022 | Senior Notes | Subsequent Event | |||||||
Debt Instrument [Line Items] | |||||||
Face amount of loan | $ 750,000,000 | ||||||
Interest rate | 0.55% | ||||||
Unsecured term loan, expiring March 2021 | Unsecured term loan | |||||||
Debt Instrument [Line Items] | |||||||
Face amount of loan | $ 500,000,000 | ||||||
Unsecured term loan, expiring March 2021 | Unsecured term loan | Subsequent Event | |||||||
Debt Instrument [Line Items] | |||||||
Repayment of debt | $ 500,000,000 | ||||||
Unsecured term loan, expiring June 2021 | Unsecured term loan | |||||||
Debt Instrument [Line Items] | |||||||
Face amount of loan | $ 167,000,000 | ||||||
Unsecured term loan, expiring June 2021 | Unsecured term loan | Subsequent Event | |||||||
Debt Instrument [Line Items] | |||||||
Repayment of debt | $ 167,000,000 |
Long-Term Debt (Schedule of Deb
Long-Term Debt (Schedule of Debt Redeemed) (Details) $ in Millions | 9 Months Ended |
Sep. 30, 2020USD ($) | |
Debt Instrument, Redemption [Line Items] | |
Debt redeemed | $ 682 |
DTE Electric | Senior Notes | 4.89% Senior Notes Maturing 2020 | |
Debt Instrument, Redemption [Line Items] | |
Interest rate | 4.89% |
Debt redeemed | $ 300 |
DTE Electric | Senior Notes | 5.63% Senior Notes Maturing 2020 | |
Debt Instrument, Redemption [Line Items] | |
Interest rate | 5.63% |
Debt redeemed | $ 32 |
DTE Electric | Senior Notes | 3.45% Senior Notes Maturing 2020 | |
Debt Instrument, Redemption [Line Items] | |
Interest rate | 3.45% |
Debt redeemed | $ 300 |
DTE Electric | Senior Notes | 6.36% Senior Notes Maturing 2020 | |
Debt Instrument, Redemption [Line Items] | |
Interest rate | 6.36% |
Debt redeemed | $ 50 |
Short-Term Credit Arrangement_3
Short-Term Credit Arrangements and Borrowings (Details Textuals) | 1 Months Ended | 9 Months Ended | |||||||
Oct. 27, 2020USD ($) | Sep. 30, 2020USD ($) | Sep. 30, 2020CAD ($) | Jul. 31, 2020USD ($) | Jun. 30, 2020USD ($) | May 31, 2020CAD ($) | Apr. 30, 2020USD ($) | Mar. 31, 2020USD ($) | Dec. 31, 2019USD ($) | |
Short-term Debt [Line Items] | |||||||||
Face amount of loan | $ 2,750,000,000 | ||||||||
Amounts drawn | 988,000,000 | $ 828,000,000 | |||||||
Maximum borrowing capacity | 3,810,000,000 | ||||||||
Amounts outstanding | 1,200,000,000 | ||||||||
Debt redeemed | 682,000,000 | ||||||||
Unsecured term loan | |||||||||
Short-term Debt [Line Items] | |||||||||
Amounts outstanding | 967,000,000 | ||||||||
Revolving credit facility | |||||||||
Short-term Debt [Line Items] | |||||||||
Amounts outstanding | 21,000,000 | ||||||||
Letters of credit | |||||||||
Short-term Debt [Line Items] | |||||||||
Amounts outstanding | 212,000,000 | ||||||||
Unsecured term loan, expiring March 2021 | Unsecured term loan | |||||||||
Short-term Debt [Line Items] | |||||||||
Face amount of loan | $ 500,000,000 | ||||||||
Amounts drawn | 500,000,000 | ||||||||
Maximum borrowing capacity | 500,000,000 | ||||||||
Unsecured term loan, expiring March 2021 | Unsecured term loan | Subsequent Event | |||||||||
Short-term Debt [Line Items] | |||||||||
Debt redeemed | $ 500,000,000 | ||||||||
Unsecured Term Loan, Expiring April 2021 | Unsecured term loan | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity | 500,000,000 | ||||||||
Unsecured Canadian Revolving Credit Facility, Expiring May 2023 | Revolving credit facility | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity | 83,000,000 | ||||||||
Unsecured term loan, expiring June 2021 | Unsecured term loan | |||||||||
Short-term Debt [Line Items] | |||||||||
Face amount of loan | $ 167,000,000 | ||||||||
Maximum borrowing capacity | 167,000,000 | ||||||||
Unsecured term loan, expiring June 2021 | Unsecured term loan | Subsequent Event | |||||||||
Short-term Debt [Line Items] | |||||||||
Debt redeemed | 167,000,000 | ||||||||
DTE Energy | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity | 2,510,000,000 | ||||||||
Amounts outstanding | $ 900,000,000 | ||||||||
Ratio of indebtedness to net capital | 0.60 | 0.60 | |||||||
DTE Energy | Unsecured term loan | |||||||||
Short-term Debt [Line Items] | |||||||||
Amounts outstanding | $ 667,000,000 | ||||||||
DTE Energy | Revolving credit facility | |||||||||
Short-term Debt [Line Items] | |||||||||
Amounts outstanding | 21,000,000 | ||||||||
DTE Energy | Letters of credit | |||||||||
Short-term Debt [Line Items] | |||||||||
Amounts outstanding | 212,000,000 | ||||||||
DTE Energy | Demand financing agreement | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity, financing agreement | 300,000,000 | ||||||||
Amount outstanding | 43,000,000 | $ 114,000,000 | |||||||
DTE Energy | Unsecured term loan, expiring March 2021 | Unsecured term loan | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity | 500,000,000 | ||||||||
DTE Energy | Unsecured Term Loan, Expiring April 2021 | Unsecured term loan | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity | 0 | ||||||||
DTE Energy | Unsecured Canadian Revolving Credit Facility, Expiring May 2023 | Revolving credit facility | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity | 83,000,000 | ||||||||
DTE Energy | Unsecured term loan, expiring June 2021 | Unsecured term loan | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity | 167,000,000 | ||||||||
DTE Energy | Other outstanding letters of credit | Letters of credit | |||||||||
Short-term Debt [Line Items] | |||||||||
Amounts outstanding | 59,000,000 | ||||||||
DTE Energy | Uncommitted letter of credit facility, Expiring July 2021 | Letters of credit | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity | $ 50,000,000 | ||||||||
DTE Energy | Demand financing agreement, indefinite term | Demand financing agreement | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity, financing agreement | 100,000,000 | ||||||||
Maximum additional margin financing | 50,000,000 | ||||||||
DTE Energy | Demand financing agreement, expiring in 2022 | Demand financing agreement | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity, financing agreement | $ 150,000,000 | ||||||||
Maximum | |||||||||
Short-term Debt [Line Items] | |||||||||
Ratio of indebtedness to net capital | 0.65 | 0.65 | |||||||
DTE Electric | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity | $ 900,000,000 | ||||||||
Amounts outstanding | $ 200,000,000 | ||||||||
Ratio of indebtedness to net capital | 0.52 | 0.52 | |||||||
DTE Electric | Unsecured term loan | |||||||||
Short-term Debt [Line Items] | |||||||||
Amounts outstanding | $ 200,000,000 | ||||||||
DTE Electric | Revolving credit facility | |||||||||
Short-term Debt [Line Items] | |||||||||
Amounts outstanding | 0 | ||||||||
DTE Electric | Letters of credit | |||||||||
Short-term Debt [Line Items] | |||||||||
Amounts outstanding | 0 | ||||||||
DTE Electric | Unsecured term loan, expiring March 2021 | Unsecured term loan | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity | 0 | ||||||||
DTE Electric | Unsecured Term Loan, Expiring April 2021, Funded | Unsecured term loan | |||||||||
Short-term Debt [Line Items] | |||||||||
Face amount of loan | $ 200,000,000 | ||||||||
Amounts drawn | 200,000,000 | ||||||||
DTE Electric | Unsecured Term Loan, Expiring April 2021, Unfunded | Unsecured term loan | |||||||||
Short-term Debt [Line Items] | |||||||||
Face amount of loan | 200,000,000 | ||||||||
Amounts drawn | 0 | ||||||||
DTE Electric | Unsecured Term Loan, Expiring April 2021 | Unsecured term loan | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity | 400,000,000 | ||||||||
DTE Electric | Unsecured Canadian Revolving Credit Facility, Expiring May 2023 | Revolving credit facility | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity | 0 | ||||||||
DTE Electric | Unsecured term loan, expiring June 2021 | Unsecured term loan | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity | 0 | ||||||||
DTE Gas | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity | 400,000,000 | ||||||||
Amounts outstanding | $ 100,000,000 | ||||||||
Ratio of indebtedness to net capital | 0.49 | 0.49 | |||||||
DTE Gas | Unsecured term loan | |||||||||
Short-term Debt [Line Items] | |||||||||
Amounts outstanding | $ 100,000,000 | ||||||||
DTE Gas | Revolving credit facility | |||||||||
Short-term Debt [Line Items] | |||||||||
Amounts outstanding | 0 | ||||||||
DTE Gas | Letters of credit | |||||||||
Short-term Debt [Line Items] | |||||||||
Amounts outstanding | 0 | ||||||||
DTE Gas | Unsecured term loan, expiring March 2021 | Unsecured term loan | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity | 0 | ||||||||
DTE Gas | Unsecured Term Loan, Expiring April 2021 | Unsecured term loan | |||||||||
Short-term Debt [Line Items] | |||||||||
Face amount of loan | 100,000,000 | ||||||||
Amounts drawn | $ 100,000,000 | ||||||||
Maximum borrowing capacity | 100,000,000 | ||||||||
DTE Gas | Unsecured Term Loan, Expiring April 2021 | Unsecured term loan | Subsequent Event | |||||||||
Short-term Debt [Line Items] | |||||||||
Debt redeemed | $ 100,000,000 | ||||||||
DTE Gas | Unsecured Canadian Revolving Credit Facility, Expiring May 2023 | Revolving credit facility | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity | 0 | ||||||||
DTE Gas | Unsecured term loan, expiring June 2021 | Unsecured term loan | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity | $ 0 | ||||||||
DTE Lake Erie Generation, Inc | Unsecured Canadian Revolving Credit Facility, Expiring May 2023 | Revolving credit facility | |||||||||
Short-term Debt [Line Items] | |||||||||
Maximum borrowing capacity | $ 110,000,000 | ||||||||
Amounts outstanding | $ 28,000,000 |
Short-Term Credit Arrangement_4
Short-Term Credit Arrangements and Borrowings (Details) | Sep. 30, 2020USD ($) |
Availability under combined facilities | |
Maximum borrowing capacity | $ 3,810,000,000 |
Amounts outstanding | 1,200,000,000 |
Net availability | 2,610,000,000 |
DTE Electric | |
Availability under combined facilities | |
Maximum borrowing capacity | 900,000,000 |
Amounts outstanding | 200,000,000 |
Net availability | 700,000,000 |
DTE Gas | |
Availability under combined facilities | |
Maximum borrowing capacity | 400,000,000 |
Amounts outstanding | 100,000,000 |
Net availability | 300,000,000 |
DTE Energy | |
Availability under combined facilities | |
Maximum borrowing capacity | 2,510,000,000 |
Amounts outstanding | 900,000,000 |
Net availability | 1,610,000,000 |
Letters of credit | |
Availability under combined facilities | |
Amounts outstanding | 212,000,000 |
Letters of credit | DTE Electric | |
Availability under combined facilities | |
Amounts outstanding | 0 |
Letters of credit | DTE Gas | |
Availability under combined facilities | |
Amounts outstanding | 0 |
Letters of credit | DTE Energy | |
Availability under combined facilities | |
Amounts outstanding | 212,000,000 |
Unsecured term loan | |
Availability under combined facilities | |
Amounts outstanding | 967,000,000 |
Unsecured term loan | DTE Electric | |
Availability under combined facilities | |
Amounts outstanding | 200,000,000 |
Unsecured term loan | DTE Gas | |
Availability under combined facilities | |
Amounts outstanding | 100,000,000 |
Unsecured term loan | DTE Energy | |
Availability under combined facilities | |
Amounts outstanding | 667,000,000 |
Revolver borrowings | |
Availability under combined facilities | |
Amounts outstanding | 21,000,000 |
Revolver borrowings | DTE Electric | |
Availability under combined facilities | |
Amounts outstanding | 0 |
Revolver borrowings | DTE Gas | |
Availability under combined facilities | |
Amounts outstanding | 0 |
Revolver borrowings | DTE Energy | |
Availability under combined facilities | |
Amounts outstanding | 21,000,000 |
Unsecured letter of credit facility, expiring in February 2021 | Letters of credit | |
Availability under combined facilities | |
Maximum borrowing capacity | 150,000,000 |
Unsecured letter of credit facility, expiring in February 2021 | Letters of credit | DTE Electric | |
Availability under combined facilities | |
Maximum borrowing capacity | 0 |
Unsecured letter of credit facility, expiring in February 2021 | Letters of credit | DTE Gas | |
Availability under combined facilities | |
Maximum borrowing capacity | 0 |
Unsecured letter of credit facility, expiring in February 2021 | Letters of credit | DTE Energy | |
Availability under combined facilities | |
Maximum borrowing capacity | 150,000,000 |
Unsecured letter of credit facility, expiring in August 2021 | Letters of credit | |
Availability under combined facilities | |
Maximum borrowing capacity | 110,000,000 |
Unsecured letter of credit facility, expiring in August 2021 | Letters of credit | DTE Electric | |
Availability under combined facilities | |
Maximum borrowing capacity | 0 |
Unsecured letter of credit facility, expiring in August 2021 | Letters of credit | DTE Gas | |
Availability under combined facilities | |
Maximum borrowing capacity | 0 |
Unsecured letter of credit facility, expiring in August 2021 | Letters of credit | DTE Energy | |
Availability under combined facilities | |
Maximum borrowing capacity | 110,000,000 |
Unsecured term loan, expiring in March 2021 | Unsecured term loan | |
Availability under combined facilities | |
Maximum borrowing capacity | 500,000,000 |
Unsecured term loan, expiring in March 2021 | Unsecured term loan | DTE Electric | |
Availability under combined facilities | |
Maximum borrowing capacity | 0 |
Unsecured term loan, expiring in March 2021 | Unsecured term loan | DTE Gas | |
Availability under combined facilities | |
Maximum borrowing capacity | 0 |
Unsecured term loan, expiring in March 2021 | Unsecured term loan | DTE Energy | |
Availability under combined facilities | |
Maximum borrowing capacity | 500,000,000 |
Unsecured term loans, expiring in April 2021 | Unsecured term loan | |
Availability under combined facilities | |
Maximum borrowing capacity | 500,000,000 |
Unsecured term loans, expiring in April 2021 | Unsecured term loan | DTE Electric | |
Availability under combined facilities | |
Maximum borrowing capacity | 400,000,000 |
Unsecured term loans, expiring in April 2021 | Unsecured term loan | DTE Gas | |
Availability under combined facilities | |
Maximum borrowing capacity | 100,000,000 |
Unsecured term loans, expiring in April 2021 | Unsecured term loan | DTE Energy | |
Availability under combined facilities | |
Maximum borrowing capacity | 0 |
Unsecured term loan, expiring in June 2021 | Unsecured term loan | |
Availability under combined facilities | |
Maximum borrowing capacity | 167,000,000 |
Unsecured term loan, expiring in June 2021 | Unsecured term loan | DTE Electric | |
Availability under combined facilities | |
Maximum borrowing capacity | 0 |
Unsecured term loan, expiring in June 2021 | Unsecured term loan | DTE Gas | |
Availability under combined facilities | |
Maximum borrowing capacity | 0 |
Unsecured term loan, expiring in June 2021 | Unsecured term loan | DTE Energy | |
Availability under combined facilities | |
Maximum borrowing capacity | 167,000,000 |
Unsecured Canadian revolving credit facility, expiring May 2023 | Revolver borrowings | |
Availability under combined facilities | |
Maximum borrowing capacity | 83,000,000 |
Unsecured Canadian revolving credit facility, expiring May 2023 | Revolver borrowings | DTE Electric | |
Availability under combined facilities | |
Maximum borrowing capacity | 0 |
Unsecured Canadian revolving credit facility, expiring May 2023 | Revolver borrowings | DTE Gas | |
Availability under combined facilities | |
Maximum borrowing capacity | 0 |
Unsecured Canadian revolving credit facility, expiring May 2023 | Revolver borrowings | DTE Energy | |
Availability under combined facilities | |
Maximum borrowing capacity | 83,000,000 |
Unsecured revolving credit facility, expiring April 2024 | Revolver borrowings | |
Availability under combined facilities | |
Maximum borrowing capacity | 2,300,000,000 |
Unsecured revolving credit facility, expiring April 2024 | Revolver borrowings | DTE Electric | |
Availability under combined facilities | |
Maximum borrowing capacity | 500,000,000 |
Unsecured revolving credit facility, expiring April 2024 | Revolver borrowings | DTE Gas | |
Availability under combined facilities | |
Maximum borrowing capacity | 300,000,000 |
Unsecured revolving credit facility, expiring April 2024 | Revolver borrowings | DTE Energy | |
Availability under combined facilities | |
Maximum borrowing capacity | $ 1,500,000,000 |
Leases (Details Textuals)
Leases (Details Textuals) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||||
Sep. 30, 2020 | Jun. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | Mar. 31, 2020 | |
Leases [Abstract] | ||||||
Finance lease agreement, term (less than) | 2 years | |||||
Net investment in finance lease arrangement | $ 8 | |||||
Selling profit recognized | $ 11 | |||||
Net investment in finance lease arrangement | $ 133 | |||||
Interest income recognized under finance leases | $ 4 | $ 2 | $ 12 | $ 4 |
Leases (Components of Net Inves
Leases (Components of Net Investment in Finance Leases) (Details) $ in Millions | Sep. 30, 2020USD ($) |
Leases [Abstract] | |
2020 | $ 8 |
2021 | 24 |
2022 | 20 |
2023 | 19 |
2024 | 19 |
2025 and Thereafter | 273 |
Total minimum future lease receipts | 363 |
Residual value of leased pipeline | 19 |
Less unearned income | 201 |
Net investment in finance lease | 181 |
Less current portion | 10 |
Net investment in finance lease, noncurrent | $ 171 |
Leases (Lease Income Associated
Leases (Lease Income Associated with Operating Leases) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | |
Leases [Abstract] | ||||
Fixed payments | $ 17 | $ 17 | $ 50 | $ 51 |
Variable payments | 43 | 40 | 82 | 92 |
Total lease income under operating leases | $ 60 | $ 57 | $ 132 | $ 143 |
Commitments and Contingencies (
Commitments and Contingencies (Details Textuals) $ in Millions | Jul. 23, 2020USD ($) | Jun. 30, 2020 | Sep. 30, 2020USD ($)employeesitefacilityplant | May 31, 2020plant | Dec. 31, 2019USD ($) | Jul. 31, 2019CAD ($) | Jul. 31, 2009plant |
Loss Contingencies [Line Items] | |||||||
Estimated utility capital expenditures, expenditures for non-utility businesses, and contributions to equity method investees | $ 4,500 | ||||||
Power and Industrial Projects | |||||||
Loss Contingencies [Line Items] | |||||||
Number of generating plants operated with ownership interest held | plant | 5 | ||||||
Workforce subject to collective bargaining arrangements | Labor force concentration risk | |||||||
Loss Contingencies [Line Items] | |||||||
Number of employees | employee | 5,200 | ||||||
Synthetic fuel | |||||||
Loss Contingencies [Line Items] | |||||||
Number of days after expiration of statutes of limitations | 90 days | ||||||
Maximum potential liability | $ 400 | ||||||
Reduced emissions fuel guarantees | |||||||
Loss Contingencies [Line Items] | |||||||
Number of days after expiration of statutes of limitations | 90 days | ||||||
Maximum potential liability | $ 543 | ||||||
Other guarantees | |||||||
Loss Contingencies [Line Items] | |||||||
Maximum potential liability | 50 | ||||||
Performance surety bonds | |||||||
Loss Contingencies [Line Items] | |||||||
Performance bonds outstanding | $ 125 | ||||||
Reduction of Carbon Emissions by Early 2020s | |||||||
Loss Contingencies [Line Items] | |||||||
Commitment to reduce carbon emissions, percentage | 32.00% | ||||||
Reduction of Carbon Emissions by 2030 | |||||||
Loss Contingencies [Line Items] | |||||||
Commitment to reduce carbon emissions, percentage | 50.00% | ||||||
Reduction of Carbon Emissions by 2040 | |||||||
Loss Contingencies [Line Items] | |||||||
Commitment to reduce carbon emissions, percentage | 80.00% | ||||||
The Sierra Club | |||||||
Loss Contingencies [Line Items] | |||||||
Amount accrued for settlement | $ 5 | ||||||
DTE Gas | NEXUS pipeline | |||||||
Loss Contingencies [Line Items] | |||||||
Maximum potential liability | $ 226 | ||||||
Guarantee termination, minimum threshold, period following end of primary term of capacity lease agreements | 2 months | ||||||
Texas Eastern Transmission, LP | NEXUS pipeline | |||||||
Loss Contingencies [Line Items] | |||||||
Maximum potential liability | $ 360 | ||||||
Percentage of payment obligations due | 50.00% | ||||||
Guarantee termination, minimum threshold, period following end of primary term of capacity lease agreements | 2 months | ||||||
Vector | Revolving Term Credit Facility | |||||||
Loss Contingencies [Line Items] | |||||||
Revolving term credit facility amount | $ 70,000,000 | ||||||
Maximum potential payments under line of credit | $ 52 | ||||||
Vector | NEXUS pipeline | |||||||
Loss Contingencies [Line Items] | |||||||
Maximum potential liability | $ 7 | ||||||
Percentage of payment obligations due | 50.00% | ||||||
Guarantee termination, minimum threshold, period following end of primary term of capacity lease agreements | 15 years | ||||||
DTE Electric | |||||||
Loss Contingencies [Line Items] | |||||||
Number of power plants in violation | plant | 5 | ||||||
Number of power plants with requirement to retire, repower, refuel or retrofit units | plant | 4 | ||||||
Environmental capital expenditures | $ 2,400 | ||||||
Number of former MGP sites | site | 3 | ||||||
Accrued for remediation | $ 6 | $ 8 | |||||
Number of permitted engineered ash storage facilities owned | facility | 3 | ||||||
Estimated utility capital expenditures, expenditures for non-utility businesses, and contributions to equity method investees | $ 2,600 | ||||||
DTE Electric | Workforce subject to collective bargaining arrangements | Labor force concentration risk | |||||||
Loss Contingencies [Line Items] | |||||||
Number of employees | employee | 2,800 | ||||||
DTE Electric | Performance surety bonds | |||||||
Loss Contingencies [Line Items] | |||||||
Performance bonds outstanding | $ 69 | ||||||
DTE Electric | Reduction of Carbon Emissions by 2050 | |||||||
Loss Contingencies [Line Items] | |||||||
Goal of net carbon emissions, percentage | 0.00% | ||||||
DTE Electric | Coal Combustion Residual Rule | |||||||
Loss Contingencies [Line Items] | |||||||
Estimated impact of the current rule | $ 629 | ||||||
DTE Electric | The Sierra Club | |||||||
Loss Contingencies [Line Items] | |||||||
Amount paid related to settlement | $ 2 | ||||||
DTE Gas | |||||||
Loss Contingencies [Line Items] | |||||||
Number of former MGP sites | site | 14 | ||||||
Accrued for remediation | $ 24 | $ 25 | |||||
Amortization period (in years) | 10 years | ||||||
DTE Gas | Clean up completed and site closed | |||||||
Loss Contingencies [Line Items] | |||||||
Number of former MGP sites | site | 8 | ||||||
DTE Gas | Partial closure complete | |||||||
Loss Contingencies [Line Items] | |||||||
Number of former MGP sites | site | 4 | ||||||
DTE Gas | Reduction of Greenhouse Gas Emissions by 2050 | |||||||
Loss Contingencies [Line Items] | |||||||
Goal of net greenhouse gas emissions, percentage | 0.00% | ||||||
DTE Gas | DTE Gas | NEXUS pipeline | |||||||
Loss Contingencies [Line Items] | |||||||
Percentage of payment obligations due | 50.00% | ||||||
NEXUS | DTE Gas | NEXUS pipeline | |||||||
Loss Contingencies [Line Items] | |||||||
Agreement term | 15 years | ||||||
NEXUS | Texas Eastern Transmission, LP | NEXUS pipeline | |||||||
Loss Contingencies [Line Items] | |||||||
Agreement term | 15 years | ||||||
NEXUS | Vector | NEXUS pipeline | |||||||
Loss Contingencies [Line Items] | |||||||
Agreement term | 15 years |
Retirement Benefits and Trust_3
Retirement Benefits and Trusteed Assets (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | |
Pension Benefits | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Service cost | $ 25 | $ 21 | $ 74 | $ 63 |
Interest cost | 46 | 55 | 139 | 164 |
Expected return on plan assets | (84) | (82) | (250) | (244) |
Amortization of net actuarial loss | 43 | 33 | 129 | 99 |
Amortization of prior service credit | 0 | 0 | 0 | 0 |
Settlements | 2 | 0 | 2 | 0 |
Net periodic benefit cost (credit) | 32 | 27 | 94 | 82 |
Other Postretirement Benefits | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Service cost | 7 | 5 | 20 | 16 |
Interest cost | 14 | 18 | 42 | 53 |
Expected return on plan assets | (32) | (30) | (96) | (92) |
Amortization of net actuarial loss | 4 | 3 | 12 | 9 |
Amortization of prior service credit | (5) | (3) | (15) | (7) |
Settlements | 0 | 0 | 0 | 0 |
Net periodic benefit cost (credit) | (12) | (7) | (37) | (21) |
Other Postretirement Benefits | DTE Electric | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Service cost | 5 | 4 | 15 | 12 |
Interest cost | 11 | 13 | 32 | 40 |
Expected return on plan assets | (21) | (21) | (65) | (63) |
Amortization of net actuarial loss | 2 | 1 | 8 | 3 |
Amortization of prior service credit | (3) | (1) | (10) | (5) |
Net periodic benefit cost (credit) | $ (6) | $ (4) | $ (20) | $ (13) |
Retirement Benefits and Trust_4
Retirement Benefits and Trusteed Assets (Details Textuals) - USD ($) | Sep. 08, 2020 | Sep. 30, 2020 | Sep. 30, 2020 | Sep. 30, 2019 | Mar. 31, 2019 | Sep. 30, 2020 | Sep. 30, 2019 |
Defined Benefit Plan Disclosure [Line Items] | |||||||
Contribution of common stock to pension plan | $ 82,000,000 | $ 100,000,000 | |||||
Qualified Plan | |||||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Cash contribution | $ 2,000,000 | ||||||
Pension Benefits | |||||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Contribution of common stock to pension plan | $ 82,000,000 | ||||||
Pension Benefits | Qualified Plan | |||||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Contributions by employer | 84,000,000 | ||||||
Contribution of common stock to pension plan | 82,000,000 | ||||||
Other Postretirement Benefits | |||||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Anticipated contributions, remainder of fiscal year | $ 0 | 0 | 0 | ||||
DTE Electric | Pension Benefits | |||||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Pension cost | $ 28,000,000 | $ 23,000,000 | $ 79,000,000 | $ 68,000,000 | |||
Cash contribution | 60,000,000 | ||||||
DTE Gas | Pension Benefits | |||||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Cash contribution | $ 22,000,000 |
Retirement Benefits and Trust_5
Retirement Benefits and Trusteed Assets (Contributions to DTE Energy Company Affiliates Employee Benefit Plans Master Trust) (Details) - USD ($) $ / shares in Units, $ in Millions | Sep. 08, 2020 | Sep. 30, 2020 | Mar. 31, 2019 |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Contribution of common stock to pension plan | $ 82 | $ 100 | |
Pension Benefits | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Number of Shares (in shares) | 694,444 | ||
Price per Share (in dollars per share) | $ 118.08 | ||
Contribution of common stock to pension plan | $ 82 |
Segment and Related Informati_3
Segment and Related Information (Details Textuals) customer in Millions | Sep. 30, 2020customer |
Segment Reporting [Abstract] | |
Number of electric utility customers | 2.2 |
Number of gas utility customers | 1.3 |
Segment and Related Informati_4
Segment and Related Information (Financial Data - Inter-segment Billing) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | |
Segment Reporting Information [Line Items] | ||||
Revenues | $ (3,284) | $ (3,119) | $ (8,889) | $ (9,521) |
Electric | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | (1,693) | (1,520) | (4,221) | (3,945) |
Gas | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | (173) | (155) | (964) | (1,043) |
Gas Storage and Pipelines | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | (204) | (126) | (546) | (363) |
Power and Industrial Projects | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | (324) | (406) | (850) | (1,196) |
Energy Trading | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | (1,061) | (1,105) | (2,714) | (3,519) |
Reconciliation and Eliminations | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 172 | 195 | 408 | 548 |
Reconciliation and Eliminations | Electric | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 16 | 16 | 46 | 43 |
Reconciliation and Eliminations | Gas | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 4 | 3 | 12 | 8 |
Reconciliation and Eliminations | Gas Storage and Pipelines | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 8 | 11 | 17 | 17 |
Reconciliation and Eliminations | Power and Industrial Projects | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 134 | 160 | 308 | 462 |
Reconciliation and Eliminations | Energy Trading | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 9 | 4 | 23 | 16 |
Reconciliation and Eliminations | Corporate and Other | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | $ 1 | $ 1 | $ 2 | $ 2 |
Segment and Related Informati_5
Segment and Related Information (Financial Data - Operating Revenues including Inter-segment Revenues) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | |
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues — Utility operations | $ 1,844 | $ 1,656 | $ 5,119 | $ 4,937 |
Operating Revenues — Non-utility operations | 1,440 | 1,463 | 3,770 | 4,584 |
Operating Revenues | 3,284 | 3,119 | 8,889 | 9,521 |
Reconciliation and Eliminations | ||||
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues — Non-utility operations | (172) | (195) | (408) | (548) |
Operating Revenues | (172) | (195) | (408) | (548) |
Electric | ||||
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues | 1,693 | 1,520 | 4,221 | 3,945 |
Electric | Operating segments | ||||
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues — Utility operations | 1,690 | 1,520 | 4,211 | 3,945 |
Operating Revenues — Non-utility operations | 3 | 0 | 10 | 0 |
Electric | Reconciliation and Eliminations | ||||
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues | (16) | (16) | (46) | (43) |
Gas | ||||
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues | 173 | 155 | 964 | 1,043 |
Gas | Operating segments | ||||
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues — Utility operations | 173 | 155 | 964 | 1,043 |
Gas | Reconciliation and Eliminations | ||||
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues | (4) | (3) | (12) | (8) |
Gas Storage and Pipelines | ||||
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues | 204 | 126 | 546 | 363 |
Gas Storage and Pipelines | Operating segments | ||||
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues — Non-utility operations | 204 | 126 | 546 | 363 |
Gas Storage and Pipelines | Reconciliation and Eliminations | ||||
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues | (8) | (11) | (17) | (17) |
Power and Industrial Projects | ||||
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues | 324 | 406 | 850 | 1,196 |
Power and Industrial Projects | Operating segments | ||||
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues — Non-utility operations | 324 | 406 | 850 | 1,196 |
Power and Industrial Projects | Reconciliation and Eliminations | ||||
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues | (134) | (160) | (308) | (462) |
Energy Trading | ||||
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues | 1,061 | 1,105 | 2,714 | 3,519 |
Energy Trading | Operating segments | ||||
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues — Non-utility operations | 1,061 | 1,105 | 2,714 | 3,519 |
Energy Trading | Reconciliation and Eliminations | ||||
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues | (9) | (4) | (23) | (16) |
Corporate and Other | Operating segments | ||||
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues — Non-utility operations | 1 | 2 | 2 | 3 |
Corporate and Other | Reconciliation and Eliminations | ||||
Segment Reporting, Revenue Reconciling Item [Line Items] | ||||
Operating Revenues | $ (1) | $ (1) | $ (2) | $ (2) |
Segment and Related Informati_6
Segment and Related Information (Financial Data - Net Income (Loss) Attributable to DTE Energy by Segment) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | |
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items] | ||||
Net Income Attributable to DTE Energy Company | $ 476 | $ 319 | $ 1,093 | $ 902 |
Electric | ||||
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items] | ||||
Net Income Attributable to DTE Energy Company | 398 | 307 | 675 | 587 |
Gas | ||||
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items] | ||||
Net Income Attributable to DTE Energy Company | (20) | (38) | 102 | 121 |
Gas Storage and Pipelines | ||||
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items] | ||||
Net Income Attributable to DTE Energy Company | 104 | 60 | 246 | 158 |
Power and Industrial Projects | ||||
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items] | ||||
Net Income Attributable to DTE Energy Company | 47 | 49 | 102 | 104 |
Energy Trading | ||||
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items] | ||||
Net Income Attributable to DTE Energy Company | (28) | (14) | 5 | 12 |
Corporate and Other | ||||
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items] | ||||
Net Income Attributable to DTE Energy Company | $ (25) | $ (45) | $ (37) | $ (80) |
Related Party Transactions (Det
Related Party Transactions (Details) - NEXUS - Equity Method Investee | 9 Months Ended |
Sep. 30, 2020 | |
DTE Gas | Capacity Lease Agreement | |
Related Party Transaction [Line Items] | |
Term of related party agreement | 15 years |
DTE Gas | Service Agreement | |
Related Party Transaction [Line Items] | |
Term of related party agreement | 15 years |
DTE Electric | Service Agreement | |
Related Party Transaction [Line Items] | |
Term of related party agreement | 20 years |
Related Party Transactions (Sch
Related Party Transactions (Schedule of Related Party Transactions) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2020 | Sep. 30, 2019 | Sep. 30, 2020 | Sep. 30, 2019 | |
Related Party Transaction [Line Items] | ||||
Operating Revenues — Utility operations | $ 1,844 | $ 1,656 | $ 5,119 | $ 4,937 |
Fuel, purchased power, and gas — utility | 455 | 400 | 1,296 | 1,342 |
Fuel, purchased power, and gas — non-utility | 1,180 | 1,257 | 2,937 | 3,900 |
DTE Electric | ||||
Related Party Transaction [Line Items] | ||||
Operating Revenues — Utility operations | 1,690 | 1,519 | 4,211 | 3,944 |
Fuel, purchased power, and gas — utility | 451 | 399 | 1,090 | 1,067 |
NEXUS | DTE Gas | Equity Method Investee | ||||
Related Party Transaction [Line Items] | ||||
Operating Revenues — Utility operations | 8 | 8 | 24 | 24 |
Fuel, purchased power, and gas — utility | 2 | 2 | 14 | 15 |
NEXUS | DTE Electric | Equity Method Investee | ||||
Related Party Transaction [Line Items] | ||||
Fuel, purchased power, and gas — utility | 2 | 2 | 6 | 6 |
NEXUS | DTE Energy Trading | Equity Method Investee | ||||
Related Party Transaction [Line Items] | ||||
Fuel, purchased power, and gas — non-utility | $ 7 | $ 2 | $ 20 | $ 5 |