|
| | | |
| | 2018 |
| | (In millions) |
Unrealized Margins(a) | |
| Favorable results, primarily in the power trading strategy | $ | 20 |
|
Unfavorable results, primarily in gas structured, and power full requirements strategies(b) | (100 | ) |
| | (80 | ) |
Realized Margins(a) | |
| Favorable results, primarily in the gas structured strategy | 54 |
|
Unfavorable results, primarily in the power full requirements strategy(c) | (34 | ) |
| | 20 |
|
| Decrease in Non-utility Margin | $ | (60 | ) |
_______________________________________104 | | (a)Unfavorable results, primarily in environmental and gas trading, and power full requirements strategies | Natural gas structured transactions typically involve a physical purchase or sale of natural gas in the future and/or natural gas basis financial instruments which are derivatives and a related non-derivative pipeline transportation contract. These gas structured transactions can result in significant earnings volatility as the derivative components are marked-to-market without revaluing the related non-derivative contracts. |
| (28) | | (b) | Amount includes $74 million of timing related losses related to gas strategies which will reverse in future periods as the underlying contracts settle. |
| 76 | | (c)Realized Margins(a) | Amount includes $11 million of timing related gains related to | Favorable results, primarily in power full requirements, environmental trading, and gas transportation strategies recognized | 74 | | Unfavorable results, primarily in previous periods that reversed as the underlying contracts settled.gas structured and gas full requirements strategies(c) | (135) | | | (61) | | | Increase in Non-utility Margin | $ | 15 | |
(a)Natural gas structured transactions typically involve a physical purchase or sale of natural gas in the future and/or natural gas basis financial instruments which are derivatives and a related non-derivative pipeline transportation contract. These gas structured transactions can result in significant earnings volatility as the derivative components are marked-to-market without revaluing the related non-derivative contracts. (b)Amount includes $87 million of timing related losses related to gas strategies which will reverse in future periods as the underlying contracts settle. (c)Amount includes $61 million of timing related gains related to gas strategies recognized in previous periods that reversed as the underlying contracts settled. Outlook — In the near-term, Energy Trading expects market conditions to remain challenging. The profitability of this segment may be impacted by the volatility in commodity prices and the uncertainty of impacts associated with regulatory changes, and changes in operating rules of RTOs. Significant portions of the Energy Trading portfolio are economically hedged. Most financial instruments, physical power and natural gas contracts, and certain environmental contracts are deemed derivatives; whereas, natural gas and environmental inventory, contracts for pipeline transportation, storage assets, and some environmental contracts are not derivatives. As a result, Energy Trading will experience earnings volatility as derivatives are marked-to-market without revaluing the underlying non-derivative contracts and assets. Energy Trading's strategy is to economically manage the price risk of these underlying non-derivative contracts and assets with futures, forwards, swaps, and options. This results in gains and losses that are recognized in different interim and annual accounting periods. See also the "Fair Value" section herein and Notes 13 and 14 to the Consolidated Financial Statements in Item 8 of this Report, "Fair Value" and "Financial and Other Derivative Instruments," respectively.
CORPORATE AND OTHER Corporate and Other includes various holding company activities, holds certain non-utility debt, and holds energy-related investments. certain investments, including funds supporting regional development and economic growth. The 2020 net loss of $80 million represents a decrease of $36 million from the 2019 net loss of $116 million. This decrease was primarily due a tax adjustment recorded in 2020 pursuant to the CARES Act, which allowed the carryback of net operating losses five years for tax years 2018 through 2020. This enabled DTE Energy to carryback 2018 net operating losses to 2013 and resulted in a $34 million reduction to Income Tax Expense. Refer to Note 11 to the Consolidated Financial Statements in Item 8 of this Report, "Income Taxes", for additional information regarding the CARES Act and related impacts. The 2019 net loss of $116 million represents a decrease of $13 million from the 2018 net loss of $129 millionmillion. This decrease was primarily due to lower state income taxes and decreased contributions to not-for-profit organizations, partially offset by higher interest expense and impairment of an equity method investment. The 2018 net loss of $129 million represents an increase of $26 million from the 2017 net loss of $103 million primarily due to a reduction in the corporate tax rate from the TCJA in December 2017, higher interest expense and increased contributions to the DTE Energy Foundation and other not-for-profit organizations, partially offset by the remeasurement of deferred tax assets and liabilities to reflect the reduction in the corporate tax rate from the enactment of the TCJA in 2017. See Note 11 to the Consolidated Financial Statements in Item 8 of this Report, "Income Taxes."
CAPITAL RESOURCES AND LIQUIDITY Cash Requirements DTE Energy uses cash to maintain and invest in the electric and natural gas utilities, to grow the non-utility businesses, to retire and pay interest on long-term debt, and to pay dividends. DTE Energy believes it will have sufficient internal and external capital resources to fund anticipated capital and operating requirements. DTE Energy expects that cash from operations in 20202021 will be approximately $3.0 billion. DTE Energy anticipates base level utility capital investments, including environmental, renewable, and energy waste reduction expenditures; expenditures for non-utility businesses; and contributions to equity method investees in 20202021 of approximately $4.5$4.2 billion. DTE Energy plans to seek regulatory approval to include utility capital expenditures in regulatory rate base consistent with prior treatment. Capital spending for growth of existing or new non-utility businesses will depend on the existence of opportunities that meet strict risk-return and value creation criteria. Refer to the "Capital Investments" section above for additional information on DTE Energy's capital strategy and estimated spend over the next five years. Any capital commitments are also included in the disclosure of Purchase Commitments within Note 19 to the Consolidated Financial Statements, "Commitments and Contingencies." | | | | 2019 | | 2018 | | 2017 | | 2020 | | 2019 | | 2018 | | | (In millions) | | (In millions) | | Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | $ | 76 |
| | $ | 89 |
| | $ | 113 |
| Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | $ | 93 | | | $ | 76 | | | $ | 89 | | | Net cash from operating activities | 2,649 |
| | 2,680 |
| | 2,117 |
| Net cash from operating activities | 3,697 | | | 2,649 | | | 2,680 | | | Net cash used for investing activities | (5,732 | ) | | (3,347 | ) | | (2,562 | ) | Net cash used for investing activities | (4,070) | | | (5,732) | | | (3,347) | | | Net cash from financing activities | 3,100 |
| | 654 |
| | 421 |
| Net cash from financing activities | 796 | | | 3,100 | | | 654 | | | Net Increase (Decrease) in Cash, Cash Equivalents, and Restricted Cash | 17 |
| | (13 | ) | | (24 | ) | Net Increase (Decrease) in Cash, Cash Equivalents, and Restricted Cash | 423 | | | 17 | | | (13) | | | Cash, Cash Equivalents, and Restricted Cash at End of Period | $ | 93 |
| | $ | 76 |
| | $ | 89 |
| Cash, Cash Equivalents, and Restricted Cash at End of Period | $ | 516 | | | $ | 93 | | | $ | 76 | |
Cash from Operating Activities A majority of DTE Energy's operating cash flows are provided by the electric and natural gas utilities, which are significantly influenced by factors such as weather, electric retail access, regulatory deferrals, regulatory outcomes, economic conditions, changes in working capital, and operating costs. Net cash from operations increased $1.0 billion in 2020. The increase was primarily due to an increase in Net Income, Depreciation and amortization, and cash from tax refunds and working capital items. Net cash from operations decreased $31 million in 2019. The reduction iswas primarily due to a decrease in cash from working capital items, partially offset by an increase in non-cash and non-operating items, primarily Deferred income taxes and Depreciation and amortization. Net cash from operations increased $563 million
The change in 2018. The increaseworking capital items in operating cash flows reflects2020 was primarily due to an increase in adjustments for non-cashcash related to Accounts receivable, net, Accounts payable, and non-operating items, primarily DepreciationOther current and amortizationnoncurrent assets and working capital adjustments,liabilities, partially offset by a decrease in cash related to Deferred income taxes. Prepaid postretirement benefit costs and Regulatory assets and liabilities. The change in working capital items in 2019 was primarily related to an increase in cash used for Accounts payable and Other current and noncurrent assets and liabilities, partially offset by an increase in cash received related to Accounts receivable, net, Accrued pension and postretirement costs, and Regulatory assets and liabilities. The change in working capital items in 2018 primarily related to increases in cash from Accounts receivable, Accrued pension liability, Derivative assets and liabilities, and Other current and noncurrent assets and liabilities, partially offset by increases of cash used for Equity earnings of equity method investees, Prepaid postretirement benefit costs, Accrued postretirement liability, and Regulatory assets and liabilities. Cash used for Investing Activities Cash inflows associated with investing activities are primarily generated from the sale of assets, while cash outflows are the result of plant and equipment expenditures and acquisitions. In any given year, DTE Energy looks to realize cash from under-performing or non-strategic assets or matured, fully valued assets. Capital spending within the utility businesses is primarily to maintain and improve electric generation and the electric and natural gas distribution infrastructure, and to comply with environmental regulations and renewable energy requirements.
Capital spending within the non-utility businesses is primarily for ongoing maintenance, expansion, and growth. DTE Energy looks to make growth investments that meet strict criteria in terms of strategy, management skills, risks, and returns. All new investments are analyzed for their rates of return and cash payback on a risk adjusted basis. DTE Energy has been disciplined in how it deploys capital and will not make investments unless they meet the criteria. For new business lines, DTE Energy initially invests based on research and analysis. DTE Energy starts with a limited investment, evaluates the results, and either expands or exits the business based on those results. In any given year, the amount of growth capital will be determined by the underlying cash flows of DTE Energy, with a clear understanding of any potential impact on its credit ratings. Net cash used for investing activities decreased $1.7 billion in 2020 due primarily to a decrease in Acquisitions related to business combinations, net of cash acquired, primarily driven by DTE Energy's acquisition of Blue Union and LEAP in 2019 for net cash of $2.3 billion. The decrease was also due to lower Contributions to equity method investees, partially offset by an increase in Plant and equipment expenditures. Net cash used for investing activities increased $2.4 billion in 2019 due primarily to DTE Energy's acquisitionsthe acquisition of midstream natural gas assetsBlue Union and renewable energy projects of $2.5 billion, net of cash acquired of $62 million as described in Note 4 to the Consolidated Financial Statements in Item 8 of this Report, "Acquisitions," as well as an increase inLEAP and higher Plant and equipment expenditures, partially offset by a reduction inlower Contributions to equity method investees. Net cash used for investing activities increased $785 million in 2018 due primarily to an increase in Plant and equipment expenditures and Contributions to equity method investees, principally to NEXUS.
Cash from Financing Activities DTE Energy relies on both short-term borrowing and long-term financing as a source of funding for capital requirements not satisfied by its operations. DTE Energy's strategy is to have a targeted debt portfolio blend of fixed and variable interest rates and maturity. DTE Energy targets balance sheet financial metrics to ensure it is consistent with the objective of a strong investment grade debt rating. Net cash from financing activities decreased $2.3 billion in 2020. The decrease was primarily due to the issuance of equity units and common stock associated with the acquisition of Blue Union and LEAP in 2019, as well as an increase in cash used for Short-term borrowings, net and the Acquisition related deferred payment in 2020. These decreases were partially offset by higher cash from Issuances of long-term debt, net of issuance costs and lower Purchases of noncontrolling interest, principally SGG. Net cash from financing activities increased $2.4 billion in 2019. The increase was primarily due to an increase in Issuancescash from issuances of long-term debt, equity units, common stock, and Short-termshort-term borrowings, partially offset by an increase in cash used for Redemptions of long-term debt and Purchases of noncontrolling interests, principally related to SGG. The increased issuances in 2019 were primarily related to the acquisition of midstream natural gas assets. SeeBlue Union and LEAP. For further details, disclosed inrefer to the "Acquisition Financing" section of Note 15 to the Consolidated Financial Statements in Item 8. of this Report, "Long-Term Debt." Net cash from financing activities increased $233 million in 2018. The increase was primarily due to the reduction of Redemption of long-term debt and Repurchases of common stock and an increase in Issuance of long-term debt, partially offset by an increase in cash used for repayments of Short-term borrowings and an increase in Dividends on common stock.
Outlook DTE Energy expects cash flows from operations to increase over the long-term, primarily as a result of growth from the utility and non-utility businesses. Growth in the utilities is expected to be driven primarily by capital spending which will increase the base from which rates are determined. Non-utility growth is expected from additional investments, primarily in the Gas Storage and Pipelines and Power and Industrial Projects segments. Power and Industrial Projects cash flows are expected to temporarily decrease beginning in 2022 as REF facilities will have ceased operations. Growth from new industrial energy services projects and renewable energy investments are expected to offset these decreases over the long-term. DTE Energy's intention to spin-off the DTE Midstream business could also reduce cash flows if the separation transaction is completed. However, DTE Energy would still expect higher cash flows from operations over the long-term due to the growth of its utilities and other non-utility operations. DTE Energy will continue to assess the impact of the potential spin-off transaction on its cash flows, including any financing activity related to the separation of DTE Midstream. DTE Energy may be impacted by the timing of collection or refund of various recovery and tracking mechanisms as a result of timing of MPSC orders. Energy prices are likely to be a source of volatility with regard to working capital requirements for the foreseeable future. DTE Energy continues its efforts to identify opportunities to improve cash flows through working capital initiatives and maintaining flexibility in the timing and extent of long-term capital projects. DTE Energy has approximately $687$469 million in long-term debt, including finance leases, maturing in the next twelve months. The repayment of the debt is expected to be paidmade through internally generated funds or the issuance of new long-term debt. DTE Energy has approximately $1.6$3.1 billion of available liquidity at December 31, 2019,2020, consisting of cash and amounts available under unsecured revolving credit agreements. At the discretion of management and depending upon economic and financial market conditions, DTE Energy expects to issue equity up to $300$200 million in 2020. At the discretion of management, and depending upon financial market conditions,2021. If issued, DTE Energy anticipates up to $185$100 million of these equity issuances will be made through contributions to the qualified pension plans including $160 million ofat DTE Electric contributions.Electric. DTE Energy does not anticipate making any contributions to theits other postretirement benefit plans in 2020.2021. Any additional equity issuances are expected to be made through the dividend reinvestment plan and other employee benefit plans.
To finance the acquisition of midstream natural gas assets in December 2019, DTE Energy issued equity units that will result in the issuance of common stock in November 2022. This transaction is not expected to impact DTE Energy's cash flows. Future cash flow impacts will relate primarily to the payment of DTE Energy's remaining stock purchase liability associated with the equity units. Refer to Note 15 to the Consolidated Financial Statements, "Long-Term Debt," for additional information. Over the long-term, DTE Energy does not have any other equity commitments and will continue to evaluate equity needs on an annual basis in consideration of economic and financial market conditions.
Various subsidiaries and equity investees 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 December 31, 2019,2020, 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 $527$428 million.
DTE Energy is actively monitoring the impact of the COVID-19 pandemic on capital markets and any related effects to our cost of capital. During 2020, concerns over the pandemic led to an impact in liquidity in the commercial paper market and increases to related borrowing costs. Despite these impacts, the Registrants have maintained adequate liquidity due to the availability of committed credit facilities, and by raising additional liquidity through term loans and the public issuance of debt, while paying off maturing commercial paper. DTE Energy believes it will have sufficient operating flexibility, cash resources and funding sources to maintain adequate amounts of liquidity and to meet future operating cash and capital expenditure needs. However, virtually all DTE Energy's businesses are capital intensive, or require access to capital, and the inability to access adequate capital could adversely impact earnings and cash flows. See Notes 10, 11, 15, 17, 19, and 21 to the Consolidated Financial Statements in Item 8 of this Report, "Regulatory Matters," "Income Taxes," "Long-Term Debt," "Short-Term Credit Arrangements and Borrowings," "Commitments and Contingencies," and "Retirement Benefits and Trusteed Assets," respectively.
Contractual Obligations The following table details DTE Energy's, including DTE Electric's, contractual obligations for debt redemptions, leases, purchase obligations, and other long-term obligations as of December 31, 2019:2020: | | | | Total | | 2020 | | 2021-2022 | | 2023-2024 | | 2025 and Thereafter | | Total | | 2021 | | 2022-2023 | | 2024-2025 | | 2026 and Thereafter | | | (In millions) | | (In millions) | | Long-term debt: | | | | | | | | | | Long-term debt: | | Mortgage bonds, notes, and other(a) | $ | 15,575 |
| | $ | 682 |
| | $ | 3,178 |
| | $ | 2,602 |
| | $ | 9,113 |
| Mortgage bonds, notes, and other(a) | $ | 18,393 | | | $ | 462 | | | $ | 4,643 | | | $ | 2,645 | | | $ | 10,643 | | | Junior subordinated debentures(b) | 1,180 |
| | — |
| | — |
| | — |
| | 1,180 |
| Junior subordinated debentures(b) | 1,210 | | | — | | | — | | | — | | | 1,210 | | | Finance lease obligations | 17 |
| | 5 |
| | 6 |
| | 2 |
| | 4 |
| Finance lease obligations | 34 | | | 8 | | | 16 | | | 3 | | | 7 | | | Interest | 11,221 |
| | 652 |
| | 1,210 |
| | 1,012 |
| | 8,347 |
| Interest | 11,655 | | | 682 | | | 1,251 | | | 1,029 | | | 8,693 | | Stock purchase contract | 156 |
| | 52 |
| | 104 |
| | — |
| | — |
| 104 | | | 52 | | | 52 | | | — | | | — | | | Operating leases | 193 |
| | 38 |
| | 56 |
| | 32 |
| | 67 |
| Operating leases | 172 | | | 37 | | | 53 | | | 21 | | | 61 | | Electric, gas, fuel, transportation, and storage purchase obligations(c)(d) | 4,720 |
| | 1,849 |
| | 1,406 |
| | 607 |
| | 858 |
| 5,144 | | | 2,048 | | | 1,663 | | | 661 | | | 772 | | Long-term DTE Electric renewable energy power purchase agreements(e)(f) | 1,028 |
| | 80 |
| | 160 |
| | 160 |
| | 628 |
| 1,291 | | | 81 | | | 180 | | | 186 | | | 844 | | Other long-term obligations(f)(g)(h) | 1,316 |
| | 1,223 |
| | 60 |
| | 16 |
| | 17 |
| | | Other purchase obligations | | Other purchase obligations | 1,060 | | | 869 | | | 103 | | | 70 | | | 18 | | Total obligations | $ | 35,406 |
| | $ | 4,581 |
| | $ | 6,180 |
| | $ | 4,431 |
| | $ | 20,214 |
| $ | 39,063 | | | $ | 4,239 | | | $ | 7,961 | | | $ | 4,615 | | | $ | 22,248 | |
| | (a) | Excludes $24(a)Excludes $25 million of unamortized debt discount and $104 million of unamortized debt discount and $91 million of unamortized debt issuance costs. |
| | (b) | Excludes $34 million of unamortized debt issuance costs.
(b)Excludes $35 million of unamortized debt issuance costs. (c)Includes $3 million of interest. (d)Excludes amounts associated with full requirements contracts where no stated minimum purchase volume is required and $58 million of obligations between DTE Electric and affiliates of DTE Energy. (e)The agreements represent the minimum obligations with suppliers for renewable energy and renewable energy credits under existing contract terms which expire from 2030 through 2035. DTE Electric's share of plant output ranges from 28% to 100%. (f)Excludes $51 million of power purchase agreements between DTE Electric and non-utility affiliates of DTE Energy. (g)Excludes $316 million of other long-term liabilities that do not reflect contractual obligations or for which the timing of payments cannot be reasonably estimated, including $10 million of liabilities for unrecognized tax benefits. (h)At December 31, 2020, DTE Energy met the minimum pension funding levels required under the Employee Retirement Income Security Act of 1974 (ERISA) and the Pension Protection Act of 2006 for the defined benefit pension plans. DTE Energy may contribute more than the minimum funding requirements for the pension plans and may also make contributions to other postretirement benefit plans; however, these amounts are not included in the table above as such amounts are discretionary. Planned funding levels are disclosed in the "Capital Resources and Liquidity" and "Critical Accounting Estimates" sections herein and in Note 21 to the Consolidated Financial Statements in Item 8 of this Report, "Retirement Benefits and Trusteed Assets."
|
| | (c) | Excludes amounts associated with full requirements contracts where no stated minimum purchase volume is required. |
| | (d) | The agreements represent the minimum obligations with suppliers for renewable energy and renewable energy credits under existing contract terms which expire from 2030 through 2035. DTE Electric's share of plant output ranges from 29% to 100%. |
| | (e) | Excludes a power purchase agreement with a non-utility affiliate of DTE Energy. |
| | (f) | Includes liabilities for unrecognized tax benefits of $10 million. |
| | (g) | Excludes other long-term liabilities of $220 million not directly derived from contracts or other agreements. |
| | (h) | At December 31, 2019, DTE Energy met the minimum pension funding levels required under the Employee Retirement Income Security Act of 1974 (ERISA) and the Pension Protection Act of 2006 for the defined benefit pension plans. DTE Energy may contribute more than the minimum funding requirements for the pension plans and may also make contributions to the other postretirement benefit plans; however, these amounts are not included in the table above as such amounts are discretionary. Planned funding levels are disclosed in the "Capital Resources and Liquidity" and "Critical Accounting Estimates" sections herein and in Note 21 to the Consolidated Financial Statements in Item 8 of this Report, "Retirement Benefits and Trusteed Assets." |
Credit Ratings Credit ratings are intended to provide banks and capital market participants with a framework for comparing the credit quality of securities and are not a recommendation to buy, sell, or hold securities. DTE Energy, DTE Electric, and DTE Gas' credit ratings affect their costs of capital and other terms of financing, as well as their ability to access the credit and commercial paper markets. DTE Energy, DTE Electric, and DTE Gas' management believes that the current credit ratings provide sufficient access to capital markets. However, disruptions in the banking and capital markets not specifically related to DTE Energy, DTE Electric, and DTE Gas may affect their ability to access these funding sources or cause an increase in the return required by investors.
As part of the normal course of business, DTE Electric, DTE Gas, and various non-utility subsidiaries of DTE Energy routinely enter into physical or financially settled contracts for the purchase and sale of electricity, natural gas, coal, capacity, storage, and other energy-related products and services. Certain of these contracts contain provisions which allow the counterparties to request that DTE Energy posts cash or letters of credit in the event that the senior unsecured debt rating of DTE Energy is downgraded below investment grade. The amount of such collateral which could be requested fluctuates based upon commodity prices and the provisions and maturities of the underlying transactions and could be substantial. Also, upon a downgrade below investment grade, DTE Energy, DTE Electric, and DTE Gas could have restricted access to the commercial paper market, and if DTE Energy is downgraded below investment grade, the non-utility businesses, especially the Energy Trading and Power and Industrial Projects segments, could be required to restrict operations due to a lack of available liquidity. A downgrade below investment grade could potentially increase the borrowing costs of DTE Energy, DTE Electric, and DTE Gas and their subsidiaries and may limit access to the capital markets. The impact of a downgrade will not affect DTE Energy, DTE Electric, and DTE Gas' ability to comply with existing debt covenants. While DTE Energy, DTE Electric, and DTE Gas currently do not anticipate such a downgrade, they cannot predict the outcome of current or future credit rating agency reviews.
In October 2019, Moody's Investors ServiceApril 2020, Fitch Ratings downgraded DTE Energy's unsecured debt rating from Baa1BBB+ to Baa2 followingBBB. The downgrade primarily reflects increased leverage and business risk associated with DTE Energy's announcement to acquireacquisition of midstream natural gas assets.assets in December 2019. Refer to Note 4 to the Consolidated Financial Statements, "Acquisitions and Dispositions," for additional information. We doThe downgrade has not expect the downgrade to negatively impactimpacted DTE Energy's liquidity or access to the capital markets. In October 2020, DTE Energy announced its intent to spin-off its Midstream business. We do not expect the separation transaction to negatively impact DTE Energy's credit ratings, liquidity, or access to the capital markets.
CRITICAL ACCOUNTING ESTIMATES The preparation of the Registrants' Consolidated Financial Statements in conformity with generally accepted accounting principles requires that management apply accounting policies and make estimates and assumptions that affect results of operations and the amounts of assets and liabilities reported in the Consolidated Financial Statements. The Registrants' management believes that the areas described below require significant judgment in the application of accounting policy or in making estimates and assumptions in matters that are inherently uncertain and that may change in subsequent periods. Additional discussion of these accounting policies can be found in the Combined Notes to Consolidated Financial Statements in Item 8 of this Report. Regulation A significant portion of the Registrants' businesses are subject to regulation. This results in differences in the application of generally accepted accounting principles between regulated and non-regulated businesses. DTE Electric and DTE Gas are required to record regulatory assets and liabilities for certain transactions that would have been treated as revenue or expense in non-regulated businesses. Future regulatory changes or changes in the competitive environment could result in the discontinuance of this accounting treatment for regulatory assets and liabilities for some or all of the Registrants' businesses. The Registrants' management believes that currently available facts support the continued use of regulatory assets and liabilities and that all regulatory assets and liabilities are recoverable or refundable in the current rate environment. See Note 10 to the Consolidated Financial Statements in Item 8 of this Report, "Regulatory Matters." Derivatives Derivatives are generally recorded at fair value and shown as Derivative assets or liabilities. Changes in the fair value of the derivative instruments are recognized in earnings in the period of change. The normal purchases and normal sales exception requires, among other things, physical delivery in quantities expected to be used or sold over a reasonable period in the normal course of business. Contracts that are designated as normal purchases and normal sales are not recorded at fair value. Substantially all of the commodity contracts entered into by DTE Electric and DTE Gas meet the criteria specified for this exception.
Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable inputs. The Registrants make certain assumptions they believe that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. Credit risk of the Registrants and their counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at December 31, 20192020 and 2018.2019. The Registrants believe they use valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs. The fair values the Registrants calculate for their derivatives may change significantly as inputs and assumptions are updated for new information. Actual cash returns realized on derivatives may be different from the results the Registrants estimate using models. As fair value calculations are estimates based largely on commodity prices, the Registrants perform sensitivity analyses on the fair values of forward contracts. See the sensitivity analysis in Item 7A. of this report, "Quantitative and Qualitative Disclosures About Market Risk." See also the "Fair Value" section herein. See Notes 13 and 14 to the Consolidated Financial Statements in Item 8 of this Report, "Fair Value" and "Financial and Other Derivative Instruments," respectively. Goodwill Certain of DTE Energy's reporting units have goodwill or allocated goodwill resulting from business combinations. DTE Energy performs an impairment test for each of the reporting units with goodwill annually or whenever events or circumstances indicate that the value of goodwill may be impaired.
In performing Step 1 of the impairment test, DTE Energy compares the fair value of the reporting unit to its carrying value including goodwill. If the carrying value including goodwill were to exceed the fair value of a reporting unit, Step 2 of the testan impairment loss would be performed. Step 2 ofrecognized. A goodwill impairment loss is measured as the impairment test requiresamount by which a reporting unit's carrying value exceeds fair value, not to exceed the carrying valueamount of goodwill to be reduced to its fair value, if lower, as of the test date.goodwill. For Step 1 of the test, DTE Energy estimates the reporting unit's fair value using standard valuation techniques, including techniques which use estimates of projected future results and cash flows to be generated by the reporting unit. For certain reporting units, the fair values were calculated using a weighted combination of the income approach, which estimates fair value based on discounted cash flows, and the market approach, which estimates fair value based on market comparables within the utility and energy industries. The income approach includes a terminal value that utilizes an assumed long-term growth rate approach, which incorporates management's assumptions regarding sustainable long-term growth of the reporting units. The income approach cash flow valuations involve a number of estimates that require broad assumptions and significant judgment by management regarding future performance.
One of the most significant assumptions utilized in determining the fair value of reporting units under the market approach is implied market multiples for certain peer companies. Management selects comparable peers based on each peer’s primary business mix, operations, and market capitalization compared to the applicable reporting unit and calculates implied market multiples based on available projected earnings guidance and peer company market values as of the test date. DTE Energy performs an annual impairment test each October. In between annual tests, DTE Energy monitors its estimates and assumptions regarding estimated future cash flows, including the impact of movements in market indicators in future quarters, and will update the impairment analyses if a triggering event occurs. While DTE Energy believes the assumptions are reasonable, actual results may differ from projections. To the extent projected results or cash flows are revised downward, the reporting unit may be required to write down all or a portion of its goodwill, which would adversely impact DTE Energy's earnings. DTE Energy performed its annual impairment test as of October 1, 20192020 and determined that the estimated fair value of each reporting unit exceeded its carrying value, and no impairment existed.
The results of the test and key estimates that were incorporated are as follows as of the October 1, 20192020 valuation date: | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | Reporting Unit | | Goodwill | | Fair Value Reduction %(a) | | Discount Rate | | | | Valuation Methodology(b)(c) | | | (In millions) | | | | | | | | | | Electric | | $ | 1,208 | | | 49 | % | | 5.0 | % | | | | DCF and market multiples analysis | | Gas | | 743 | | | 47 | % | | 5.0 | % | | | | DCF and market multiples analysis | | Gas Storage and Pipelines | | 472 | | | 18 | % | | 7.5 | % | | | | DCF and market multiples analysis | | Power and Industrial Projects | | 26 | | | 58 | % | | 7.1 | % | | | | DCF | | Energy Trading | | 17 | | | 68 | % | | 8.2 | % | | | | DCF | | | $ | 2,466 | | | | | | | | | |
(a) | | | | | | | | | | | | | | | Reporting Unit | | Goodwill | | Fair Value Reduction %(a) | | Discount Rate | | Valuation Methodology(b)(c) | | | | (In millions) | | | | | | | | Electric | | $ | 1,208 |
| | 55 | % | | 5 | % | | DCF and market multiples analysis | | Gas | | 743 |
| | 51 | % | | 5 | % | | DCF and market multiples analysis | | Gas Storage and Pipelines | | 299 |
| | 34 | % | | 7 | % | | DCF and market multiples analysis | | Power and Industrial Projects | | 26 |
| | 69 | % | | 7 | % | | DCF | | Energy Trading | | 17 |
| | 72 | % | | 9 | % | | DCF | | | | $ | 2,293 |
| | | | | | |
______________________________________Percentage by which the fair value of equity of the reporting unit would need to decline to equal its carrying value, including goodwill. | | (a) | Percentage by which the fair value of equity of the reporting unit would need to decline to equal its carrying value, including goodwill. |
| | (b) | Discounted cash flows (DCF) incorporated 2020-2024(b)Discounted cash flows (DCF) incorporated 2021-2025 projected cash flows plus a calculated terminal value. For each of the reporting units, DTE Energy capitalized the terminal year cash flows at the weighted average costs of capital (WACC) less an assumed long-term growth rate of 2.0%. Management applied equal weighting to the DCF and market multiples analysis, where applicable, to determine the fair value of the respective reporting units. |
| | (c) | Due to lack of market comparable information for the Power & Industrial and Energy Trading reporting units, DTE Energy did not perform a market multiples analysis. |
DTE Energy recognized additional goodwill of $171 millioncapitalized the terminal year cash flows at the Gas Storageweighted average costs of capital (WACC) less an assumed long-term growth rate of 2.0%. Management applied equal weighting to the DCF and Pipelines reporting unit inmarket multiples analysis, where applicable, to determine the fourth quarter of 2019 as a resultfair value of the Blue Unionrespective reporting units. (c)Due to lack of market comparable information for the Power & Industrial and LEAP acquisition. For further discussion, see Note 4 to the Consolidated Financial Statements, "Acquisitions."Energy Trading reporting units, DTE Energy did not perform a market multiples analysis.
Business Combinations The assets acquired and liabilities assumed in a business combination are recorded at their estimated fair values at the date of acquisition. The excess purchase price over the fair value of net assets acquired is recognized as goodwill. The fair value of the assets acquired and liabilities assumed are determined based on significant estimates and assumptions, including projected timing and amount of future cash flows and discount rates reflecting risk inherent in future market prices. In some cases, DTE Energy engages independent third-party valuation firms to assist in determining the fair values. Refer to Note 4 to the Consolidated Financial Statements, "Acquisitions."Acquisitions and Dispositions." Long-Lived Assets The Registrants evaluate the carrying value of long-lived assets, excluding goodwill, when circumstances indicate that the carrying value of those assets may not be recoverable. Conditions that could have an adverse impact on the cash flows and fair value of the long-lived assets are deteriorating business climate, condition of the asset, or plans to dispose of the asset before the end of its useful life. The review of long-lived assets for impairment requires significant assumptions about operating strategies and estimates of future cash flows, which require assessments of current and projected market conditions. An impairment evaluation is based on an undiscounted cash flow analysis at the lowest level for which independent cash flows of long-lived assets can be identified from other groups of assets and liabilities. Impairment may occur when the carrying value of the asset exceeds the future undiscounted cash flows. When the undiscounted cash flow analysis indicates a long-lived asset is not recoverable, the amount of the impairment loss is determined by measuring the excess of the long-lived asset over its fair value. An impairment would require the Registrants to reduce both the long-lived asset and current period earnings by the amount of the impairment, which would adversely impact their earnings. Pension and Other Postretirement Costs DTE Energy sponsors both funded and unfunded defined benefit pension plans and other postretirement benefit plans for eligible employees of the Registrants. The measurement of the plan obligations and cost of providing benefits under these plans involve various factors, including numerous assumptions and accounting elections. When determining the various assumptions that are required, DTE Energy considers historical information as well as future expectations. The benefit costs are affected by, among other things, the actual rate of return on plan assets, the long-term expected return on plan assets, the discount rate applied to benefit obligations, the incidence of mortality, the expected remaining service period of plan participants, level of compensation and rate of compensation increases, employee age, length of service, the anticipated rate of increase of health care costs, benefit plan design changes, and the level of benefits provided to employees and retirees. Pension and other postretirement benefit costs attributed to the segments are included with labor costs and ultimately allocated to projects within the segments, some of which are capitalized.
DTE Energy had pension costs of $148 million in 2020, $112 million in 2019, and $148 million in 2018, and $172 million in 2017.2018. Other postretirement benefit credits were $49 million in 2020, $1 million in 2019, and $36 million in 2018, and $31 million in 2017.2018. Pension costs and other postretirement benefit credits for 20192020 were calculated based upon several actuarial assumptions, including an expected long-term rate of return on plan assets of 7.30%7.10% for the pension plans and 7.20% for the other postretirement benefit plans. In developing the expected long-term rate of return assumptions, DTE Energy evaluated asset class risk and return expectations, as well as inflation assumptions. Projected returns are based on broad equity, bond, and other markets. DTE Energy's 20202021 expected long-term rate of return on pension plan assets is based on an asset allocation assumption utilizing active and passive investment management of 35%37% in equity markets, 42%38% in fixed income markets, including long duration bonds, and 23%25% invested in other assets. DTE Energy's 20202021 expected long-term rate of return on other postretirement plan assets is based on an asset allocation assumption utilizing active and passive investment management of 35%23% in equity markets, 37%52% in fixed income markets, and 28%25% invested in other assets. Because of market volatility, DTE Energy periodically reviews the asset allocation and rebalances the portfolio when considered appropriate. DTE Energy is lowering its long-term rate of return assumption for the pension plans to 7.10%7.00% and lowering the other postretirement plans to 7.20%6.70% for 2020.2021. DTE Energy believes these rates are reasonable assumptions for the long-term rates of return on the plans' assets for 20202021 given their respective asset allocations and DTE's capital market expectations. DTE Energy will continue to evaluate the actuarial assumptions, including its expected rate of return, at least annually.
DTE Energy calculates the expected return on pension and other postretirement benefit plan assets by multiplying the expected return on plan assets by the market-related value (MRV) of plan assets at the beginning of the year, taking into consideration anticipated contributions and benefit payments that are to be made during the year. Current accounting rules provide that the MRV of plan assets can be either fair value or a calculated value that recognizes changes in fair value in a systematic and rational manner over not more than five years. For the pension plans, DTE Energy uses a calculated value when determining the MRV of the pension plan assets and recognizes changes in fair value over a three-year period. Accordingly, the future value of assets will be impacted as previously deferred gains or losses are recognized. Favorable asset performance in 20192020 resulted in unrecognized net gains. As of December 31, 2019,2020, DTE Energy had $186$507 million of cumulative gains related to investment performance in prior years that were not yet recognized in the calculation of the MRV of pension assets. For the other postretirement benefit plans, DTE Energy uses fair value when determining the MRV of other postretirement benefit plan assets, therefore all investment gains and losses have been recognized in the calculation of MRV for these plans. The discount rate that DTE Energy utilizes for determining future pension and other postretirement benefit obligations is based on a yield curve approach and a review of bonds that receive one of the two highest ratings given by a recognized rating agency. The yield curve approach matches projected pension plan and other postretirement benefit payment streams with bond portfolios reflecting actual liability duration unique to the plans. The discount rate determined on this basis was 3.28%2.57% for the pension and 3.29%2.58% for the other postretirement plans at December 31, 20192020 compared to 4.40%3.28% and 3.29%, respectively, for both the pension and other postretirement plans at December 31, 2018.2019. DTE Energy changed the mortality assumptionassumptions as of December 31, 20192020 to reflect recent plan experience and the updated MP-2019base tables and projection scale.scales published by the Society of Actuaries. The mortality assumptions used at December 31, 20192020 are the RP-2014PRI-2012 mortality table projected back to 20062018 using Scale MP-2014,MP-2019, and projected forward to 2015from 2018 using Scale MP-2017 and projected beyond 2015 using Scale MP-2019MP-2020 with generational projection. The base mortality tables vary by type of plan, employee's union status and employment status, with additional adjustments to reflect the actual experience and credibility of each population. DTE Energy estimates the 2020that total pension costs will be approximately $120$136 million in 2020,2021, compared to $112$148 million in 2019.2020. The increase in2020 total pension costs included $25 million of one-time settlement charges. Excluding these charges, total pension costs are expected to increase from 2020 to 2021, which is primarily due to a lower discount rates, offset by favorable asset returns.rate and expected rate of return. The 20202021 other postretirement benefit credit will beis estimated at approximately $40$39 million compared to $1$49 million in 2019.2020. The expected decrease in the credit is primarily due to a lower discount rate and expected rate of return. The health care trend rates for DTE Energy assume 6.75% for pre-65 participants and 7.25% for post-65 participants for 2020,2021, trending down to 4.50% for both pre-65 and post-65 participants in 2032.2033. Future actual pension and other postretirement benefit costs or credits will depend on future investment performance, changes in future discount rates, and various other factors related to plan design.
Lowering the expected long-term rate of return on the plan assets by one percentage point would have increased the 20192020 pension costs by approximately $45$47 million. Lowering the discount rate and the salary increase assumptions by one percentage point would have increased the 20192020 pension costs by approximately $22$23 million. Lowering the expected long-term rate of return on plan assets by one percentage point would have decreased the 20192020 other postretirement credit by approximately $17$18 million. Lowering the discount rate and the salary increase assumptions by one percentage point would have decreased the 20192020 other postretirement credit by approximately $21 million. Lowering the health care cost trend assumptions by one percentage point would have increased the other postretirement credit for 2019 by approximately $4$18 million. The value of the qualified pension and other postretirement benefit plan assets was $7.5 billion at December 31, 2020 and $6.8 billion at December 31, 2019 and $6.0 billion at December 31, 2018.2019. At December 31, 2019,2020, DTE Energy's qualified pension plans were underfunded by $677$653 million and its other postretirement benefit plans were overfunded by $68$153 million. In 2019,2020, the funded status of the pension plans improved as plan sponsor contributions and favorable asset returns were partially offset by a decrease in discount rates. The funded status of the other postretirement benefit plans improved as favorable asset returns and a favorable change in healthcare experiencecost assumptions were partially offset by a decrease in discount rates.
Pension and other postretirement costs and pension cash funding requirements may increase in future years without typical returns in the financial markets. DTE Energy made contributions to its qualified pension plans of $92 million in 2020 and $150 million in 2019 and $175 million in 2018.2019. At the discretion of management, consistent with the Pension Protection Act of 2006, and depending upon financial market conditions, DTE Energy anticipates making contributions to its qualified pension plans of up to $185$107 million in 20202021 and up to $458$128 million over the next five years. DTE Energy did not make other postretirement benefit plan contributions in 20192020 or 2018.2019. DTE Energy does not anticipate making any contributions to its other postretirement plans in 20202021 or over the next five years. The planned pension contributions will be made in cash and/or DTE Energy common stock. See Note 21 to the Consolidated Financial Statements in Item 8 of this Report, "Retirement Benefits and Trusteed Assets." Legal Reserves The Registrants are involved in various legal proceedings, claims, and litigation arising in the ordinary course of business. The Registrants regularly assess their liabilities and contingencies in connection with asserted or potential matters and establish reserves when appropriate. Legal reserves are based upon the Registrants' management’s assessment of pending and threatened legal proceedings and claims against the Registrants. Accounting for Tax Obligations The Registrants are required to make judgments regarding the potential tax effects of various financial transactions and results of operations in order to estimate their obligations to taxing authorities. The Registrants account for uncertain income tax positions using a benefit recognition model with a two-step approach, a more-likely-than-not recognition criterion, and a measurement attribute that measures the position as the largest amount of tax benefit that is greater than 50% likely of being realized upon ultimate settlement. If the benefit does not meet the more likely than not criteria for being sustained on its technical merits, no benefit will be recorded. Uncertain tax positions that relate only to timing of when an item is included on a tax return are considered to have met the recognition threshold. The Registrants also have non-income tax obligations related to property, sales and use, and employment-related taxes, and ongoing appeals related to these tax matters. Accounting for tax obligations requires judgments, including assessing whether tax benefits are more likely than not to be sustained, and estimating reserves for potential adverse outcomes regarding tax positions that have been taken. The Registrants also assess their ability to utilize tax attributes, including those in the form of carry-forwards, for which the benefits have already been reflected in the Consolidated Financial Statements. The Registrants believe the resulting tax reserve balances as of December 31, 20192020 and 20182019 are appropriate. The ultimate outcome of such matters could result in favorable or unfavorable adjustments to the Registrants' Consolidated Financial Statements, and such adjustments could be material. See Note 11 to the Consolidated Financial Statements in Item 8 of this Report, "Income Taxes."
NEW ACCOUNTING PRONOUNCEMENTS See Note 3 to the Consolidated Financial Statements in Item 8 of this Report, "New Accounting Pronouncements."
FAIR VALUE Derivatives are generally recorded at fair value and shown as Derivative assets or liabilities. Contracts DTE Energy typically classifies as derivative instruments include power, natural gas, oil,some environmental contracts, and certain coal forwards, futures, options and swaps, and foreign currency exchange contracts. Items DTE Energy does not generally account for as derivatives include natural gas and environmental inventory, pipeline transportation contracts, renewable energy credits,storage assets, and storage assets.some environmental contracts. See Notes 13 and 14 to the Consolidated Financial Statements in Item 8 of this Report, "Fair Value" and "Financial and Other Derivative Instruments," respectively. The tables below do not include the expected earnings impact of non-derivative natural gas storage, transportation, certain power contracts, and renewable energy creditssome environmental contracts which are subject to accrual accounting. Consequently, gains and losses from these positions may not match with the related physical and financial hedging instruments in some reporting periods, resulting in volatility in the Registrants' reported period-by-period earnings; however, the financial impact of the timing differences will reverse at the time of physical delivery and/or settlement.
The Registrants manage their MTM risk on a portfolio basis based upon the delivery period of their contracts and the individual components of the risks within each contract. Accordingly, the Registrants record and manage the energy purchase and sale obligations under their 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 Registrants have established a fair value hierarchy 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). For further discussion of the fair value hierarchy, see Note 13 to the Consolidated Financial Statements in Item 8 of this Report, "Fair Value." The following table provides details on changes in DTE Energy's MTM net asset (or liability) position: | | | | | | | Total | | | (In millions) | | MTM at December 31, 2018 | $ | (23 | ) | | Reclassified to realized upon settlement | (49 | ) | | Changes in fair value recorded to income | 55 |
| | Amounts recorded to unrealized income | 6 |
| | Changes in fair value recorded in regulatory liabilities | 2 |
| | Option premiums paid (received) and other | — |
| | Amounts recorded in other comprehensive income, pretax | 3 |
| | Change in collateral | 17 |
| | MTM at December 31, 2019 | $ | 5 |
|
| | | | | | | Total | | (In millions) | | MTM at December 31, 2019 | $ | 5 | | | Reclassified to realized upon settlement | 92 | | | Changes in fair value recorded to income | (83) | | | Amounts recorded to unrealized income | 9 | | | Changes in fair value recorded in regulatory liabilities | 20 | | | | | | | Change in collateral | (6) | | | MTM at December 31, 2020 | $ | 28 | |
The table below shows the maturity of DTE Energy's MTM positions. The positions from 20232024 and beyond principally represent longer tenor gas structured transactions: | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | Source of Fair Value | | 2021 | | 2022 | | 2023 | | 2024 and Beyond | | Total Fair Value | | | (In millions) | | Level 1 | | $ | 10 | | | $ | 1 | | | $ | (1) | | | $ | — | | | $ | 10 | | | Level 2 | | 39 | | | — | | | (5) | | | (8) | | | 26 | | | Level 3 | | 11 | | | 3 | | | — | | | (16) | | | (2) | | | MTM before collateral adjustments | | $ | 60 | | | $ | 4 | | | $ | (6) | | | $ | (24) | | | 34 | | | Collateral adjustments | | | | | | | | | | (6) | | | MTM at December 31, 2020 | | | | | | | | | | $ | 28 | |
| | | | | | | | | | | | | | | | | | | | | | | Source of Fair Value | | 2020 | | 2021 | | 2022 | | 2023 and Beyond | | Total Fair Value | | | | (In millions) | | Level 1 | | $ | (8 | ) | | $ | (5 | ) | | $ | (2 | ) | | $ | (1 | ) | | $ | (16 | ) | | Level 2 | | 18 |
| | — |
| | (2 | ) | | 1 |
| | 17 |
| | Level 3 | | 40 |
| | 6 |
| | 5 |
| | (47 | ) | | 4 |
| | MTM before collateral adjustments | | $ | 50 |
| | $ | 1 |
| | $ | 1 |
| | $ | (47 | ) | | 5 |
| | Collateral adjustments | | | | | | | | | | — |
| | MTM at December 31, 2019 | | | | | | | | | | $ | 5 |
|
Item 7A. Quantitative and Qualitative Disclosures About Market Risk Market Price Risk The Electric and Gas businesses have commodity price risk, primarily related to the purchases of coal, natural gas, uranium, and electricity. However, the Registrants do not bear significant exposure to earnings risk, as such changes are included in the PSCR and GCR regulatory rate-recovery mechanisms. In addition, changes in the price of natural gas can impact the valuation of lost and stolen gas, storage sales, and transportation services revenue at the Gas segment. The Gas segment manages its market price risk related to storage sales revenue primarily through the sale of long-term storage contracts. The Registrants are exposed to short-term cash flow or liquidity risk as a result of the time differential between actual cash settlements and regulatory rate recovery. DTE Energy's Gas Storage and Pipelines segment has exposure tois dependent on the continued availability of natural gas price fluctuations which impact the pricingproduction and reserves in its areas of operation. Low prices for natural gas, storage, gathering,including those resulting from regional basis differentials, could adversely affect development of additional reserves and transportation.production that is accessible to our pipeline and storage assets. DTE Energy manages its exposure through the use of short, medium, and long-term storage, gathering, and transportation contracts.
DTE Energy's Power and Industrial Projects business segment is subject to electricity, natural gas, and coal product price risk. DTE Energy manages its exposure to commodity price risk through the use of long-term contracts. DTE Energy's Energy Trading business segment has exposure to electricity, natural gas, coal,environmental, crude oil, heating oil, and foreign currency exchange price fluctuations. These risks are managed by the energy marketing and trading operations through the use of forward energy, capacity, storage, options, and futures contracts, within pre-determinedpredetermined risk parameters. Credit Risk 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. As of December 31, 2019, PG&Es account is substantially current&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 outstanding accounts receivable from PG&E are not material. Therefore, DTE Energy determined no reserve was necessary. As of December 31, 2019, the book value of long-lived assets used in producing electric outputpayment has been received for sale to PG&E was approximately $101 million. The Power and Industrial Projects segment also has equity investments, including a note receivable, of approximately $74 million in entities that sell power to PG&E. In January 2019, following the bankruptcy filing, DTE Energy performed an impairment analysis on its long-lived assets. Based on its undiscounted cash flow projections, DTE Energy determined it did not have an impairment loss as of December 31, 2018. DTE Energy also determined there was not an other-than-temporary decline in its equity investments. DTE has not identified subsequent facts or circumstances that would cause a changeall past due receivables related to these conclusions through December 31, 2019. DTE Energy’s assumptions and conclusions may change, and it could have impairment losses if any of the terms of the contracts are not honored by PG&E or the contracts are rejected through the bankruptcy process.agreements.
Allowance for Doubtful Accounts The Registrants regularly review contingent matters, existing and future economic conditions, customer trends and other factors relating to customers and their contracts and record provisions for amounts considered at risk of probable loss in the allowance for doubtful accounts. The Registrants believe their accrued amounts are adequate for probable loss. Trading Activities DTE Energy is exposed to credit risk through trading activities. Credit risk is the potential loss that may result if the trading counterparties fail to meet their contractual obligations. DTE Energy utilizes both external and internal credit assessments when determining the credit quality of trading counterparties.
The following table displays the credit quality of DTE Energy's trading counterparties as of December 31, 2019:2020: | | | | Credit Exposure
Before Cash
Collateral | | Cash
Collateral | | Net Credit
Exposure | | Credit Exposure
Before Cash
Collateral | | Cash
Collateral | | Net Credit
Exposure | | | (In millions) | | (In millions) | Investment Grade(a) | | | | | | Investment Grade(a) | | | A- and Greater | $ | 259 |
| | $ | — |
| | $ | 259 |
| A- and Greater | $ | 222 | | | $ | — | | | $ | 222 | | | BBB+ and BBB | 197 |
| | — |
| | 197 |
| BBB+ and BBB | 214 | | | — | | | 214 | | | BBB- | 34 |
| | — |
| | 34 |
| BBB- | 12 | | | — | | | 12 | | | Total Investment Grade | 490 |
| | — |
| | 490 |
| Total Investment Grade | 448 | | | — | | | 448 | | Non-investment grade(b) | 5 |
| | — |
| | 5 |
| Non-investment grade(b) | 10 | | | — | | | 10 | | Internally Rated — investment grade(c) | 324 |
| | (1 | ) | | 323 |
| Internally Rated — investment grade(c) | 413 | | | (1) | | | 412 | | Internally Rated — non-investment grade(d) | 13 |
| | — |
| | 13 |
| Internally Rated — non-investment grade(d) | 62 | | | (2) | | | 60 | | | Total | $ | 832 |
| | $ | (1 | ) | | $ | 831 |
| Total | $ | 933 | | | $ | (3) | | | $ | 930 | |
| | (a) | This category includes counterparties with minimum credit ratings of Baa3 assigned by Moody’s Investors Service (Moody’s) or BBB- assigned by Standard & Poor’s Rating Group, a division of McGraw-Hill Companies, Inc. (Standard & Poor’s). The five largest counterparty exposures, combined, for this category represented 16% of the total gross credit exposure. |
| | (b) | This category includes counterparties with credit ratings that are below investment grade. The five largest counterparty exposures, combined, for this category represented 1% of the total gross credit exposure. |
| | (c) | This category includes counterparties that have not been rated by Moody’s or Standard & Poor’s but are considered investment grade based on DTE Energy’s evaluation of the counterparty’s creditworthiness. The five largest counterparty exposures, combined, for this category represented 15% of the total gross credit exposure. |
| | (d) | This category includes counterparties that have not been rated by Moody’s or Standard & Poor’s and are considered non-investment grade based on DTE Energy’s evaluation of the counterparty’s creditworthiness. The five largest counterparty exposures, combined, for this category represented 1% of the total gross credit exposure. |
(a)This category includes counterparties with minimum credit ratings of Baa3 assigned by Moody’s Investors Service (Moody’s) or BBB- assigned by Standard & Poor’s Rating Group, a division of McGraw-Hill Companies, Inc. (Standard & Poor’s). The five largest counterparty exposures, combined, for this category represented 13% of the total gross credit exposure. (b)This category includes counterparties with credit ratings that are below investment grade. The five largest counterparty exposures, combined, for this category represented 1% of the total gross credit exposure. (c)This category includes counterparties that have not been rated by Moody’s or Standard & Poor’s but are considered investment grade based on DTE Energy’s evaluation of the counterparty’s creditworthiness. The five largest counterparty exposures, combined, for this category represented 14% of the total gross credit exposure. (d)This category includes counterparties that have not been rated by Moody’s or Standard & Poor’s and are considered non-investment grade based on DTE Energy’s evaluation of the counterparty’s creditworthiness. The five largest counterparty exposures, combined, for this category represented 4% of the total gross credit exposure. Other The Registrants engage in business with customers that are non-investment grade. The Registrants closely monitor the credit ratings of these customers and, when deemed necessary and permitted under the tariffs, request collateral or guarantees from such customers to secure their obligations. Interest Rate Risk DTE Energy is subject to interest rate risk in connection with the issuance of debt. In order to manage interest costs, DTE Energy may use treasury locks and interest rate swap agreements. DTE Energy's exposure to interest rate risk arises primarily from changes in U.S. Treasury rates, commercial paper rates, and LIBOR. As of December 31, 2019,2020, DTE Energy had floating rate debt of $38 million and a floating rate debt-to-total debt ratio of 4.8%0.2%. Foreign Currency Exchange Risk DTE Energy has foreign currency exchange risk arising from market price fluctuations associated with fixed priced contracts. These contracts are denominated in Canadian dollars and are primarily for the purchase and sale of natural gas and power, as well as for long-term transportation capacity. To limit DTE Energy's exposure to foreign currency exchange fluctuations, DTE Energy has entered into a series of foreign currency exchange forward contracts through December 2023.June 2030. Summary of Sensitivity Analyses Sensitivity analyses were performed on the fair values of commodity contracts for DTE Energy and long-term debt obligations for the Registrants. The commodity contracts listed below principally relate to energy marketing and trading activities. The sensitivity analyses involved increasing and decreasing forward prices and rates at December 31, 20192020 and 20182019 by a hypothetical 10% and calculating the resulting change in the fair values. The hypothetical losses related to long-term debt would be realized only if DTE Energy transferred all of its fixed-rate long-term debt to other creditors.
The results of the sensitivity analyses: | | | | | Assuming a 10% Increase in Prices/Rates | | Assuming a 10% Decrease in Prices/Rates | | | Assuming a
10% Increase in Prices/Rates | | Assuming a
10% Decrease in Prices/Rates | | | | | As of December 31, | | As of December 31, | | | As of December 31, | | As of December 31, | | | Activity | | 2019 | | 2018 | | 2019 | | 2018 | | Change in the Fair Value of | Activity | | 2020 | | 2019 | | 2020 | | 2019 | | Change in the Fair Value of | | | | (In millions) | | | | (In millions) | | | | | Gas contracts | | $ | 6 |
| | $ | 8 |
| | $ | (6 | ) | | $ | (8 | ) | | Commodity contracts | Gas contracts | | $ | 23 | | | $ | 6 | | | $ | (23) | | | $ | (6) | | | Commodity contracts | | Power contracts | | $ | 4 |
| | $ | 10 |
| | $ | (5 | ) | | $ | (10 | ) | | Commodity contracts | Power contracts | | $ | 5 | | | $ | 4 | | | $ | (5) | | | $ | (5) | | | Commodity contracts | | Environmental contracts | | $ | (3 | ) | | $ | — |
| | $ | 3 |
| | $ | — |
| | Commodity contracts | Environmental contracts | | $ | (7) | | | $ | (3) | | | $ | 5 | | | $ | 3 | | | Commodity contracts | | | Interest rate risk — DTE Energy | | $ | (698 | ) | | $ | (596 | ) | | $ | 724 |
| | $ | 625 |
| | Long-term debt | Interest rate risk — DTE Energy | | $ | (651) | | | $ | (698) | | | $ | 671 | | | $ | 724 | | | Long-term debt | | Interest rate risk — DTE Electric | | $ | (286 | ) | | $ | (277 | ) | | $ | 305 |
| | $ | 300 |
| | Long-term debt | Interest rate risk — DTE Electric | | $ | (285) | | | $ | (286) | | | $ | 300 | | | $ | 305 | | | Long-term debt | |
For further discussion of market risk, see Management's Discussion and Analysis in Item 7 of this Report and Note 14 to the Consolidated Financial Statements in Item 8 of this Report, "Financial and Other Derivative Instruments."
Item 8. Financial Statements and Supplementary Data The following Consolidated Financial Statements and financial statement schedules are included herein: | | | | | | | | | Page | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | Financial Statement Schedule | | | |
DTE Energy — Controls and Procedures (a) Evaluation of disclosure controls and procedures Management of DTE Energy carried out an evaluation, under the supervision and with the participation of DTE Energy's Chief Executive Officer (CEO) and Chief Financial Officer (CFO), of the effectiveness of the design and operation of DTE Energy's disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of December 31, 2019,2020, which is the end of the period covered by this report. Based on this evaluation, DTE Energy's CEO and CFO have concluded that such disclosure controls and procedures are effective in providing reasonable assurance that information required to be disclosed by DTE Energy in reports that it files or submits under the Exchange Act (i) is recorded, processed, summarized, and reported within the time periods specified in the U.S. Securities and Exchange Commission's rules and forms and (ii) is accumulated and communicated to DTE Energy's management, including its CEO and CFO, as appropriate to allow timely decisions regarding required disclosure. Due to the inherent limitations in the effectiveness of any disclosure controls and procedures, management cannot provide absolute assurance that the objectives of its disclosure controls and procedures will be attained. (b) Management’s report on internal control over financial reporting Management of DTE Energy is responsible for establishing and maintaining adequate internal control over financial reporting as such term is defined in Exchange Act Rules 13a-15(f) and 15d-15(f). Internal control over financial reporting is a process designed by, or under the supervision of, DTE Energy's CEO and CFO, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. Management has excluded the acquisition of M5 Louisiana Gathering, LLC and its wholly owned subsidiaries (“Blue Union and LEAP”) from the Company’s assessment of internal control over financial reporting as of December 31, 2019 as it was acquired by the Company in an acquisition on December 4, 2019. Blue Union and LEAP represent approximately 3% of consolidated total assets as of December 31, 2019 and less than 1% of total revenues and other income for the year ended December 31, 2019. We plan to fully integrate the acquired businesses into our internal control over financial reporting in 2020.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate. Management of DTE Energy has assessed the effectiveness of DTE Energy’s internal control over financial reporting as of December 31, 2019.2020. In making this assessment, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (2013 COSO) in Internal Control - Integrated Framework. Based on this assessment, management concluded that, as of December 31, 2019,2020, DTE Energy’s internal control over financial reporting was effective based on those criteria. The effectiveness of DTE Energy’s internal control over financial reporting as of December 31, 20192020 has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm who also audited DTE Energy’s financial statements, as stated in their report which appears herein. (c) Changes in internal control over financial reporting There have been no changes in DTE Energy's internal control over financial reporting during the quarter ended December 31, 20192020 that have materially affected, or are reasonably likely to materially affect, DTE Energy's internal control over financial reporting.
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRMReport of Independent Registered Public Accounting Firm
To the Board of Directors and Shareholders of DTE Energy Company Opinions on the Financial Statements and Internal Control over Financial Reporting We have audited the accompanying consolidated statements of financial position of DTE Energy Company and its subsidiaries (the “Company”) as of December 31, 20192020 and 2018,2019, and the related consolidated statements of operations, of comprehensive income, of changes in equity and of cash flows for each of the three years in the period ended December 31, 2019,2020, including the related notes and financial statement schedule listed in the accompanying index for each of the three years in the period ended December 31, 20192020 (collectively referred to as the “consolidated financial statements”). We also have audited the Company's internal control over financial reporting as of December 31, 2019,2020, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 20192020 and 20182019, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 20192020 in conformity with accounting principles generally accepted in the United States of America. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2019,2020, based on criteria established in Internal Control - Integrated Framework (2013) issued by the COSO. Basis for Opinions The Company's management is responsible for these consolidated financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s report on internal control over financial reporting. Our responsibility is to express opinions on the Company’s consolidated financial statements and on the Company's internal control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB. We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects. Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.
As described in Management’s report on internal control over financial reporting, management has excluded the acquisition of M5 Louisiana Gathering, LLC and its wholly owned subsidiaries from its assessment of internal control over financial reporting as of December 31, 2019 because they were acquired by the Company in a business combination during 2019. We have also excluded M5 Louisiana Gathering, LLC and its wholly owned subsidiaries from our audit of internal control over financial reporting. M5 Louisiana Gathering, LLC and its wholly owned subsidiaries are wholly-owned subsidiaries whose total assets and total revenues excluded from management’s assessment and our audit of internal control over financial reporting represent approximately 3% and less than 1%, respectively, of the related consolidated financial statement amounts as of and for the year ended December 31, 2019.
Definition and Limitations of Internal Control over Financial Reporting A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate. Critical Audit Matters The critical audit mattersmatter communicated beloware matters is a matter arising from the current period audit of the consolidated financial statements that werewas communicated or required to be communicated to the audit committee and that (i) relaterelates to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit mattersmatter below, providing a separate opinionsopinion on the critical audit mattersmatter or on the accounts or disclosures to which they relate.it relates. Acquisition of M5 Louisiana Gathering, LLC - Customer Relationship Intangible Assets
As described in Note 4 to the consolidated financial statements, the Company completed the acquisition of M5 Louisiana Gathering, LLC for $2.74 billion in 2019, which resulted in $1.47 billion of customer relationship intangible assets being recorded. The fair value of the intangible assets acquired was estimated by applying the income approach based upon discounted projected future cash flows attributable to the existing contracts and agreements. Key management 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.
The principal considerations for our determination that performing procedures relating to the acquisition of M5 Gathering - customer relationship intangible assets is a critical audit matter are there was significant judgment by management in determining the fair value of the intangible assets acquired, which includes significant estimates and inputs related to revenue and expense projections, discount rates, and expected renewal rates of existing customer contracts. This in turn led to a high degree of auditor judgment, subjectivity and effort in performing procedures and in evaluating the audit evidence obtained related to these estimates and inputs. In addition, the audit effort involved the use of professionals with specialized skill and knowledge to assist in performing these procedures and evaluating the audit evidence obtained.
Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the financial statements. These procedures included testing the effectiveness of controls relating to the acquisition accounting, including controls over management’s valuation of the intangible assets and controls over development of the significant estimates and inputs related to the valuation of the intangible assets, including revenue and expense projections, discount rates, and expected renewals rates of existing customer contracts. These procedures also included, among others (i) reading the purchase agreement; (ii) testing management’s process for estimating the fair value of the intangible assets; and (iii) testing management’s cash flow projections used to estimate the fair value of the intangible assets, including testing customer renewal rate assumptions included in the projections. Testing management’s process included evaluating the appropriateness of the valuation method and the reasonableness of significant estimates and inputs, including the revenue and expense projections, expected renewal rates, and the discount rate for the intangible assets. Evaluating the reasonableness of these assumptions included agreeing revenue projections, consisting of pricing and minimum volume commitments, to customer contracts, comparing projections to prior year actual results and obtaining support for the expected renewal rates which included analyzing industry data on the production lives of the reserves in the region. We used professionals with specialized skill and knowledge to assist in evaluating the appropriateness of the valuation method and discount rates.
Accounting for the Effects of New, or Changes to Existing, Regulatory Matters As described in Note 10 to the consolidated financial statements, the Company recorded $4.176$4,257 million of regulatory assets and $3.329$3,402 million of regulatory liabilities as of December 31, 2019.2020. The Company is required to record regulatory assets and liabilities for certain transactions that would have been treated as revenue or expense in non-regulated businesses. Continued applicability of regulatory accounting treatment requires that rates be designed to recover specific costs of providing regulatory services and be charged to and collected from customers. Future regulatory changes could result in a discontinuance of this accounting treatment for regulatory assets and liabilities for some or all of the Company’s regulated businesses and may require the write-off of the portion of any regulatory asset or liability that was no longer probable of recovery through regulated rates. Management believes that currently available facts support the continued use of regulatory assets and liabilities and that all regulatory assets and liabilities are recoverable or refundable in the current regulatory environment. The principal considerations for our determination that performing procedures relating to the Company's accounting for the effects of new, or changes to existing, regulatory matters is a critical audit matter are there wasthe significant judgment by management in assessing the potential outcome and resulting accounting implications of new, or changes to existing, regulatory matters. Thismatters; this in turn led to significant audita high degree of auditor judgment, subjectivity and effort in evaluating the appropriateness of management’s assessment and audit evidence obtained related to the assessment. Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to management’s assessment and implementation of new regulatory matters or changes to existing regulatory matters. These procedures also included, among others, assessing (i) the reasonableness of management’s assessment of impacts arising from correspondence with regulators and changes in laws and regulations and (ii) the appropriateness of disclosures in the consolidated financial statements. Testing regulatory assets and liabilities, including those subject to pending rate orders, involved considering the provisions and formulas outlined in the rate orders, other regulatory correspondence, and the application of relevant regulatory precedents. Valuation of Level 3 Derivative Instruments
As described in Notes 13 and 14 to the consolidated financial statements, the fair value of level 3 derivative assets was $160 million and the fair value of level 3 derivative liabilities was $156 million as of December 31, 2019. Contracts classified as derivative instruments include electricity, natural gas, oil, certain environmental contracts, certain coal forwards, futures, options, swaps, and foreign currency exchange contracts. The fair value estimate of level 3 assets and liabilities consist of unobservable inputs, and the 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. Management primarily uses a discounted cash flow valuation technique to value level 3 assets and liabilities, which include forward basis prices as unobservable inputs. Other inputs to the valuation model include commodity market prices, broker quotes, interest rates, credit ratings, default rates, market-based seasonality, and basis differential factors.
The principal considerations for our determination that performing procedures relating to the valuation of level 3 derivative instruments is a critical audit matter are there was significant judgment by management to determine the fair value of these instruments due to the use of internally-developed models or methodologies, which included significant assumptions related to forward basis prices, commodity market prices, broker quotes, and basis differential factors. This in turn led to a high degree of auditor judgment, subjectivity and effort in performing procedures and in evaluating the audit evidence obtained related to the valuation, and the audit effort involved the use of professionals with specialized skill and knowledge.
Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to the valuation of level 3 derivative instruments, including controls over the models and methodologies, data, and significant assumptions. These procedures also included, among others, testing the underlying data used in the estimate, evaluating the appropriateness of the models and methodologies, and evaluating the reasonableness of significant assumptions used by management in developing the fair value measurement related to forward basis prices, commodity market prices, broker quotes, and basis differential factors. We used professionals with specialized skill and knowledge to assist in evaluating the appropriateness of the internally developed models and methodologies, including assessing the methodology used to develop forward basis prices and assessing the key inputs and assumptions used in the models, including commodity market prices, broker quotes, and basis differential factors.
/s/ PricewaterhouseCoopers LLP
Detroit, Michigan February 5, 202019, 2021
We have served as the Company’s auditor since 2008.
DTE Energy Company Consolidated Statements of Operations | | | | Year Ended December 31, | | Year Ended December 31, | | | 2019 | | 2018 | | 2017 | | 2020 | | 2019 | | 2018 | | | (In millions, except per share amounts) | | (In millions, except per share amounts) | | Operating Revenues | | | | | | Operating Revenues | | | Utility operations | $ | 6,638 |
| | $ | 6,670 |
| | $ | 6,434 |
| Utility operations | $ | 6,845 | | | $ | 6,638 | | | $ | 6,670 | | | Non-utility operations | 6,031 |
| | 7,542 |
| | 6,173 |
| Non-utility operations | 5,332 | | | 6,031 | | | 7,542 | | | | 12,669 |
|
| 14,212 |
|
| 12,607 |
| | 12,177 | | | 12,669 | | | 14,212 | | | | | | | | | | | | | | | | Operating Expenses | | | | | | Operating Expenses | | | Fuel, purchased power, and gas — utility | 1,798 |
| | 1,981 |
| | 1,881 |
| Fuel, purchased power, and gas — utility | 1,719 | | | 1,798 | | | 1,981 | | | Fuel, purchased power, and gas — non-utility | 5,053 |
| | 6,630 |
| | 5,283 |
| | | Fuel, purchased power, gas, and other — non-utility | | Fuel, purchased power, gas, and other — non-utility | 4,141 | | | 5,053 | | | 6,630 | | | Operation and maintenance | 2,419 |
| | 2,451 |
| | 2,270 |
| Operation and maintenance | 2,443 | | | 2,419 | | | 2,451 | | | Depreciation and amortization | 1,263 |
| | 1,124 |
| | 1,030 |
| Depreciation and amortization | 1,443 | | | 1,263 | | | 1,124 | | | Taxes other than income | 414 |
| | 405 |
| | 391 |
| Taxes other than income | 410 | | | 414 | | | 405 | | | Asset (gains) losses and impairments, net | 15 |
| | 27 |
| | 41 |
| Asset (gains) losses and impairments, net | 35 | | | 15 | | | 27 | | | | 10,962 |
| | 12,618 |
| | 10,896 |
| | 10,191 | | | 10,962 | | | 12,618 | | | Operating Income | 1,707 |
| | 1,594 |
| | 1,711 |
| Operating Income | 1,986 | | | 1,707 | | | 1,594 | | | | | | | | | | | | | | | | Other (Income) and Deductions | | | | | | Other (Income) and Deductions | | | Interest expense | 641 |
| | 559 |
| | 536 |
| Interest expense | 720 | | | 641 | | | 559 | | | Interest income | (17 | ) | | (12 | ) | | (12 | ) | Interest income | (38) | | | (17) | | | (12) | | | Non-operating retirement benefits, net | 39 |
| | 37 |
| | 65 |
| Non-operating retirement benefits, net | 50 | | | 39 | | | 37 | | | Other income | (350 | ) | | (333 | ) | | (268 | ) | Other income | (388) | | | (350) | | | (333) | | | Other expenses | 70 |
| | 127 |
| | 103 |
| Other expenses | 104 | | | 70 | | | 127 | | | | 383 |
| | 378 |
| | 424 |
| | 448 | | | 383 | | | 378 | | | Income Before Income Taxes | 1,324 |
| | 1,216 |
| | 1,287 |
| Income Before Income Taxes | 1,538 | | | 1,324 | | | 1,216 | | | | | | | | | | | Income Tax Expense | 152 |
| | 98 |
| | 175 |
| Income Tax Expense | 167 | | | 152 | | | 98 | | | | | | | | | | | | | Net Income | 1,172 |
| | 1,118 |
| | 1,112 |
| Net Income | 1,371 | | | 1,172 | | | 1,118 | | | | | | | | | | | Less: Net Income (Loss) Attributable to Noncontrolling Interests | 3 |
| | (2 | ) | | (22 | ) | Less: Net Income (Loss) Attributable to Noncontrolling Interests | 3 | | | 3 | | | (2) | | | | | | | | | | | Net Income Attributable to DTE Energy Company | $ | 1,169 |
| | $ | 1,120 |
| | $ | 1,134 |
| Net Income Attributable to DTE Energy Company | $ | 1,368 | | | $ | 1,169 | | | $ | 1,120 | | | | | | | | | | | | | | | | Basic Earnings per Common Share | | | | | | Basic Earnings per Common Share | | | | Net Income Attributable to DTE Energy Company | $ | 6.32 |
| | $ | 6.18 |
| | $ | 6.32 |
| Net Income Attributable to DTE Energy Company | $ | 7.09 | | | $ | 6.32 | | | $ | 6.18 | | | | | | | | | | | | | | | | Diluted Earnings per Common Share | | | | | | Diluted Earnings per Common Share | | | | Net Income Attributable to DTE Energy Company | $ | 6.31 |
| | $ | 6.17 |
| | $ | 6.32 |
| Net Income Attributable to DTE Energy Company | $ | 7.08 | | | $ | 6.31 | | | $ | 6.17 | | | | | | | | | | | | | | | | Weighted Average Common Shares Outstanding | | | | | | Weighted Average Common Shares Outstanding | | | Basic | 185 |
| | 181 |
| | 179 |
| Basic | 193 | | | 185 | | | 181 | | | Diluted | 185 |
| | 181 |
| | 179 |
| Diluted | 193 | | | 185 | | | 181 | |
See Combined Notes to Consolidated Financial Statements
DTE Energy Company Consolidated Statements of Comprehensive Income | | | | Year Ended December 31, | | Year Ended December 31, | | | 2019 | | 2018 | | 2017 | | 2020 | | 2019 | | 2018 | | | (In millions) | | (In millions) | | Net Income | $ | 1,172 |
| | $ | 1,118 |
| | $ | 1,112 |
| Net Income | $ | 1,371 | | | $ | 1,172 | | | $ | 1,118 | | | | | | | | | | | | | | | | Other comprehensive income (loss), net of tax: | | | | | | Other comprehensive income (loss), net of tax: | | | Benefit obligations, net of taxes of $2, $2, and $5, respectively | 8 |
| | 8 |
| | 10 |
| | | Net unrealized gains (losses) on derivatives during the period, net of taxes of $(4), $—, and $—, respectively | (12 | ) | | (1 | ) | | 1 |
| | | Net unrealized gains on investments during the period, net of taxes of $—, $—, and $1, respectively | — |
| | — |
| | 1 |
| | | Benefit obligations, net of taxes of $3, $2, and $2, respectively | | Benefit obligations, net of taxes of $3, $2, and $2, respectively | 8 | | | 8 | | | 8 | | | Net unrealized gains (losses) on derivatives, net of taxes of $1, $(4), and $0, respectively | | Net unrealized gains (losses) on derivatives, net of taxes of $1, $(4), and $0, respectively | 2 | | | (12) | | | (1) | | | | Foreign currency translation | 1 |
| | (2 | ) | | 1 |
| Foreign currency translation | 1 | | | 1 | | | (2) | | | Other comprehensive income (loss) | (3 | ) | | 5 |
| | 13 |
| Other comprehensive income (loss) | 11 | | | (3) | | | 5 | | | | | | | | | | | | | | | | Comprehensive income | 1,169 |
| | 1,123 |
| | 1,125 |
| Comprehensive income | 1,382 | | | 1,169 | | | 1,123 | | | Less: Comprehensive income (loss) attributable to noncontrolling interests | 3 |
| | (2 | ) | | (22 | ) | Less: Comprehensive income (loss) attributable to noncontrolling interests | 3 | | | 3 | | | (2) | | | Comprehensive Income Attributable to DTE Energy Company | $ | 1,166 |
| | $ | 1,125 |
| | $ | 1,147 |
| Comprehensive Income Attributable to DTE Energy Company | $ | 1,379 | | | $ | 1,166 | | | $ | 1,125 | |
See Combined Notes to Consolidated Financial Statements
DTE Energy Company Consolidated Statements of Financial Position | | | | December 31, | | December 31, | | | 2019 | | 2018 | | 2020 | | 2019 | | | (In millions) | | (In millions) | | ASSETS | ASSETS | ASSETS | | Current Assets | | | | Current Assets | | | Cash and cash equivalents | $ | 93 |
| | $ | 71 |
| Cash and cash equivalents | $ | 514 | | | $ | 93 | | | Restricted cash | — |
| | 5 |
| Restricted cash | 2 | | | 0 | | | Accounts receivable (less allowance for doubtful accounts of $91 for both periods) | | | | | | Accounts receivable (less allowance for doubtful accounts of $104 and $91, respectively) | | Accounts receivable (less allowance for doubtful accounts of $104 and $91, respectively) | | | Customer | 1,642 |
| | 1,789 |
| Customer | 1,665 | | | 1,642 | | | Other | 245 |
| | 108 |
| Other | 127 | | | 245 | | | Inventories | | | | Inventories | | | Fuel and gas | 373 |
| | 406 |
| Fuel and gas | 335 | | | 373 | | | Materials and supplies | 386 |
| | 405 |
| | | Materials, supplies, and other | | Materials, supplies, and other | 381 | | | 386 | | | Derivative assets | 133 |
| | 102 |
| Derivative assets | 116 | | | 133 | | | Regulatory assets | 5 |
| | 153 |
| Regulatory assets | 129 | | | 5 | | | Other | 209 |
| | 221 |
| Other | 229 | | | 209 | | | | 3,086 |
| | 3,260 |
| | 3,498 | | | 3,086 | | | Investments | | | | Investments | | | | | Nuclear decommissioning trust funds | 1,661 |
| | 1,378 |
| Nuclear decommissioning trust funds | 1,855 | | | 1,661 | | | Investments in equity method investees | 1,862 |
| | 1,771 |
| Investments in equity method investees | 1,868 | | | 1,862 | | | Other | 265 |
| | 219 |
| Other | 196 | | | 265 | | | | 3,788 |
| | 3,368 |
| | 3,919 | | | 3,788 | | | Property | | | | Property | | | | | Property, plant, and equipment | 35,072 |
| | 31,810 |
| Property, plant, and equipment | 37,997 | | | 35,072 | | | Accumulated depreciation and amortization | (9,755 | ) | | (10,160 | ) | Accumulated depreciation and amortization | (10,028) | | | (9,755) | | | | 25,317 |
| | 21,650 |
| | 27,969 | | | 25,317 | | | Other Assets | | | | Other Assets | | | | | Goodwill | 2,464 |
| | 2,293 |
| Goodwill | 2,466 | | | 2,464 | | | Regulatory assets | 4,171 |
| | 4,568 |
| Regulatory assets | 4,128 | | | 4,171 | | | | Intangible assets | 2,393 |
| | 849 |
| Intangible assets | 2,339 | | | 2,393 | | | Notes receivable | 202 |
| | 64 |
| Notes receivable | 280 | | | 202 | | | Derivative assets | 41 |
| | 31 |
| Derivative assets | 40 | | | 41 | | | Prepaid postretirement costs | 69 |
| | 45 |
| Prepaid postretirement costs | 561 | | | 454 | | | Operating lease right-of-use assets | 169 |
| | — |
| Operating lease right-of-use assets | 152 | | | 169 | | | Other | 182 |
| | 160 |
| Other | 144 | | | 183 | | | | 9,691 |
| | 8,010 |
| | 10,110 | | | 10,077 | | | Total Assets | $ | 41,882 |
| | $ | 36,288 |
| Total Assets | $ | 45,496 | | | $ | 42,268 | |
See Combined Notes to Consolidated Financial Statements
DTE Energy Company Consolidated Statements of Financial Position — (Continued) | | | | December 31, | | December 31, | | | 2019 | | 2018 | | 2020 | | 2019 | | | (In millions, except shares) | | (In millions, except shares) | | LIABILITIES AND EQUITY | LIABILITIES AND EQUITY | LIABILITIES AND EQUITY | | Current Liabilities | | | | Current Liabilities | | | Accounts payable | $ | 1,076 |
| | $ | 1,329 |
| Accounts payable | $ | 1,029 | | | $ | 1,076 | | | Accrued interest | 147 |
| | 127 |
| Accrued interest | 158 | | | 147 | | | Dividends payable | 195 |
| | 172 |
| Dividends payable | 210 | | | 195 | | | Short-term borrowings | 828 |
| | 609 |
| Short-term borrowings | 38 | | | 828 | | | Current portion long-term debt, including finance leases | 687 |
| | 1,499 |
| Current portion long-term debt, including finance leases | 469 | | | 687 | | | Derivative liabilities | 83 |
| | 67 |
| Derivative liabilities | 68 | | | 83 | | | Regulatory liabilities | 65 |
| | 126 |
| Regulatory liabilities | 39 | | | 65 | | | Operating lease liabilities | 33 |
| | — |
| Operating lease liabilities | 33 | | | 33 | | | Acquisition related deferred payment | 379 |
| | — |
| Acquisition related deferred payment | 0 | | | 379 | | | Other | 504 |
| | 509 |
| Other | 647 | | | 504 | | | | 3,997 |
| | 4,438 |
| | 2,691 | | | 3,997 | | | Long-Term Debt (net of current portion) | | | | Long-Term Debt (net of current portion) | | | | | Mortgage bonds, notes, and other | 14,778 |
| | 10,982 |
| Mortgage bonds, notes, and other | 17,802 | | | 14,778 | | | | Junior subordinated debentures | 1,146 |
| | 1,145 |
| Junior subordinated debentures | 1,175 | | | 1,146 | | | Finance lease obligations | 11 |
| | 7 |
| Finance lease obligations | 24 | | | 11 | | | | 15,935 |
| | 12,134 |
| | 19,001 | | | 15,935 | | | Other Liabilities | | | | Other Liabilities | | | | | Deferred income taxes | 2,315 |
| | 1,975 |
| Deferred income taxes | 2,822 | | | 2,315 | | | Regulatory liabilities | 3,264 |
| | 2,922 |
| Regulatory liabilities | 3,363 | | | 3,264 | | | Asset retirement obligations | 2,672 |
| | 2,469 |
| Asset retirement obligations | 2,839 | | | 2,672 | | | Unamortized investment tax credit | 166 |
| | 138 |
| Unamortized investment tax credit | 162 | | | 166 | | | Derivative liabilities | 86 |
| | 89 |
| Derivative liabilities | 60 | | | 86 | | | Accrued pension liability | 808 |
| | 837 |
| Accrued pension liability | 797 | | | 808 | | | Accrued postretirement liability | | Accrued postretirement liability | 407 | | | 385 | | | Nuclear decommissioning | 249 |
| | 205 |
| Nuclear decommissioning | 283 | | | 249 | | | Operating lease liability | 127 |
| | — |
| Operating lease liability | 111 | | | 127 | | | Other | 427 |
| | 364 |
| Other | 371 | | | 428 | | | | 10,114 |
| | 8,999 |
| | 11,215 | | | 10,500 | | | Commitments and Contingencies (Notes 10 and 19) | | | | Commitments and Contingencies (Notes 10 and 19) | | | | | |
|
| |
|
| | 0 | | 0 | | Equity | | | | Equity | | | Common stock (No par value, 400,000,000 shares authorized, and 192,208,533 and 181,925,281 shares issued and outstanding at December 31, 2019 and December 31, 2018, respectively) | 5,233 |
| | 4,245 |
| | | Common stock (No par value, 400,000,000 shares authorized, and 193,770,617 and 192,208,533 shares issued and outstanding at December 31, 2020 and December 31, 2019, respectively) | | Common stock (No par value, 400,000,000 shares authorized, and 193,770,617 and 192,208,533 shares issued and outstanding at December 31, 2020 and December 31, 2019, respectively) | 5,406 | | | 5,233 | | | Retained earnings | 6,587 |
| | 6,112 |
| Retained earnings | 7,156 | | | 6,587 | | | Accumulated other comprehensive loss | (148 | ) | | (120 | ) | Accumulated other comprehensive loss | (137) | | | (148) | | | Total DTE Energy Company Equity | 11,672 |
| | 10,237 |
| Total DTE Energy Company Equity | 12,425 | | | 11,672 | | | Noncontrolling interests | 164 |
| | 480 |
| Noncontrolling interests | 164 | | | 164 | | | Total Equity | 11,836 |
| | 10,717 |
| Total Equity | 12,589 | | | 11,836 | | | Total Liabilities and Equity | $ | 41,882 |
| | $ | 36,288 |
| Total Liabilities and Equity | $ | 45,496 | | | $ | 42,268 | |
See Combined Notes to Consolidated Financial Statements
DTE Energy Company Consolidated Statements of Cash Flows | |
| Year Ended December 31, | | Year Ended December 31, | | | 2019 | | 2018 | | 2017 | | 2020 | | 2019 | | 2018 | | Operating Activities | (In millions) | Operating Activities | (In millions) | | Net Income | $ | 1,172 |
| | $ | 1,118 |
| | $ | 1,112 |
| Net Income | $ | 1,371 | | | $ | 1,172 | | | $ | 1,118 | | | Adjustments to reconcile Net Income to Net cash from operating activities: | | | | | | Adjustments to reconcile Net Income to Net cash from operating activities: | | | Depreciation and amortization | 1,263 |
| | 1,124 |
| | 1,030 |
| Depreciation and amortization | 1,443 | | | 1,263 | | | 1,124 | | | Nuclear fuel amortization | 60 |
| | 45 |
| | 53 |
| Nuclear fuel amortization | 37 | | | 60 | | | 45 | | | Allowance for equity funds used during construction | (24 | ) | | (28 | ) | | (23 | ) | Allowance for equity funds used during construction | (25) | | | (24) | | | (28) | | | Deferred income taxes | 329 |
| | 114 |
| | 196 |
| Deferred income taxes | 407 | | | 329 | | | 114 | | | Equity earnings of equity method investees | (111 | ) | | (132 | ) | | (102 | ) | Equity earnings of equity method investees | (132) | | | (111) | | | (132) | | | Dividends from equity method investees | 160 |
| | 74 |
| | 74 |
| Dividends from equity method investees | 142 | | | 160 | | | 74 | | | Asset (gains) losses and impairments, net | 14 |
| | 29 |
| | 38 |
| Asset (gains) losses and impairments, net | 47 | | | 14 | | | 29 | | | Changes in assets and liabilities: | | | | | | Changes in assets and liabilities: | | | Accounts receivable, net | 49 |
| | (44 | ) | | (252 | ) | Accounts receivable, net | 111 | | | 49 | | | (44) | | | Inventories | 59 |
| | (32 | ) | | (4 | ) | Inventories | 45 | | | 59 | | | (32) | | | Prepaid postretirement benefit costs | (24 | ) | | (45 | ) | | — |
| Prepaid postretirement benefit costs | (107) | | | (24) | | | (45) | | | Accounts payable | (288 | ) | | 146 |
| | 129 |
| Accounts payable | 0 | | | (288) | | | 146 | | | Accrued pension liability | (29 | ) | | (87 | ) | | (228 | ) | Accrued pension liability | (11) | | | (29) | | | (87) | | | Accrued postretirement liability | — |
| | (61 | ) | | 25 |
| Accrued postretirement liability | 22 | | | 0 | | | (61) | | | Derivative assets and liabilities | (28 | ) | | 31 |
| | (94 | ) | Derivative assets and liabilities | (23) | | | (28) | | | 31 | | | Regulatory assets and liabilities | 160 |
| | 15 |
| | 217 |
| Regulatory assets and liabilities | 104 | | | 160 | | | 15 | | | Other current and noncurrent assets and liabilities | (113 | ) | | 413 |
| | (54 | ) | Other current and noncurrent assets and liabilities | 266 | | | (113) | | | 413 | | | Net cash from operating activities | 2,649 |
| | 2,680 |
| | 2,117 |
| Net cash from operating activities | 3,697 | | | 2,649 | | | 2,680 | | | Investing Activities | | | | | | Investing Activities | | | | | | | Plant and equipment expenditures — utility | (2,724 | ) | | (2,439 | ) | | (2,037 | ) | Plant and equipment expenditures — utility | (3,241) | | | (2,724) | | | (2,439) | | | Plant and equipment expenditures — non-utility | (273 | ) | | (274 | ) | | (213 | ) | Plant and equipment expenditures — non-utility | (616) | | | (273) | | | (274) | | | Acquisition, net of cash acquired | (2,470 | ) | | — |
| | — |
| | | Acquisitions related to business combinations, net of cash acquired | | Acquisitions related to business combinations, net of cash acquired | (126) | | | (2,470) | | | 0 | | | Proceeds from sale of assets | | Proceeds from sale of assets | 13 | | | 0 | | | 0 | | | Proceeds from sale of nuclear decommissioning trust fund assets | 788 |
| | 1,203 |
| | 1,240 |
| Proceeds from sale of nuclear decommissioning trust fund assets | 2,350 | | | 788 | | | 1,203 | | | Investment in nuclear decommissioning trust funds | (794 | ) | | (1,188 | ) | | (1,226 | ) | Investment in nuclear decommissioning trust funds | (2,350) | | | (794) | | | (1,188) | | | Distributions from equity method investees | 10 |
| | 9 |
| | 10 |
| Distributions from equity method investees | 24 | | | 10 | | | 9 | | | Contributions to equity method investees | (149 | ) | | (637 | ) | | (299 | ) | Contributions to equity method investees | (37) | | | (149) | | | (637) | | | Notes receivable | (98 | ) | | 2 |
| | 1 |
| Notes receivable | (85) | | | (98) | | | 2 | | | Other | (22 | ) | | (23 | ) | | (38 | ) | Other | (2) | | | (22) | | | (23) | | | Net cash used for investing activities | (5,732 | ) | | (3,347 | ) | | (2,562 | ) | Net cash used for investing activities | (4,070) | | | (5,732) | | | (3,347) | | | Financing Activities | | | | | | Financing Activities | | | | | | | Issuance of long-term debt, net of issuance costs | 2,506 |
| | 1,432 |
| | 1,398 |
| Issuance of long-term debt, net of issuance costs | 3,692 | | | 2,506 | | | 1,432 | | | Redemption of long-term debt | (821 | ) | | (105 | ) | | (385 | ) | Redemption of long-term debt | (882) | | | (821) | | | (105) | | | | Issuance of equity units, net of issuance costs | 1,265 |
| | — |
| | — |
| Issuance of equity units, net of issuance costs | 0 | | | 1,265 | | | 0 | | | Short-term borrowings, net | 219 |
| | (12 | ) | | 122 |
| Short-term borrowings, net | (790) | | | 219 | | | (12) | | | Issuance of common stock | 1,023 |
| | — |
| | — |
| Issuance of common stock | 2 | | | 1,023 | | | 0 | | | Repurchase of common stock | — |
| | — |
| | (51 | ) | | | Dividends on common stock | (692 | ) | | (620 | ) | | (592 | ) | | | | Dividends paid on common stock | | Dividends paid on common stock | (760) | | | (692) | | | (620) | | | Contributions from noncontrolling interests, principally REF entities | 38 |
| | 53 |
| | 50 |
| Contributions from noncontrolling interests, principally REF entities | 36 | | | 38 | | | 53 | | | Distributions to noncontrolling interests | (59 | ) | | (48 | ) | | (40 | ) | Distributions to noncontrolling interests | (39) | | | (59) | | | (48) | | | Purchases of noncontrolling interest, principally SGG | (300 | ) | | — |
| | — |
| Purchases of noncontrolling interest, principally SGG | 0 | | | (300) | | | 0 | | | Acquisition related deferred payment, excluding accretion | | Acquisition related deferred payment, excluding accretion | (380) | | | 0 | | | 0 | | | Other | (79 | ) | | (46 | ) | | (81 | ) | Other | (83) | | | (79) | | | (46) | | | Net cash from financing activities | 3,100 |
| | 654 |
| | 421 |
| Net cash from financing activities | 796 | | | 3,100 | | | 654 | | | Net Increase (Decrease) in Cash, Cash Equivalents, and Restricted Cash | 17 |
| | (13 | ) | | (24 | ) | Net Increase (Decrease) in Cash, Cash Equivalents, and Restricted Cash | 423 | | | 17 | | | (13) | | | Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | 76 |
| | 89 |
| | 113 |
| Cash, Cash Equivalents, and Restricted Cash at Beginning of Period | 93 | | | 76 | | | 89 | | | Cash, Cash Equivalents, and Restricted Cash at End of Period | $ | 93 |
| | $ | 76 |
| | $ | 89 |
| Cash, Cash Equivalents, and Restricted Cash at End of Period | $ | 516 | | | $ | 93 | | | $ | 76 | | | | | | | | | | | | | | | | Supplemental disclosure of cash information | | | | | | Supplemental disclosure of cash information | | | Cash paid (received) for: | | | | | | Cash paid (received) for: | | | Interest, net of interest capitalized | $ | 595 |
| | $ | 572 |
| | $ | 495 |
| Interest, net of interest capitalized | $ | 679 | | | $ | 595 | | | $ | 572 | | | Income taxes | $ | 18 |
| | $ | (26 | ) | | $ | 4 |
| | Supplemental disclosure of non-cash investing and financing activities(a) | | | | | | | Income taxes(a) | | Income taxes(a) | $ | (360) | | | $ | 18 | | | $ | (26) | | | Supplemental disclosure of non-cash investing and financing activities | | Supplemental disclosure of non-cash investing and financing activities | | | | Plant and equipment expenditures in accounts payable | $ | 311 |
| | $ | 307 |
| | $ | 295 |
| Plant and equipment expenditures in accounts payable | $ | 266 | | | $ | 311 | | | $ | 307 | | | Premium on equity units | $ | 150 |
| | $ | — |
| | $ | — |
| Premium on equity units | $ | 0 | | | $ | 150 | | | $ | 0 | |
| | (a) | See Note 15 to the Consolidated Financial Statements, "Long-Term Debt" for additional non-cash financing activity related to the remarketing of RSNs. |
(a)2020 cash received primarily relates to AMT credit and other refunds, of which a portion was accelerated due to and CARES Act. See Note 11 to the Consolidated Financial Statements, "Income Taxes," for additional information. See Combined Notes to Consolidated Financial Statements
DTE Energy Company Consolidated Statements of Changes in Equity | | | | | | | | | | | | | | | Retained Earnings | | Accumulated Other Comprehensive Income (Loss) | | Noncontrolling Interests | | | | | | | | Retained Earnings | | Accumulated Other Comprehensive Income (Loss) | | Noncontrolling Interests | | | | Common Stock | | | | Common Stock | | | | Shares | | Amount | | Total | | | Shares | | Amount | | Total | | (Dollars in millions, shares in thousands) | | | (Dollars in millions, shares in thousands) | | | Balance, December 31, 2016 | 179,433 |
| | $ | 4,030 |
| | $ | 5,114 |
| | $ | (133 | ) | | $ | 488 |
| | $ | 9,499 |
| | | Net Income (Loss) | — |
| | — |
| | 1,134 |
| | — |
| | (22 | ) | | 1,112 |
| | | Dividends declared on common stock ($3.36 per Common Share) | — |
| | — |
| | (602 | ) | | — |
| | — |
| | (602 | ) | | | Repurchase of common stock | (524 | ) | | (51 | ) | | — |
| | — |
| | — |
| | (51 | ) | | | Other comprehensive income, net of tax | — |
| | — |
| | — |
| | 13 |
| | — |
| | 13 |
| | | Stock-based compensation, net contributions from noncontrolling interests, and other | 478 |
| | 10 |
| | (3 | ) | | — |
| | 12 |
| | 19 |
| | | Balance, December 31, 2017 | 179,387 |
| | $ | 3,989 |
| | $ | 5,643 |
| | $ | (120 | ) | | $ | 478 |
| | $ | 9,990 |
| Balance, December 31, 2017 | 179,387 | | | $ | 3,989 | | | $ | 5,643 | | | $ | (120) | | | $ | 478 | | | $ | 9,990 | | | Implementation of ASU 2016-01 | — |
| | — |
| | 5 |
| | (5 | ) | | — |
| | — |
| Implementation of ASU 2016-01 | — | | | — | | | 5 | | | (5) | | | — | | | $ | 0 | | | Net Income (Loss) | — |
| | — |
| | 1,120 |
| | — |
| | (2 | ) | | 1,118 |
| Net Income (Loss) | — | | | — | | | 1,120 | | | — | | | (2) | | | 1,118 | | | Dividends declared on common stock ($3.60 per Common Share) | — |
| | — |
| | (653 | ) | | — |
| | — |
| | (653 | ) | Dividends declared on common stock ($3.60 per Common Share) | — | | | — | | | (653) | | | — | | | — | | | (653) | | | | Issuance of common stock | 255 |
| | 26 |
| | — |
| | — |
| | — |
| | 26 |
| Issuance of common stock | 255 | | | 26 | | | — | | | — | | | — | | | 26 | | | Contribution of common stock to pension plan | 1,751 |
| | 175 |
| | — |
| | — |
| | — |
| | 175 |
| Contribution of common stock to pension plan | 1,751 | | | 175 | | | — | | | — | | | — | | | 175 | | | Other comprehensive income, net of tax | — |
| | — |
| | — |
| | 5 |
| | — |
| | 5 |
| Other comprehensive income, net of tax | — | | | — | | | — | | | 5 | | | — | | | 5 | | | Stock-based compensation, net contributions from noncontrolling interests, and other | 532 |
| | 55 |
| | (3 | ) | | — |
| | 4 |
| | 56 |
| Stock-based compensation, net contributions from noncontrolling interests, and other | 532 | | | 55 | | | (3) | | | — | | | 4 | | | 56 | | | Balance, December 31, 2018 | 181,925 |
| | $ | 4,245 |
| | $ | 6,112 |
| | $ | (120 | ) | | $ | 480 |
| | $ | 10,717 |
| Balance, December 31, 2018 | 181,925 | | | $ | 4,245 | | | $ | 6,112 | | | $ | (120) | | | $ | 480 | | | $ | 10,717 | | | Implementation of ASU 2018-02 | — |
| | — |
| | 25 |
| | (25 | ) | | — |
| | — |
| Implementation of ASU 2018-02 | — | | | — | | | 25 | | | (25) | | | — | | | 0 | | | Net Income | — |
| | — |
| | 1,169 |
| | — |
| | 3 |
| | 1,172 |
| Net Income | — | | | — | | | 1,169 | | | — | | | 3 | | | 1,172 | | | Dividends declared on common stock ($3.85 per Common Share) | — |
| | — |
| | (714 | ) | | — |
| | — |
| | (714 | ) | Dividends declared on common stock ($3.85 per Common Share) | — | | | — | | | (714) | | | — | | | — | | | (714) | | | | Issuance of common stock | 8,634 |
| | 1,014 |
| | — |
| | — |
| | — |
| | 1,014 |
| Issuance of common stock | 8,634 | | | 1,014 | | | — | | | — | | | — | | | 1,014 | | | Premium on equity units | — |
| | (150 | ) | | — |
| | — |
| | — |
| | (150 | ) | Premium on equity units | — | | | (150) | | | — | | | — | | | — | | | (150) | | | Issuance costs of equity units | — |
| | (30 | ) | | — |
| | — |
| | — |
| | (30 | ) | Issuance costs of equity units | — | | | (30) | | | — | | | — | | | — | | | (30) | | | Contribution of common stock to pension plan | 815 |
| | 100 |
| | — |
| | — |
| | — |
| | 100 |
| Contribution of common stock to pension plan | 815 | | | 100 | | | — | | | — | | | — | | | 100 | | | Other comprehensive loss, net of tax | — |
| | — |
| | — |
| | (3 | ) | | — |
| | (3 | ) | Other comprehensive loss, net of tax | — | | | — | | | — | | | (3) | | | — | | | (3) | | | Purchase of noncontrolling interests, principally SGG | — |
| | (3 | ) | | — |
| | — |
| | (297 | ) | | (300 | ) | Purchase of noncontrolling interests, principally SGG | — | | | (3) | | | — | | | — | | | (297) | | | (300) | | | Stock-based compensation, net distributions to noncontrolling interests, and other | 835 |
| | 57 |
| | (5 | ) | | — |
| | (22 | ) | | 30 |
| Stock-based compensation, net distributions to noncontrolling interests, and other | 835 | | | 57 | | | (5) | | | — | | | (22) | | | 30 | | | Balance, December 31, 2019 | 192,209 |
| | $ | 5,233 |
| | $ | 6,587 |
| | $ | (148 | ) | | $ | 164 |
| | $ | 11,836 |
| Balance, December 31, 2019 | 192,209 | | | $ | 5,233 | | | $ | 6,587 | | | $ | (148) | | | $ | 164 | | | $ | 11,836 | | | | Net Income | | Net Income | — | | | — | | | 1,368 | | | — | | | 3 | | | 1,371 | | | Dividends declared on common stock ($4.12 per Common Share) | | Dividends declared on common stock ($4.12 per Common Share) | — | | | — | | | (796) | | | — | | | — | | | (796) | | | Issuance of common stock | | Issuance of common stock | 192 | | | 22 | | | — | | | — | | | — | | | 22 | | | | Contribution of common stock to pension plan | | Contribution of common stock to pension plan | 694 | | | 82 | | | — | | | — | | | — | | | 82 | | | Other comprehensive income, net of tax | | Other comprehensive income, net of tax | — | | | — | | | — | | | 11 | | | — | | | 11 | | | | Stock-based compensation, net distributions to noncontrolling interests, and other | | Stock-based compensation, net distributions to noncontrolling interests, and other | 676 | | | 69 | | | (3) | | | — | | | (3) | | | 63 | | | Balance, December 31, 2020 | | Balance, December 31, 2020 | 193,771 | | | $ | 5,406 | | | $ | 7,156 | | | $ | (137) | | | $ | 164 | | | $ | 12,589 | |
See Combined Notes to Consolidated Financial Statements
DTE Electric — Controls and Procedures (a) Evaluation of disclosure controls and procedures Management of DTE Electric carried out an evaluation, under the supervision and with the participation of DTE Electric's Chief Executive Officer (CEO) and Chief Financial Officer (CFO), of the effectiveness of the design and operation of DTE Electric's disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of December 31, 2019,2020, which is the end of the period covered by this report. Based on this evaluation, DTE Electric's CEO and CFO have concluded that such disclosure controls and procedures are effective in providing reasonable assurance that information required to be disclosed by DTE Electric in reports that it files or submits under the Exchange Act (i) is recorded, processed, summarized, and reported within the time periods specified in the U.S. Securities and Exchange Commission's rules and forms and (ii) is accumulated and communicated to DTE Electric's management, including its CEO and CFO, as appropriate to allow timely decisions regarding required disclosure. Due to the inherent limitations in the effectiveness of any disclosure controls and procedures, management cannot provide absolute assurance that the objectives of its disclosure controls and procedures will be attained. (b) Management’s report on internal control over financial reporting Management of DTE Electric is responsible for establishing and maintaining adequate internal control over financial reporting as such term is defined in Exchange Act Rules 13a-15(f) and 15d-15(f). Internal control over financial reporting is a process designed by, or under the supervision of, DTE Electric's CEO and CFO, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate. Management of DTE Electric has assessed the effectiveness of DTE Electric's internal control over financial reporting as of December 31, 2019.2020. In making this assessment, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (2013 COSO) in Internal Control - Integrated Framework. Based on this assessment, management concluded that, as of December 31, 2019,2020, DTE Electric's internal control over financial reporting was effective based on those criteria. This annual report does not include an audit report of DTE Electric's independent registered public accounting firm regarding internal control over financial reporting. Management’s report was not subject to audit by DTE Electric's independent registered public accounting firm pursuant to rules of the Securities and Exchange Commission that permit DTE Electric to provide only management’s report in this annual report. (c) Changes in internal control over financial reporting There have been no changes in DTE Electric's internal control over financial reporting during the quarter ended December 31, 20192020 that have materially affected, or are reasonably likely to materially affect, DTE Electric's internal control over financial reporting.
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRMReport of Independent Registered Public Accounting Firm
To the Board of Directors and Shareholder of DTE Electric Company Opinion on the Financial Statements We have audited the accompanying consolidated statements of financial position of DTE Electric Company and its subsidiaries (the “Company”) as of December 31, 20192020 and 2018,2019, and the related consolidated statements of operations, of comprehensive income, of changes in shareholder’s equity and of cash flows for each of the three years in the period ended December 31, 2019,2020, including the related notes and financial statement schedule listed in the accompanying index for each of the three years in the period ended December 31, 20192020 (collectively referred to as the “consolidated financial statements”). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 20192020 and 2018,2019, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 20192020 in conformity with accounting principles generally accepted in the United States of America. Basis for Opinion These consolidated financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company’s consolidated financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB. We conducted our audits of these consolidated financial statements in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion. Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.
The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that (i) relates to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates. Accounting for the Effects of New, or Changes to Existing, Regulatory Matters As described in Note 10 to the consolidated financial statements, the Company recorded $3,563 million of regulatory assets and $2,450 million of regulatory liabilities as of December 31, 2020. The Company is required to record regulatory assets and liabilities for certain transactions that would have been treated as revenue or expense in non-regulated businesses. Continued applicability of regulatory accounting treatment requires that rates be designed to recover specific costs of providing regulatory services and be charged to and collected from customers. Future regulatory changes could result in a discontinuance of this accounting treatment for regulatory assets and liabilities for some or all of the Company’s regulated businesses and may require the write-off of the portion of any regulatory asset or liability that was no longer probable of recovery through regulated rates. Management believes that currently available facts support the continued use of regulatory assets and liabilities and that all regulatory assets and liabilities are recoverable or refundable in the current regulatory environment.
The principal considerations for our determination that performing procedures relating to the Company's accounting for the effects of new, or changes to existing, regulatory matters is a critical audit matter are the significant judgment by management in assessing the potential outcome and resulting accounting implications of new, or changes to existing, regulatory matters; this in turn led to a high degree of auditor judgment, subjectivity and effort in evaluating the appropriateness of management’s assessment and audit evidence obtained related to the assessment. Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to management’s assessment and implementation of new regulatory matters or changes to existing regulatory matters. These procedures also included, among others, assessing (i) the reasonableness of management’s assessment of impacts arising from correspondence with regulators and changes in laws and regulations and (ii) the appropriateness of disclosures in the consolidated financial statements. Testing regulatory assets and liabilities, including those subject to pending rate orders, involved considering the provisions and formulas outlined in the rate orders, other regulatory correspondence, and the application of relevant regulatory precedents.
/s/ PricewaterhouseCoopers LLP
Detroit, Michigan February 5, 202019, 2021
We have served as the Company's auditor since 2008.
DTE Electric Company Consolidated Statements of Operations | | | | Year Ended December 31, | | Year Ended December 31, | | | 2019 | | 2018 | | 2017 | | 2020 | | 2019 | | 2018 | | | (In millions) | | (In millions) | | Operating Revenues | $ | 5,224 |
| | $ | 5,298 |
| | $ | 5,102 |
| Operating Revenues | $ | 5,506 | | | $ | 5,224 | | | $ | 5,298 | | | | | | | | | | | | | | | | Operating Expenses | | | | | | Operating Expenses | | | Fuel and purchased power — utility | 1,390 |
| | 1,552 |
| | 1,454 |
| Fuel and purchased power — utility | 1,397 | | | 1,390 | | | 1,552 | | | Operation and maintenance | 1,452 |
| | 1,470 |
| | 1,428 |
| Operation and maintenance | 1,505 | | | 1,452 | | | 1,470 | | | Depreciation and amortization | 946 |
| | 836 |
| | 753 |
| Depreciation and amortization | 1,043 | | | 946 | | | 836 | | | Taxes other than income | 310 |
| | 307 |
| | 302 |
| Taxes other than income | 296 | | | 310 | | | 307 | | | Asset (gains) losses and impairments, net | 13 |
| | (1 | ) | | — |
| Asset (gains) losses and impairments, net | 41 | | | 13 | | | (1) | | | | 4,111 |
| | 4,164 |
| | 3,937 |
| | 4,282 | | | 4,111 | | | 4,164 | | | Operating Income | 1,113 |
|
| 1,134 |
|
| 1,165 |
| Operating Income | 1,224 | | | 1,113 | | | 1,134 | | | | | | | | | | | | | | | | Other (Income) and Deductions | | | | | | Other (Income) and Deductions | | | Interest expense | 313 |
| | 283 |
| | 274 |
| Interest expense | 331 | | | 313 | | | 283 | | | Interest income | (2 | ) | | — |
| | — |
| Interest income | (2) | | | (2) | | | 0 | | | Non-operating retirement benefits, net | (1 | ) | | — |
| | — |
| Non-operating retirement benefits, net | (1) | | | (1) | | | 0 | | | Other income | (107 | ) | | (83 | ) | | (77 | ) | Other income | (87) | | | (107) | | | (83) | | | Other expenses | 56 |
| | 77 |
| | 40 |
| Other expenses | 96 | | | 56 | | | 77 | | | | 259 |
| | 277 |
| | 237 |
| | 337 | | | 259 | | | 277 | | | Income Before Income Taxes | 854 |
| | 857 |
| | 928 |
| Income Before Income Taxes | 887 | | | 854 | | | 857 | | | | | | | | | | | Income Tax Expense | 138 |
| | 193 |
| | 327 |
| Income Tax Expense | 109 | | | 138 | | | 193 | | | | | | | | | | | Net Income | $ | 716 |
| | $ | 664 |
| | $ | 601 |
| Net Income | $ | 778 | | | $ | 716 | | | $ | 664 | |
See Combined Notes to Consolidated Financial Statements
DTE Electric Company Consolidated Statements of Comprehensive Income | | | | Year Ended December 31, | | Year Ended December 31, | | | 2019 | | 2018 | | 2017 | | 2020 | | 2019 | | 2018 | | | (In millions) | | (In millions) | | Net Income | $ | 716 |
| | $ | 664 |
| | $ | 601 |
| Net Income | $ | 778 | | | $ | 716 | | | $ | 664 | | | Other comprehensive income, net of tax: | | | | | | | | Net unrealized gains on investments during the period, net of taxes of $—, $—, and $1, respectively | — |
| | — |
| | 1 |
| | | | Other comprehensive income | — |
|
| — |
|
| 1 |
| Other comprehensive income | 0 | | | 0 | | | 0 | | | Comprehensive Income | $ | 716 |
|
| $ | 664 |
|
| $ | 602 |
| Comprehensive Income | $ | 778 | | | $ | 716 | | | $ | 664 | |
See Combined Notes to Consolidated Financial Statements
DTE Electric Company Consolidated Statements of Financial Position | | | | December 31, | | December 31, | | | 2019 | | 2018 | | 2020 | | 2019 | | | (In millions) | | (In millions) | | ASSETS | ASSETS | ASSETS | | Current Assets | | | | Current Assets | | | Cash and cash equivalents | $ | 12 |
| | $ | 18 |
| Cash and cash equivalents | $ | 16 | | | $ | 12 | | | Accounts receivable (less allowance for doubtful accounts of $46 and $53, respectively) | | | | | | | Accounts receivable (less allowance for doubtful accounts of $57 and $46, respectively) | | Accounts receivable (less allowance for doubtful accounts of $57 and $46, respectively) | | | Customer | 729 |
| | 750 |
| Customer | 763 | | | 729 | | | Affiliates | 25 |
| | 11 |
| Affiliates | 13 | | | 25 | | | Other | 41 |
| | 54 |
| Other | 62 | | | 41 | | | Inventories | | | | Inventories | | | Fuel | 187 |
| | 171 |
| Fuel | 187 | | | 187 | | | Materials and supplies | 280 |
| | 279 |
| Materials and supplies | 292 | | | 280 | | | | Regulatory assets | 5 |
| | 148 |
| Regulatory assets | 123 | | | 5 | | | Other | 78 |
| | 89 |
| Other | 71 | | | 78 | | | | 1,357 |
| | 1,520 |
| | 1,527 | | | 1,357 | | | Investments | | | | Investments | | | | | Nuclear decommissioning trust funds | 1,661 |
| | 1,378 |
| Nuclear decommissioning trust funds | 1,855 | | | 1,661 | | | Other | 38 |
| | 34 |
| Other | 42 | | | 38 | | | | 1,699 |
| | 1,412 |
| | 1,897 | | | 1,699 | | | Property | | | | Property | | | | | Property, plant, and equipment | 24,279 |
| | 22,747 |
| Property, plant, and equipment | 26,171 | | | 24,279 | | | Accumulated depreciation and amortization | (6,706 | ) | | (7,310 | ) | Accumulated depreciation and amortization | (7,050) | | | (6,706) | | | | 17,573 |
| | 15,437 |
| | 19,121 | | | 17,573 | | | Other Assets | | | | Other Assets | | | | | Regulatory assets | 3,448 |
| | 3,829 |
| Regulatory assets | 3,440 | | | 3,448 | | | | Intangible assets | 15 |
| | 21 |
| Intangible assets | 11 | | | 15 | | | Prepaid postretirement costs — affiliates | 266 |
| | 189 |
| Prepaid postretirement costs — affiliates | 335 | | | 266 | | | Operating lease right-of-use assets | 87 |
| | — |
| Operating lease right-of-use assets | 75 | | | 87 | | | Other | 143 |
| | 121 |
| Other | 107 | | | 143 | | | | 3,959 |
| | 4,160 |
| | 3,968 | | | 3,959 | | | Total Assets | $ | 24,588 |
| | $ | 22,529 |
| Total Assets | $ | 26,513 | | | $ | 24,588 | |
See Combined Notes to Consolidated Financial Statements
DTE Electric Company Consolidated Statements of Financial Position — (Continued) | | | | December 31, | | December 31, | | | 2019 | | 2018 | | 2020 | | 2019 | | | (In millions, except shares) | | (In millions, except shares) | | LIABILITIES AND SHAREHOLDER'S EQUITY | LIABILITIES AND SHAREHOLDER'S EQUITY | LIABILITIES AND SHAREHOLDER'S EQUITY | | Current Liabilities | | | | Current Liabilities | | | Accounts payable | | | | Accounts payable | | | Affiliates | $ | 59 |
| | $ | 71 |
| Affiliates | $ | 62 | | | $ | 59 | | | Other | 406 |
| | 441 |
| Other | 410 | | | 406 | | | Accrued interest | 84 |
| | 74 |
| Accrued interest | 91 | | | 84 | | | | Current portion long-term debt, including finance leases | 636 |
| | 4 |
| Current portion long-term debt, including finance leases | 468 | | | 636 | | | Regulatory liabilities | 40 |
| | 98 |
| Regulatory liabilities | 18 | | | 40 | | | Short-term borrowings | | | | Short-term borrowings | | | Affiliates | 97 |
| | 101 |
| Affiliates | 101 | | | 97 | | | Other | 354 |
| | 149 |
| Other | 0 | | | 354 | | | Operating lease liabilities | 12 |
| | — |
| Operating lease liabilities | 11 | | | 12 | | | Other | 155 |
| | 139 |
| Other | 219 | | | 155 | | | | 1,843 |
| | 1,077 |
| | 1,380 | | | 1,843 | | | Long-Term Debt (net of current portion) | | | | Long-Term Debt (net of current portion) | | | | | Mortgage bonds, notes, and other | 6,548 |
| | 6,538 |
| Mortgage bonds, notes, and other | 7,774 | | | 6,548 | | | Finance lease obligations | 4 |
| | 7 |
| Finance lease obligations | 13 | | | 4 | | | | 6,552 |
| | 6,545 |
| | 7,787 | | | 6,552 | | | Other Liabilities | | | | Other Liabilities | | | | | Deferred income taxes | 2,355 |
| | 2,246 |
| Deferred income taxes | 2,525 | | | 2,355 | | | Regulatory liabilities | 2,546 |
| | 2,171 |
| Regulatory liabilities | 2,432 | | | 2,546 | | | Asset retirement obligations | 2,447 |
| | 2,271 |
| Asset retirement obligations | 2,607 | | | 2,447 | | | Unamortized investment tax credit | 166 |
| | 137 |
| Unamortized investment tax credit | 162 | | | 166 | | | Nuclear decommissioning | 249 |
| | 205 |
| Nuclear decommissioning | 283 | | | 249 | | | Accrued pension liability — affiliates | 717 |
| | 718 |
| Accrued pension liability — affiliates | 731 | | | 717 | | | Accrued postretirement liability — affiliates | 367 |
| | 278 |
| Accrued postretirement liability — affiliates | 384 | | | 367 | | | Operating lease liabilities | 67 |
| | — |
| Operating lease liabilities | 56 | | | 67 | | | Other | 84 |
| | 88 |
| Other | 96 | | | 84 | | | | 8,998 |
| | 8,114 |
| | 9,276 | | | 8,998 | | | Commitments and Contingencies (Notes 10 and 19) |
|
| |
|
| Commitments and Contingencies (Notes 10 and 19) | 0 | | 0 | | | | | | | | Shareholder's Equity | | | | Shareholder's Equity | | | Common stock ($10 par value, 400,000,000 shares authorized, and 138,632,234 shares issued and outstanding for both periods) | 4,811 |
| | 4,631 |
| | | Common stock ($10 par value, 400,000,000 shares authorized, and 138,632,324 shares issued and outstanding for both periods) | | Common stock ($10 par value, 400,000,000 shares authorized, and 138,632,324 shares issued and outstanding for both periods) | 5,447 | | | 4,811 | | | Retained earnings | 2,384 |
| | 2,162 |
| Retained earnings | 2,623 | | | 2,384 | | | | Total Shareholder's Equity | 7,195 |
| | 6,793 |
| Total Shareholder's Equity | 8,070 | | | 7,195 | | | Total Liabilities and Shareholder's Equity | $ | 24,588 |
| | $ | 22,529 |
| Total Liabilities and Shareholder's Equity | $ | 26,513 | | | $ | 24,588 | |
See Combined Notes to Consolidated Financial Statements
DTE Electric Company Consolidated Statements of Cash Flows | | | | Year Ended December 31, | | Year Ended December 31, | | | 2019 | | 2018 | | 2017 | | 2020 | | 2019 | | 2018 | | Operating Activities | (In millions) | Operating Activities | (In millions) | | Net Income | $ | 716 |
| | $ | 664 |
| | $ | 601 |
| Net Income | $ | 778 | | | $ | 716 | | | $ | 664 | | | Adjustments to reconcile Net Income to Net cash from operating activities: | | | | | | Adjustments to reconcile Net Income to Net cash from operating activities: | | | Depreciation and amortization | 946 |
| | 836 |
| | 753 |
| Depreciation and amortization | 1,043 | | | 946 | | | 836 | | | Nuclear fuel amortization | 60 |
| | 45 |
| | 53 |
| Nuclear fuel amortization | 37 | | | 60 | | | 45 | | | Allowance for equity funds used during construction | (22 | ) | | (19 | ) | | (18 | ) | Allowance for equity funds used during construction | (23) | | | (22) | | | (19) | | | Deferred income taxes | 97 |
| | 189 |
| | 345 |
| Deferred income taxes | 89 | | | 97 | | | 189 | | | Asset (gains) losses and impairments, net | 13 |
| | — |
| | — |
| Asset (gains) losses and impairments, net | 41 | | | 13 | | | 0 | | | Changes in assets and liabilities: | | | | | | Changes in assets and liabilities: | | | Accounts receivable, net | 20 |
| | 33 |
| | (80 | ) | Accounts receivable, net | (42) | | | 20 | | | 33 | | | Inventories | (17 | ) | | 15 |
| | 31 |
| Inventories | (12) | | | (17) | | | 15 | | | Prepaid postretirement benefit costs — affiliates | (77 | ) | | (76 | ) | | 1 |
| Prepaid postretirement benefit costs — affiliates | (69) | | | (77) | | | (76) | | | Accounts payable | (57 | ) | | 54 |
| | (2 | ) | Accounts payable | 20 | | | (57) | | | 54 | | | Accrued pension liability — affiliates | (1 | ) | | (93 | ) | | (197 | ) | Accrued pension liability — affiliates | 14 | | | (1) | | | (93) | | | Accrued postretirement liability — affiliates | 89 |
| | (33 | ) | | 42 |
| Accrued postretirement liability — affiliates | 17 | | | 89 | | | (33) | | | Regulatory assets and liabilities | 139 |
| | 4 |
| | 202 |
| Regulatory assets and liabilities | 55 | | | 139 | | | 4 | | | Other current and noncurrent assets and liabilities | (197 | ) | | 101 |
| | (147 | ) | Other current and noncurrent assets and liabilities | (43) | | | (197) | | | 101 | | | Net cash from operating activities | 1,709 |
| | 1,720 |
| | 1,584 |
| Net cash from operating activities | 1,905 | | | 1,709 | | | 1,720 | | | Investing Activities | | | | | | Investing Activities | | | | | | | Plant and equipment expenditures | (2,200 | ) | | (1,989 | ) | | (1,574 | ) | Plant and equipment expenditures | (2,674) | | | (2,200) | | | (1,989) | | | | Proceeds from sale of nuclear decommissioning trust fund assets | 788 |
| | 1,203 |
| | 1,240 |
| Proceeds from sale of nuclear decommissioning trust fund assets | 2,350 | | | 788 | | | 1,203 | | | Investment in nuclear decommissioning trust funds | (794 | ) | | (1,188 | ) | | (1,226 | ) | Investment in nuclear decommissioning trust funds | (2,350) | | | (794) | | | (1,188) | | | Other | (21 | ) | | (15 | ) | | 18 |
| | | Notes receivable and other | | Notes receivable and other | (8) | | | (21) | | | (15) | | | Net cash used for investing activities | (2,227 | ) | | (1,989 | ) | | (1,542 | ) | Net cash used for investing activities | (2,682) | | | (2,227) | | | (1,989) | | | Financing Activities | | | | | | Financing Activities | | | | | | | Issuance of long-term debt, net of issuance costs | 643 |
| | 519 |
| | 435 |
| Issuance of long-term debt, net of issuance costs | 1,683 | | | 643 | | | 519 | | | Redemption of long-term debt | — |
| | — |
| | (300 | ) | Redemption of long-term debt | (632) | | | 0 | | | 0 | | | | Capital contribution by parent company | 180 |
| | 325 |
| | 100 |
| Capital contribution by parent company | 636 | | | 180 | | | 325 | | | Short-term borrowings, net — affiliate | (4 | ) | | (15 | ) | | (1 | ) | Short-term borrowings, net — affiliate | 4 | | | (4) | | | (15) | | | Short-term borrowings, net — other | 205 |
| | (89 | ) | | 176 |
| Short-term borrowings, net — other | (354) | | | 205 | | | (89) | | | Dividends on common stock | (494 | ) | | (461 | ) | | (432 | ) | | | Dividends paid on common stock | | Dividends paid on common stock | (539) | | | (494) | | | (461) | | | Other | (18 | ) | | (7 | ) | | (18 | ) | Other | (17) | | | (18) | | | (7) | | | Net cash from (used for) financing activities | 512 |
| | 272 |
| | (40 | ) | | | Net cash from financing activities | | Net cash from financing activities | 781 | | | 512 | | | 272 | | | Net Increase (Decrease) in Cash and Cash Equivalents | (6 | ) | | 3 |
| | 2 |
| Net Increase (Decrease) in Cash and Cash Equivalents | 4 | | | (6) | | | 3 | | | Cash and Cash Equivalents at Beginning of Period | 18 |
| | 15 |
| | 13 |
| Cash and Cash Equivalents at Beginning of Period | 12 | | | 18 | | | 15 | | | Cash and Cash Equivalents at End of Period | $ | 12 |
| | $ | 18 |
| | $ | 15 |
| Cash and Cash Equivalents at End of Period | $ | 16 | | | $ | 12 | | | $ | 18 | | | | | | | | | | | | | | | | Supplemental disclosure of cash information | | | | | | Supplemental disclosure of cash information | | | Cash paid (received) for: | | | | | | | | Cash paid for: | | Cash paid for: | | | Interest, net of interest capitalized | $ | 295 |
| | $ | 283 |
| | $ | 252 |
| Interest, net of interest capitalized | $ | 315 | | | $ | 295 | | | $ | 283 | | | Income taxes | $ | 46 |
| | $ | — |
| | $ | (16 | ) | Income taxes | $ | 14 | | | $ | 46 | | | $ | 0 | | | Supplemental disclosure of non-cash investing and financing activities | | | | | | Supplemental disclosure of non-cash investing and financing activities | | | Plant and equipment expenditures in accounts payable | $ | 192 |
| | $ | 181 |
| | $ | 191 |
| Plant and equipment expenditures in accounts payable | $ | 174 | | | $ | 192 | | | $ | 181 | |
See Combined Notes to Consolidated Financial Statements
DTE Electric Company Consolidated Statements of Changes in Shareholder's Equity | | | | | | | | | | | | | | | Additional Paid-in Capital | | Retained Earnings | | Accumulated Other Comprehensive Income | | | | | | | | Additional Paid-in Capital | | Retained Earnings | | Accumulated Other Comprehensive Income | | | | Common Stock | | | | Common Stock | | | | Shares | | Amount | | Total | | | Shares | | Amount | | Total | | (Dollars in millions, shares in thousands) | | | (Dollars in millions, shares in thousands) | | | Balance, December 31, 2016 | 138,632 |
| | $ | 1,386 |
| | $ | 2,820 |
| | $ | 1,787 |
| | $ | 2 |
| | $ | 5,995 |
| | | Net Income | — |
| | — |
| | — |
| | 601 |
| | — |
| | 601 |
| | | Dividends declared on common stock | — |
| | — |
| | — |
| | (432 | ) | | — |
| | (432 | ) | | | Other comprehensive income, net of tax | — |
| | — |
| | — |
| | — |
| | 1 |
| | 1 |
| | | Capital contribution by parent company | — |
| | — |
| | 100 |
| | — |
| | — |
| | 100 |
| | | Balance, December 31, 2017 | 138,632 |
| | $ | 1,386 |
| | $ | 2,920 |
| | $ | 1,956 |
| | $ | 3 |
| | $ | 6,265 |
| Balance, December 31, 2017 | 138,632 | | | $ | 1,386 | | | $ | 2,920 | | | $ | 1,956 | | | $ | 3 | | | $ | 6,265 | | | Implementation of ASU 2016-01 | — |
| | — |
| | — |
| | 3 |
| | (3 | ) | | — |
| Implementation of ASU 2016-01 | — | | | — | | | — | | | 3 | | | (3) | | | 0 | | | Net Income | — |
| | — |
| | — |
| | 664 |
| | — |
| | 664 |
| Net Income | — | | | — | | | — | | | 664 | | | — | | | 664 | | | Dividends declared on common stock | — |
| | — |
| | — |
| | (461 | ) | | — |
| | (461 | ) | Dividends declared on common stock | — | | | — | | | — | | | (461) | | | — | | | (461) | | | | Capital contribution by parent company | — |
| | — |
| | 325 |
| | — |
| | — |
| | 325 |
| Capital contribution by parent company | — | | | — | | | 325 | | | — | | | — | | | 325 | | | Balance, December 31, 2018 | 138,632 |
| | $ | 1,386 |
| | $ | 3,245 |
| | $ | 2,162 |
| | $ | — |
| | $ | 6,793 |
| Balance, December 31, 2018 | 138,632 | | | $ | 1,386 | | | $ | 3,245 | | | $ | 2,162 | | | $ | 0 | | | $ | 6,793 | | | | Net Income | — |
| | — |
| | — |
| | 716 |
| | — |
| | 716 |
| Net Income | — | | | — | | | — | | | 716 | | | — | | | 716 | | | Dividends declared on common stock | — |
| | — |
| | — |
| | (494 | ) | | — |
| | (494 | ) | Dividends declared on common stock | — | | | — | | | — | | | (494) | | | — | | | (494) | | | | Capital contribution by parent company | — |
| | — |
| | 180 |
| | — |
| | — |
| | 180 |
| Capital contribution by parent company | — | | | — | | | 180 | | | — | | | — | | | 180 | | | Balance, December 31, 2019 | 138,632 |
| | $ | 1,386 |
| | $ | 3,425 |
| | $ | 2,384 |
| | $ | — |
| | $ | 7,195 |
| Balance, December 31, 2019 | 138,632 | | | $ | 1,386 | | | $ | 3,425 | | | $ | 2,384 | | | $ | 0 | | | $ | 7,195 | | | | Net Income | | Net Income | — | | | — | | | — | | | 778 | | | — | | | 778 | | | Dividends declared on common stock | | Dividends declared on common stock | — | | | — | | | — | | | (539) | | | — | | | (539) | | | | Capital contribution by parent company | | Capital contribution by parent company | — | | | — | | | 636 | | | — | | | — | | | 636 | | | Balance, December 31, 2020 | | Balance, December 31, 2020 | 138,632 | | | $ | 1,386 | | | $ | 4,061 | | | $ | 2,623 | | | $ | 0 | | | $ | 8,070 | |
See Combined Notes to Consolidated Financial Statements
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements
Index of Combined Notes to Consolidated Financial Statements The Combined Notes to Consolidated Financial Statements are a combined presentation for DTE Energy and DTE Electric. The following list indicates the Registrant(s) to which each note applies: | | | | | | | | | | | | | | | | Note 1 | | Organization and Basis of Presentation | | DTE Energy and DTE Electric | | Note 2 | | Significant Accounting Policies | | DTE Energy and DTE Electric | | Note 3 | | New Accounting Pronouncements | | DTE Energy and DTE Electric | | Note 4 | | Acquisitions and Dispositions | | DTE Energy | | Note 5 | | Revenue | | DTE Energy and DTE Electric | | Note 6 | | Goodwill | | DTE Energy | | Note 7 | | Property, Plant, and Equipment | | DTE Energy and DTE Electric | | Note 8 | | Jointly-Owned Utility Plant | | DTE Energy and DTE Electric | | Note 9 | | Asset Retirement Obligations | | DTE Energy and DTE Electric | | Note 10 | | Regulatory Matters | | DTE Energy and DTE Electric | | Note 11 | | Income Taxes | | DTE Energy and DTE Electric | | Note 12 | | Earnings Per Share | | DTE Energy | | Note 13 | | Fair Value | | DTE Energy and DTE Electric | | Note 14 | | Financial and Other Derivative Instruments | | DTE Energy and DTE Electric | | Note 15 | | Long-Term Debt | | DTE Energy and DTE Electric | | Note 16 | | Preferred and Preference Securities | | DTE Energy and DTE Electric | | Note 17 | | Short-Term Credit Arrangements and Borrowings | | DTE Energy and DTE Electric | | Note 18 | | Leases | | DTE Energy and DTE Electric | | Note 19 | | Commitments and Contingencies | | DTE Energy and DTE Electric | | Note 20 | | Nuclear Operations | | DTE Energy and DTE Electric | | Note 21 | | Retirement Benefits and Trusteed Assets | | DTE Energy and DTE Electric | | Note 22 | | Stock-Based Compensation | | DTE Energy and DTE Electric | | Note 23 | | Segment and Related Information | | DTE Energy | | Note 24 | | Related Party Transactions | | DTE Energy and DTE Electric | | Note 25 | | Supplementary Quarterly Financial Information (Unaudited) | | DTE Energy and DTE Electric | | | | | | Note 1 | | Organization and Basis of Presentation | | DTE Energy and DTE Electric | Note 2 | | Significant Accounting Policies | | DTE Energy and DTE Electric | Note 3 | | New Accounting Pronouncements | | DTE Energy and DTE Electric | Note 4 | | Acquisitions | | DTE Energy | Note 5 | | Revenue | | DTE Energy and DTE Electric | Note 6 | | Goodwill | | DTE Energy | Note 7 | | Property, Plant, and Equipment | | DTE Energy and DTE Electric | Note 8 | | Jointly-Owned Utility Plant | | DTE Energy and DTE Electric | Note 9 | | Asset Retirement Obligations | | DTE Energy and DTE Electric | Note 10 | | Regulatory Matters | | DTE Energy and DTE Electric | Note 11 | | Income Taxes | | DTE Energy and DTE Electric | Note 12 | | Common Stock and Earnings Per Share | | DTE Energy | Note 13 | | Fair Value | | DTE Energy and DTE Electric | Note 14 | | Financial and Other Derivative Instruments | | DTE Energy and DTE Electric | Note 15 | | Long-Term Debt | | DTE Energy and DTE Electric | Note 16 | | Preferred and Preference Securities | | DTE Energy and DTE Electric | Note 17 | | Short-Term Credit Arrangements and Borrowings | | DTE Energy and DTE Electric | Note 18 | | Leases | | DTE Energy and DTE Electric | Note 19 | | Commitments and Contingencies | | DTE Energy and DTE Electric | Note 20 | | Nuclear Operations | | DTE Energy and DTE Electric | Note 21 | | Retirement Benefits and Trusteed Assets | | DTE Energy and DTE Electric | Note 22 | | Stock-Based Compensation | | DTE Energy and DTE Electric | Note 23 | | Segment and Related Information | | DTE Energy | Note 24 | | Related Party Transactions | | DTE Electric | Note 25 | | Supplementary Quarterly Financial Information (Unaudited) | | DTE Energy and DTE Electric |
NOTE 1 — 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.CFTC and CARB.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
Basis of Presentation The accompanying Consolidated Financial Statements of the Registrants are prepared using accounting principles generally accepted in the United States of America. These accounting principles require management to use estimates and assumptions that impact reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results may differ from the Registrants' estimates. The information in these combined notes relates to each of the Registrants as noted in the Index of Combined Notes to Consolidated Financial Statements. However, DTE Electric does not make any representation as to information related solely to DTE Energy or the subsidiaries of DTE Energy other than itself. Certain prior year balances for the Registrants were reclassified to match the current year's Consolidated Financial Statements presentation. Principles of Consolidation The Registrants consolidate all majority-owned subsidiaries and investments in entities in which they have controlling influence. Non-majority owned investments are accounted for using the equity method when the Registrants are able to significantly influence the operating policies of the investee. When the Registrants do not influence the operating policies of an investee, the equity investment is valued at cost method is used.minus any impairments, if applicable. These Consolidated Financial Statements also reflect the Registrants' proportionate interests in certain jointly-owned utility plants. The Registrants eliminate all intercompany balances and transactions. The Registrants evaluate whether an entity is a VIE whenever reconsideration events occur. The Registrants consolidate VIEs for which they are the primary beneficiary. If a Registrant is not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, a Registrant considers all relevant facts and circumstances, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. The Registrants perform ongoing reassessments of all VIEs to determine if the primary beneficiary status has changed. Legal entities within 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 iswas 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-mile25-mile regulated pipeline system located in northern Ohio, which was acquired in September 2019. Refer to Note 4, "Acquisitions," for additional information. 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, as well asand 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 Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
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.contracts, including the transportation services contract with NEXUS. As of December 31, 2019,2020, 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 December 31, 2019,2020, 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 0 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 0 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 19 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 19 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 December 31, 20192020 and 2018.2019. 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: | | | | December 31, 2019 | | December 31, 2018 | | December 31, 2020 | | December 31, 2019 | | | SGG(a) | | Other | | Total | | SGG(a) | | Other | | Total | | SGG(a) | | Other | | Total | | SGG(a) | | Other | | Total | | | (In millions) | | (In millions) | | ASSETS | | | | | | | | | | | | ASSETS | | | Cash and cash equivalents | $ | 16 |
| | $ | 11 |
| | $ | 27 |
| | $ | 25 |
| | $ | 14 |
| | $ | 39 |
| Cash and cash equivalents | $ | 34 | | | $ | 20 | | | $ | 54 | | | $ | 16 | | | $ | 11 | | | $ | 27 | | | Restricted cash | — |
| | — |
| | — |
| | — |
| | 5 |
| | 5 |
| | | | Accounts receivable | 8 |
| | 19 |
| | 27 |
| | 9 |
| | 37 |
| | 46 |
| Accounts receivable | 8 | | | 28 | | | 36 | | | 8 | | | 19 | | | 27 | | | Inventories | — |
| | 74 |
| | 74 |
| | 1 |
| | 92 |
| | 93 |
| Inventories | 0 | | | 107 | | | 107 | | | 0 | | | 74 | | | 74 | | | Property, plant, and equipment, net | 410 |
| | 33 |
| | 443 |
| | 395 |
| | 46 |
| | 441 |
| Property, plant, and equipment, net | 402 | | | 23 | | | 425 | | | 410 | | | 33 | | | 443 | | | Goodwill | 25 |
| | — |
| | 25 |
| | 25 |
| | — |
| | 25 |
| Goodwill | 25 | | | 0 | | | 25 | | | 25 | | | 0 | | | 25 | | | Intangible assets | 542 |
| | — |
| | 542 |
| | 557 |
| | — |
| | 557 |
| Intangible assets | 527 | | | 0 | | | 527 | | | 542 | | | 0 | | | 542 | | | Other current and long-term assets | 2 |
| | — |
| | 2 |
| | 3 |
| | — |
| | 3 |
| Other current and long-term assets | 2 | | | 33 | | | 35 | | | 2 | | | 0 | | | 2 | | | | $ | 1,003 |
| | $ | 137 |
| | $ | 1,140 |
| | $ | 1,015 |
| | $ | 194 |
| | $ | 1,209 |
| | $ | 998 | | | $ | 211 | | | $ | 1,209 | | | $ | 1,003 | | | $ | 137 | | | $ | 1,140 | | | | | | | | | | | | | | | | | | | | | | | | | | | | LIABILITIES | | | | | | | | | | | | LIABILITIES | | | Accounts payable and accrued current liabilities | $ | 2 |
| | $ | 13 |
| | $ | 15 |
| | $ | 3 |
| | $ | 31 |
| | $ | 34 |
| Accounts payable and accrued current liabilities | $ | 0 | | | $ | 22 | | | $ | 22 | | | $ | 2 | | | $ | 13 | | | $ | 15 | | | Short-term borrowings | | Short-term borrowings | 0 | | | 38 | | | 38 | | | 0 | | | 0 | | | 0 | | | | Other current and long-term liabilities | 7 |
| | 7 |
| | 14 |
| | 9 |
| | 10 |
| | 19 |
| Other current and long-term liabilities | 7 | | | 4 | | | 11 | | | 7 | | | 7 | | | 14 | | | | $ | 9 |
| | $ | 20 |
| | $ | 29 |
| | $ | 12 |
| | $ | 41 |
| | $ | 53 |
| | $ | 7 | | | $ | 64 | | | $ | 71 | | | $ | 9 | | | $ | 20 | | | $ | 29 | |
| | (a) | Amounts shown are 100% of SGG's assets and liabilities, of which DTE Energy owns 85% at December 31, 2019 and 55% at December 31, 2018. |
(a)Amounts shown are 100% of SGG's assets and liabilities, of which DTE Energy owns 85% at December 31, 2020 and 2019.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
Amounts for DTE Energy's non-consolidated VIEs are as follows: | | | | | | | | | | | December 31, | | | 2019 | | 2018 | | | (In millions) | | Investments in equity method investees | $ | 1,503 |
| | $ | 1,425 |
| | Notes receivable | $ | 21 |
| | $ | 15 |
| | Future funding commitments | $ | 63 |
| | $ | 55 |
|
| | | | | | | | | | | | | December 31, | | 2020 | | 2019 | | (In millions) | | Investments in equity method investees | $ | 1,507 | | | $ | 1,503 | | | Notes receivable | $ | 47 | | | $ | 21 | | | Future funding commitments | $ | 26 | | | $ | 63 | |
Equity Method Investments Investments in non-consolidated affiliates that are not controlled by the Registrants, but over which they have significant influence, are accounted for using the equity method. Certain of the equity method investees are also considered VIEs and disclosed in the non-consolidated VIEs table above. At December 31, 20192020 and 2018,2019, DTE Energy's share of the underlying equity in the net assets of the investees exceeded the carrying amounts of Investments in equity method investees by $74$80 million and $59$74 million, respectively. The difference is being amortized over the life of the underlying assets. As of December 31, 2020 and 2019, DTE Energy's consolidated retained earnings balance includes undistributed earnings from equity method investments of $109 million and $129 million, respectively. DTE Energy equity method investees are described below: | | | | | | | | | | | | | | | | | | | Investments | | % Owned | | | | Segment | | 2019 | | 2018 | | 2019 | | 2018 | | Description | | | | (In millions) | | | | | | | | Significant Equity Method Investees | | | | | | | | | | | | Gas Storage and Pipelines | | | | | | | | | | | | NEXUS Pipeline | | $ | 1,345 |
| | $ | 1,260 |
| | 50% | | 50% | | 256-mile pipeline to transport Utica and Marcellus shale gas to Ohio, Michigan, and Ontario market centers. Also includes Generation Pipeline, a 23-mile pipeline located in northern Ohio | | Vector Pipeline | | 131 |
| | 123 |
| | 40% | | 40% | | 348-mile pipeline connecting Chicago, Michigan, and Ontario market centers | | Millennium Pipeline | | 209 |
| | 202 |
| | 26% | | 26% | | 263-mile pipeline serving markets in the Northeast | | | | 1,685 |
| | 1,585 |
| | | | | | | | Other Equity Method Investees | | | | | | | | | | | | Other Segments | | 177 |
| | 186 |
| | | | | | | | | | $ | 1,862 |
| | $ | 1,771 |
| | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | Investments | | % Owned | | | | Segment | | 2020 | | 2019 | | 2020 | | 2019 | | Description | | | (In millions) | | | | | | | | Significant Equity Method Investees | | | | | | | | | | | | Gas Storage and Pipelines | | | | | | | | | | | | NEXUS Pipeline | | $ | 1,349 | | | $ | 1,345 | | | 50% | | 50% | | 256-mile pipeline to transport Utica and Marcellus shale gas to Ohio, Michigan, and Ontario market centers. Also includes Generation Pipeline, a 25-mile pipeline located in northern Ohio | | Vector Pipeline | | 134 | | | 131 | | | 40% | | 40% | | 348-mile pipeline connecting Chicago, Michigan, and Ontario market centers | | Millennium Pipeline | | 208 | | | 209 | | | 26% | | 26% | | 263-mile pipeline serving markets in the Northeast | | | 1,691 | | | 1,685 | | | | | | | | | Other Equity Method Investees | | | | | | | | | | | | Other Segments | | 177 | | | 177 | | | | | | | | | | $ | 1,868 | | | $ | 1,862 | | | | | | | |
The balances in Other Equity Method Investees are individually insignificant and are primarily from the Power and Industrial Projects segment. These investments are comprised of projects that deliver energy and utility-type products and services to an industrial customer,customers, sell electricity from renewable energy projects under long-term power purchase agreements, and produce and sell metallurgical coke. For further information by segment, see Note 23 to the Consolidated Financial Statements, "Segment and Related Information." The following table presents summarized financial information of subsidiaries not consolidated and 50 percent or less owned by DTE Energy. The amounts included in the table below represents 100% of the results of continuing operations of such entities accounted for under the equity method of accounting.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
Summarized balance sheet data is as follows: | | | | December 31, | | December 31, | | | 2019 | | 2018 | | 2020 | | 2019 | | | (In millions) | | (In millions) | | Current Assets | $ | 374 |
| | $ | 358 |
| Current Assets | $ | 351 | | | $ | 374 | | | Non-current assets | $ | 5,260 |
| | $ | 5,101 |
| Non-current assets | $ | 5,235 | | | $ | 5,260 | | | Current Liabilities | $ | 414 |
| | $ | 391 |
| Current Liabilities | $ | 319 | | | $ | 414 | | | Non-current liabilities | $ | 698 |
| | $ | 762 |
| Non-current liabilities | $ | 686 | | | $ | 698 | | |
Summarized income statement data is as follows: | | | | | | | | | | | | | | | | | | | December 31, | | 2020 | | 2019 | | 2018 | | (In millions) | | Operating Revenues | $ | 1,227 | | | $ | 1,210 | | | $ | 883 | | | Operating Expenses | $ | 847 | | | $ | 853 | | | $ | 622 | | | | | | | | | Net Income | $ | 395 | | | $ | 313 | | | $ | 365 | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | December 31, | | | 2019 | | 2018 | | 2017 | | | (In millions) | | Operating Revenues | $ | 1,210 |
| | $ | 883 |
| | $ | 756 |
| | Operating Expenses | $ | 853 |
| | $ | 622 |
| | $ | 561 |
| | Net Income | $ | 313 |
| | $ | 365 |
| | $ | 254 |
|
NOTE 2 — SIGNIFICANT ACCOUNTING POLICIES Other Income Other income for the Registrants is recognized for non-operating income such as equity earnings of equity method investees, allowance for equity funds used during construction, contract services, and gains (losses) from trading securities.securities, primarily from those held in DTE Energy's rabbi trust. DTE Energy's Power and Industrial Projects segment also recognizes Other income in connection with the sale of membership interests in reduced emissions fuel facilities to investors. In exchange for the cash received, the investors will receive a portion of the economic attributes of the facilities, including income tax attributes. The transactions are not treated as a sale of membership interests for financial reporting purposes. Other income related to fixed non-refundable cash payments received from investors for which the earnings process is not contingent upon production of refined coal is recognized on a straight-line basis over the non-cancelable contract term as the economic benefit from the ownership of the facility is transferred to investors. Other income related to cash payments that is contingent upon production of refined coal is considered earned and recognized when the contingency regarding the timing and amount of payment is resolved, generally as refined coal is produced and tax credits are generated. The following is a summary of DTE Energy's Other income: | | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | (In millions) | | Income from REF entities | $ | 139 | | | $ | 130 | | | $ | 98 | | | Equity earnings of equity method investees | 132 | | | 111 | | | 132 | | Gains from rabbi trust securities(a) | 28 | | | 37 | | | 6 | | | Contract services | 28 | | | 29 | | | 51 | | | Allowance for equity funds used during construction | 25 | | | 24 | | | 28 | | | Gas Storage and Pipelines post-acquisition settlement | 20 | | | 0 | | | 0 | | | Other | 16 | | | 19 | | | 18 | | | $ | 388 | | | $ | 350 | | | $ | 333 | |
| | | | | | | | | | | | | | | 2019 | | 2018 | | 2017 | | | (In millions) | | Income from REF entities | $ | 130 |
| | $ | 98 |
| | $ | 77 |
| | Equity earnings of equity method investees | 111 |
| | 132 |
| | 102 |
| | Gains from equity securities | 37 |
| | 6 |
| | 26 |
| | Contract services | 29 |
| | 51 |
| | 19 |
| | Allowance for equity funds used during construction | 24 |
| | 28 |
| | 23 |
| | Other | 19 |
| | 18 |
| | 21 |
| | | $ | 350 |
| | $ | 333 |
| | $ | 268 |
|
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
The following is a summary of DTE Electric's Other income: | | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | (In millions) | Gains from rabbi trust securities allocated from DTE Energy(a) | $ | 28 | | | $ | 37 | | | $ | 6 | | | Contract services | 28 | | | 32 | | | 51 | | | Allowance for equity funds used during construction | 23 | | | 22 | | | 19 | | | | | | | | | Other | 8 | | | 16 | | | 7 | | | $ | 87 | | | $ | 107 | | | $ | 83 | |
| | | | | | | | | | | | | | | 2019 | | 2018 | | 2017 | | | (In millions) | | Gains from equity securities allocated from DTE Energy | $ | 37 |
| | $ | 6 |
| | $ | 26 |
| | Contract services | 32 |
| | 51 |
| | 21 |
| | Allowance for equity funds used during construction | 22 |
| | 19 |
| | 18 |
| | Other | 16 |
| | 7 |
| | 12 |
| | | $ | 107 |
| | $ | 83 |
| | $ | 77 |
|
For information on equity earnings of equity method investees by segment, see Note 23 to the Consolidated Financial Statements, "Segment and Related Information." Accounting for ISO Transactions DTE Electric participates in the energy market through MISO. MISO requires that DTE Electric submit hourly day-ahead, real-time, and FTR bids and offers for energy at locations across the MISO region. DTE Electric accounts for MISO transactions on a net hourly basis in each of the day-ahead, real-time, and FTR markets. In any single hour, transactions in each of the MISO energy markets are netted based on MWh to determine if DTE Electric is in a net sale or purchase position. Net purchases are recorded in Fuel, purchased power, and gas — utility and net sales are recorded in Operating Revenues — Utility operations on the Registrants' Consolidated Statements of Operations. The Energy Trading segment participates in the energy markets through various ISOs and RTOs. These markets require that Energy Trading submits hourly day-ahead, real-time bids and offers for energy at locations across each region. Energy Trading submits bids in the annual and monthly auction revenue rights and FTR auctions to the RTOs. Energy Trading accounts for these transactions on a net hourly basis for the day-ahead, real-time, and FTR markets. These transactions are related to trading contracts which, if derivatives, are presented on a net basis in Operating Revenues — Non-utility operations, and if non-derivatives, the realized gains and losses for sales are recorded in Operating Revenues — Non-utility operations and purchases are recorded in Fuel, purchased power, gas, and gasother — non-utility in the DTE Energy Consolidated Statements of Operations. DTE Electric and Energy Trading record accruals for future net purchases adjustments based on historical experience and reconcile accruals to actual costs when invoices are received from MISO and other ISOs and RTOs. Derivatives Energy Trading classifies derivative transactions as revenue or expense based on the intent of the transaction (buy or sell). Revenues are recorded on a gross or net basis within the income statement depending upon whether it represents a non-trading activity or trading activity, respectively. For additional information, refer to Note 14 to the Consolidated Financial Statements, "Financial and Other Derivative Instruments". Changes in Accumulated Other Comprehensive Income (Loss) Comprehensive income (loss) is the change in common shareholders’ equity during a period from transactions and events from non-owner sources, including Net Income. The amounts recorded to Accumulated other comprehensive income (loss) for DTE Energy include changes in benefit obligations, consisting of deferred actuarial losses and prior service costs, unrealized gains and losses from derivatives accounted for as cash flow hedges, DTE Energy's interest in other comprehensive income of equity investees which comprise the net unrealized gains and losses on investments, 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 further discussion regarding changes in Accumulated other comprehensive income (loss), see Note 3 to the Consolidated Financial Statements, "New Accounting Pronouncements." For the yearsyear ended December 31, 2019 and 2018,2020, reclassifications out of Accumulated other comprehensive income (loss) not relating to the adoption of new accounting pronouncements for DTE Energy were not material.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
The following table summarizes the changes in DTE Energy's Accumulated other comprehensive income (loss) by component(a) for the years ended December 31, 20192020 and 2018:2019: | | | | | | | | | | | | | | Net Unrealized Gain (Loss) on Derivatives | | | Benefit Obligations(b) | | Foreign Currency Translation | | Total | | | Net Unrealized Gain (Loss) on Derivatives | | Net Unrealized Loss on Investments | | Benefit Obligations(b) | | Foreign Currency Translation | | Total | | (In millions) | | | (In millions) | | | Balance, December 31, 2017 | $ | (3 | ) | | $ | (2 | ) | | $ | (110 | ) | | $ | (5 | ) | | $ | (120 | ) | | | Other comprehensive loss before reclassifications | (2 | ) | | — |
| | (1 | ) | | (2 | ) | | (5 | ) | | | Amounts reclassified from Accumulated other comprehensive income (loss) | 1 |
| | — |
| | 9 |
| | — |
| | 10 |
| | | Net current-period Other comprehensive income (loss) | (1 | ) | | — |
|
| 8 |
|
| (2 | ) |
| 5 |
| | | Implementation of ASU 2016-01 | (7 | ) | | 2 |
| | — |
| | — |
| | (5 | ) | | | Balance, December 31, 2018 | $ | (11 | ) | | $ | — |
|
| $ | (102 | ) |
| $ | (7 | ) |
| $ | (120 | ) | Balance, December 31, 2018 | $ | (11) | | | | $ | (102) | | | $ | (7) | | | $ | (120) | | | Other comprehensive income (loss) before reclassifications | (14 | ) | | — |
| | (7 | ) | | 1 |
| | (20 | ) | Other comprehensive income (loss) before reclassifications | (14) | | | | (7) | | | 1 | | | (20) | | | Amounts reclassified from Accumulated other comprehensive income (loss) | 2 |
| | — |
| | 15 |
| | — |
| | 17 |
| Amounts reclassified from Accumulated other comprehensive income (loss) | 2 | | | | 15 | | | 0 | | | 17 | | | Net current-period Other comprehensive income (loss) | (12 | ) | | — |
|
| 8 |
|
| 1 |
|
| (3 | ) | Net current-period Other comprehensive income (loss) | (12) | | | | 8 | | | 1 | | | (3) | | | Implementation of ASU 2018-02 | (2 | ) | | — |
| | (23 | ) | | — |
| | (25 | ) | Implementation of ASU 2018-02 | (2) | | | | (23) | | | 0 | | | (25) | | | Balance, December 31, 2019 | $ | (25 | ) | | $ | — |
|
| $ | (117 | ) |
| $ | (6 | ) |
| $ | (148 | ) | Balance, December 31, 2019 | $ | (25) | | | | $ | (117) | | | $ | (6) | | | $ | (148) | | | Other comprehensive income (loss) before reclassifications | | Other comprehensive income (loss) before reclassifications | (3) | | | | (2) | | | 1 | | | (4) | | | Amounts reclassified from Accumulated other comprehensive income (loss) | | Amounts reclassified from Accumulated other comprehensive income (loss) | 5 | | | | 10 | | | 0 | | | 15 | | | Net current-period Other comprehensive income | | Net current-period Other comprehensive income | 2 | | | | 8 | | | 1 | | | 11 | | | Balance, December 31, 2020 | | Balance, December 31, 2020 | $ | (23) | | | | $ | (109) | | | $ | (5) | | | $ | (137) | |
| | (a) | All amounts are net of tax, except for Foreign currency translation. |
| | (b) | The amounts reclassified from Accumulated other comprehensive income (loss) are included in the computation of the net periodic pension and other postretirement benefit costs (see Note 21 to the Consolidated Financial Statements, "Retirement Benefits and Trusteed Assets"). |
(a)All amounts are net of tax, except for Foreign currency translation. (b)The amounts reclassified from Accumulated other comprehensive income (loss) are included in the computation of the net periodic pension and other postretirement benefit costs (see Note 21 to the Consolidated Financial Statements, "Retirement Benefits and Trusteed Assets"). 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 requirements of certain debtcontractual obligations and DTE Energy partnership operating agreements.guarantee performance. Restricted cash designated for interest and principal payments within one year is classified as a Current Asset. Financing Receivables Accounts receivableFinancing receivables are primarily composed of trade receivables, notes receivable, and unbilled revenue. The Registrants' Accounts receivableRegistrant's financing receivables are stated at net realizable value.
DTE Energy unbilled revenues of $944 million and $855 million at December 31, 2020 and 2019, respectively, include $260 million and $263 million of DTE Electric unbilled revenues, respectively, included in Customer Accounts receivable. The Registrants monitor the credit quality of their financing receivables on a regular basis by reviewing credit quality indicators and monitoring for trigger events, such as a credit rating downgrade or bankruptcy. Credit quality indicators include, but are not limited to, ratings by credit agencies where available, collection history, collateral, counterparty financial statements and other internal metrics. Utilizing such data, the Registrants have determined three internal grades of credit quality. Internal grade 1 includes financing receivables for counterparties where credit rating agencies have ranked the counterparty as investment grade. To the extent credit ratings are not available, the Registrants utilize other credit quality indicators to determine the level of risk associated with the financing receivable. Internal grade 1 may include financing receivables for counterparties for which credit rating agencies have ranked the counterparty as below investment grade, however, due to favorable information on other credit quality indicators, the Registrants have determined the risk level to be similar to that of an investment grade counterparty. Internal grade 2 includes financing receivables for counterparties with limited credit information and those with a higher risk profile based upon credit quality indicators. Internal grade 3 reflects financing receivables for which the counterparties have the greatest level of risk, including those in bankruptcy status.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) 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 December 31, 2020. | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | DTE Energy | | DTE Electric | | Year of origination | | 2020 | | 2019 | | 2018 and prior | | Total | | 2020 and prior | | (In millions) | | Notes receivable | | | | | | | | | | | Internal grade 1 | $ | 0 | | | $ | 14 | | | $ | 10 | | | $ | 24 | | | $ | 14 | | | Internal grade 2 | 68 | | | 43 | | | 6 | | | 117 | | | 2 | | Total notes receivable(a) | $ | 68 | | | $ | 57 | | | $ | 16 | | | $ | 141 | | | $ | 16 | | | | | | | | | | | | | Net investment in leases | | | | | | | | | | | Net investment in leases, internal grade 1 | $ | 6 | | | $ | 0 | | | $ | 39 | | | $ | 45 | | | $ | 0 | | | Net investment in leases, internal grade 2 | 131 | | | 0 | | | 1 | | | 132 | | | 0 | | Total net investment in leases(a) | $ | 137 | | | $ | 0 | | | $ | 40 | | | $ | 177 | | | $ | 0 | |
(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 DTE Electric and DTE Gasthe utility entities is generally calculated using thean 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’smanagement'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 DTE Energy'snon-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. DTE Energy unbilled revenues 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 $0.9 billion and $1.0 billion at December 31, 2019 and 2018, respectively, include $263 million and $264 million of DTE Electric unbilled revenues, respectively, included in Customer Accountsthe associated receivable.
Notes Receivable Notes receivable or financing receivables, for DTE Energy are primarily comprised of finance lease receivables and loans andthat are included in Notes receivableReceivable and Other current assets on DTE Energy’sEnergy's Consolidated Statements of Financial Position. Notes receivable or financing receivables, for DTE Electric are primarily comprised of loans.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
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. Cash payments received on nonaccrual status notes receivable, that do not bring the account contractually current, are first applied to contractually owed past due interest, with any remainder applied to principal. Accrual of interest is generally resumed when the note receivable becomes contractually current. 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’scounterparty's ability to pay.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 19, "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.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) The following table presents a roll-forward of the activity for the Registrants' financing receivables credit loss reserves as of December 31, 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 | 100 | | | 3 | | | | | | | 103 | | | 61 | | | | | | | | | | | | | | | Write-offs charged against allowance | (136) | | | (4) | | | | | | | (140) | | | (80) | | | Recoveries of amounts previously written off | 50 | | | 0 | | | | | | | 50 | | | 30 | | | Ending reserve balance, December 31, 2020 | $ | 101 | | | $ | 3 | | | | | | | $ | 104 | | | $ | 57 | |
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 December 31, 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, the Registrants monitorbegan deferring uncollectible expense as Regulatory assets, including $2 million at DTE Gas for the credit ratingsyear ended December 31, 2020. For DTE Electric, deferrals recorded throughout the year were reversed and recorded to expense as a result of the counterparties fromMPSC approval of DTE Electric's one-time accounting application in December 2020. Refer to Note 10 to the Consolidated Financial Statements, "Regulatory Matters," for further information. For DTE Energy, uncollectible expense was $103 million, $111 million, and $140 million for the years ended December 31, 2020, 2019, and 2018, respectively, which they have notes receivable.is primarily comprised of the current period provision for allowance for doubtful accounts adjusted for regulatory deferrals at DTE Gas. For DTE Electric, uncollectible expense was $62 million, $65 million, and $85 million for the years ended December 31, 2020, 2019, and 2018, respectively, which is primarily comprised of the current period provision for allowance for doubtful accounts. There are 0 material amounts of past due financing receivables for the Registrants as of December 31, 2020. Inventories Inventory related to utility operations is generally valued at average cost. Inventory related toand non-utility operations is valued at the lower of cost or net realizable value.value, where cost is generally valued using average cost. DTE Gas' natural gas inventory of $40 million and $48 million as of December 31, 20192020 and 2018, respectively,2019 is determined using the last-in, first-out (LIFO) method. The replacement cost of gas in inventory exceeded the LIFO cost by $49$62 million and $113$49 million at December 31, 20192020 and 2018,2019, respectively. Property, Retirement and Maintenance, and Depreciation and Amortization Property is stated at cost and includes construction-related labor, materials, overheads, and AFUDC for utility property. The cost of utility properties retired is charged to accumulated depreciation. Expenditures for maintenance and repairs are charged to expense when incurred. Utility property at DTE Electric and DTE Gas is depreciated over its estimated useful life using straight-line rates approved by the MPSC. DTE Energy's non-utility property is depreciated over its estimated useful life using the straight-line method. Depreciation and amortization expense also includes the amortization of certain regulatory assets for the Registrants. The cost of nuclear fuel is capitalized. The amortization of nuclear fuel is included within Fuel, purchased power, and gas — utility in the DTE Energy Consolidated Statements of Operations, and Fuel and purchased power in the DTE Electric Consolidated Statements of Operations, and is recorded using the units-of-production method. See Note 7 to the Consolidated Financial Statements, "Property, Plant, and Equipment."
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) Long-Lived Assets Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of an asset may not be recoverable. If the carrying amount of the asset exceeds the expected undiscounted future cash flows generated by the asset, an impairment loss is recognized resulting in the asset being written down to its estimated fair value. Assets to be disposed of are reported at the lower of the carrying amount or fair value, less costs to sell.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
Intangible Assets The Registrants have certain Intangible assets as shown below: | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | December 31, 2019 | | December 31, 2018 | | | Useful Lives | | Gross Carrying Value | | Accumulated Amortization | | Net Carrying Value | | Gross Carrying Value | | Accumulated Amortization | | Net Carrying Value | | | | | (In millions) | | Intangible assets subject to amortization | | | | | | | | | | | | | | Customer relationships | 25 to 40 years(a) | | $ | 2,252 |
| | $ | (66 | ) | | $ | 2,186 |
| | $ | 779 |
| | $ | (44 | ) | | $ | 735 |
| | Contract intangibles | 6 to 26 years | | 268 |
| | (76 | ) | | 192 |
| | 159 |
| | (66 | ) | | 93 |
| | | | | 2,520 |
| | (142 | ) | | 2,378 |
| | 938 |
| | (110 | ) | | 828 |
| | | | | | | | | | | | | | | | | DTE Electric renewable energy credits | (b) | | 15 |
| | — |
| | 15 |
| | 20 |
| | — |
| | 20 |
| | DTE Electric emission allowances | (b) | | — |
| | — |
| | — |
| | 1 |
| | — |
| | 1 |
| | DTE Electric Long-term intangible assets | | 15 |
| | — |
| | 15 |
| | 21 |
| | — |
| | 21 |
| | | | | | | | | | | | | | | | | DTE Energy Long-term intangible assets | | $ | 2,535 |
| | $ | (142 | ) | | $ | 2,393 |
| | $ | 959 |
| | $ | (110 | ) | | $ | 849 |
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | December 31, 2020 | | December 31, 2019 | | Useful Lives | | Gross Carrying Value | | Accumulated Amortization | | Net Carrying Value | | Gross Carrying Value | | Accumulated Amortization | | Net Carrying Value | | | | (In millions) | | Intangible assets subject to amortization | | | | | | | | | | | | | | Customer relationships | 25 to 40 years(a) | | $ | 2,252 | | | $ | (121) | | | $ | 2,131 | | | $ | 2,252 | | | $ | (66) | | | $ | 2,186 | | | Contract intangibles | 6 to 26 years | | 289 | | | (92) | | | 197 | | | 268 | | | (76) | | | 192 | | | | | 2,541 | | | (213) | | | 2,328 | | | 2,520 | | | (142) | | | 2,378 | | | | | | | | | | | | | | | | | DTE Electric renewable energy credits | (b) | | 8 | | | — | | | 8 | | | 15 | | | — | | | 15 | | | | | | | | | | | | | | | | | DTE Electric zonal resource credits | (c) | | 3 | | | — | | | 3 | | | 0 | | | — | | | 0 | | | DTE Electric Long-term intangible assets | | 11 | | | — | | | 11 | | | 15 | | | — | | | 15 | | | | | | | | | | | | | | | | | DTE Energy Long-term intangible assets | | $ | 2,552 | | | $ | (213) | | | $ | 2,339 | | | $ | 2,535 | | | $ | (142) | | | $ | 2,393 | |
| | (a) | The useful lives of the customer relationship intangible assets are based on the number of years in which the assets are expected to economically contribute to the business. The expected economic benefit incorporates existing customer contracts and expected renewal rates based on the estimated volume and production lives of gas resources in the region. |
| | (b) | Emission allowances and renewable energy credits are charged to expense, using average cost, as the allowances and credits are consumed in the operation of the business. |
(a)The useful lives of the customer relationship intangible assets are based on the number of years in which the assets are expected to economically contribute to the business. The expected economic benefit incorporates existing customer contracts and expected renewal rates based on the estimated volume and production lives of gas resources in the region. (b)Renewable energy credits are charged to expense, using average cost, as the credits are consumed in the operation of the business. (c)Zonal resource credits are amortized on a straight-line basis over the period that they are in effect. The following table summarizes DTE Energy's estimated customer relationship and contract intangible amortization expense expected to be recognized during each year through 2024:2025: | | | | | | | | | | | | | | | | | | | | | | | 2020 | | 2021 | | 2022 | | 2023 | | 2024 | | | (In millions) | | Estimated amortization expense | $ | 82 |
| | $ | 86 |
| | $ | 86 |
| | $ | 86 |
| | $ | 86 |
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | 2021 | | 2022 | | 2023 | | 2024 | | 2025 | | (In millions) | | Estimated amortization expense | $ | 73 | | | $ | 73 | | | $ | 73 | | | $ | 73 | | | $ | 73 | |
DTE Energy amortizes customer relationship and contract intangible assets on a straight-line basis over the expected period of benefit. DTE Energy's Intangible assets amortization expense was $71 million in 2020, $33 million in 2019, and $27 million in 2018, and $29 million in 2017.2018. Excise and Sales Taxes The Registrants record the billing of excise and sales taxes as a receivable with an offsetting payable to the applicable taxing authority, with 0 net impact on the Registrants’ Consolidated Statements of Operations. Deferred Debt Costs The costs related to the issuance of long-term debt are deferred and amortized over the life of each debt issue. The deferred amounts are included as a direct deduction from the carrying amount of each debt issue in Mortgage bonds, notes, and other and Junior subordinated debentures on DTE Energy's Consolidated Statements of Financial Position and in Mortgage bonds, notes, and other on DTE Electric's Consolidated Statements of Financial Position. In accordance with MPSC regulations applicable to DTE Energy’s electric and gas utilities, the unamortized discount, premium, and expense related to utility debt redeemed with a refinancing are amortized over the life of the replacement issue. Discount, premium, and expense on early redemptions of debt associated with DTE Energy's non-utility operations are charged to earnings.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
Investments in Debt and Equity Securities The Registrants generally record investments in debt and equity securities at market value with unrealized gains or losses included in earnings. Changes in the fair value of Fermi 2 nuclear decommissioning investments are recorded as adjustments to Regulatory assets or liabilities, due to a recovery mechanism from customers. The Registrants' equity investments are reviewed for impairment each reporting period. If the assessment indicates that an impairment exists, a loss is recognized resulting in the equity investment being written down to its estimated fair value. See Note 13 of the Consolidated Financial Statements, "Fair Value." DTE Energy Foundation DTE Energy's contributions to the DTE Energy Foundation were $20 million and $22 million for the years ended December 31, 2020 and December 31, 2018, respectively. There were 0 charitable contributions made by DTE Energy to the DTE Energy Foundation for the year ended December 31, 2019. DTE Energy's charitable contributions to the DTE Energy Foundation were $22 million and $43 million for the years ended December 31, 2018 and 2017, respectively. The DTE Energy Foundation is a non-consolidated not-for-profit private foundation, the purpose of which is to contribute to and assist charitable organizations. Other Accounting Policies See the following notes for other accounting policies impacting the Registrants’ Consolidated Financial Statements: | | | | | | | | | | Note | | Title | | 5 | | Revenue | 97 | | Property, Plant, and Equipment | | 9 | | Asset Retirement Obligations | | 10 | | Regulatory Matters | | 11 | | Income Taxes | | 13 | | Fair Value | | 14 | | Financial and Other Derivative Instruments | | 18 | | Leases | | 21 | | Retirement Benefits and Trusteed Assets | | 22 | | Stock-Based Compensation |
NOTE 3 — NEW ACCOUNTING PRONOUNCEMENTS Recently Adopted Pronouncements In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842), as amended. This guidance requires a lessee to account for leases as finance or operating leases and disclose key information about leasing arrangements. Both types of leases will result in the lessee recognizing a right-of-use asset and a corresponding lease liability on its balance sheet, with differing methodology for income statement recognition, depending on the lease classification. The Registrants adopted the standard on January 1, 2019 using the prospective approach. The standard provides a number of transition practical expedients of which the Registrants elected the package of three expedients that must be taken together, allowing entities to not reassess whether an agreement is a lease, to carryforward the existing lease classification, and to not reassess initial direct costs associated with existing leases; but did not elect to apply hindsight in determining lease term and impairment of the right-to-use assets. The Registrants also elected to not evaluate land easements under the new guidance at adoption if they were not previously accounted for as leases. These practical expedients apply to leases that commenced prior to January 1, 2019. At adoption of the new standard, the Registrants recognized on the Consolidated Statements of Financial Position, right-of-use assets and lease liabilities for certain operating leases of approximately $137 million and $130 million, respectively, for DTE Energy and approximately $74 million and $67 million, respectively, for DTE Electric as of January 1, 2019. The right-of-use lease assets include $9 million of prepaid lease costs that have been reclassified from Other assets, current and noncurrent, and $2 million of deferred lease costs that have been reclassified from Other liabilities, current and noncurrent, for the Registrants. The adoption of the ASU did not have a significant impact on the Registrants' Consolidated Statements of Operations but required additional disclosures for leases. See Note 18 to the Consolidated Financial Statements, "Leases."
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
In February 2018, the FASB issued ASU No. 2018-02, Income Statement — Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income. The amendments in this update allow a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the TCJA. The amendments in this update also require entities to disclose their accounting policy for releasing income tax effects from accumulated other comprehensive income. The Registrants adopted the standard effective January 1, 2019. Upon adoption, DTE Energy reclassified $25 million of income tax effects from Accumulated other comprehensive income (loss) to Retained Earnings.
Recently Issued 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 replacehave replaced the previous incurred loss impairment methodology in current generally accepted accounting principles 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 currentprevious generally accepted accounting principles. Entities willmust 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 is effectivedid 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 January 2017, the FASB issued ASU No. 2017-04, Intangibles - Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment. The guidance removes Step 2 of the Registrants beginning after December 15, 2019, and interim periods therein.goodwill impairment test, which requires a hypothetical purchase price allocation to determine the amount of goodwill impairment. Under the ASU, a goodwill impairment will be the amount by which a reporting unit's carrying value exceeds its fair value, not to exceed the carrying amount of goodwill. The Registrants will adoptadopted the ASU effective January 1, 2020. The adoption of the ASU did not have an impact on its effective date. The Registrants are currently assessing the impact of this standard on theirRegistrants' Consolidated Financial Statements.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) 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 is effective for the Registrants for fiscal years beginning after December 15, 2019, and interim periods therein.January 1, 2020. The Registrants will adopthave updated Note 13 to the ASU on its effective date. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements. In August 2018, the FASB issued ASU No. 2018-14, Compensation — Retirement Benefits — Defined Benefit Plans (Subtopic 715-20): Disclosure Framework — ChangesStatements, "Fair Value," to the Disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. The amendments in this update modifyincorporate the disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. The ASU is effective forchanges required by the Registrants for fiscal years ending after December 15, 2020. Early adoption is permitted. The Registrants anticipate adopting the ASU on its effective date. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements.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 isIs 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 ASU isRegistrants adopted the standard effective forJanuary 1, 2020 using the Registrants for fiscal years beginning after December 15, 2019, and interim periods therein. The Registrants will adopt the ASU on its effective date. The ASU may be applied using either a retrospective or prospective approach. The Registrants will applyadoption of the ASU prospectively, and are currently assessingdid not have an impact on the impactRegistrants’ Consolidated Financial Statements. On a prospective basis, costs within the scope of this standardamendment will be accounted for consistent with any underlying service contracts. Capitalized implementation costs will be reflected in Other noncurrent assets on theirthe 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 - General (Subtopic 715-20): Disclosure Framework - Changes to the Disclosure Requirements for Defined Benefit 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 Registrants have updated Note 21 to the Consolidated Financial Statements.Statements, "Retirement Benefits and Trusteed Assets," to incorporate the disclosure changes required by the ASU. 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-making fee is adecision maker or service provider are variable interestinterests and require reporting entities to consider indirect interests held through related parties under common control on a proportional basis. The ASU is effective for the Registrants for fiscal years beginning after December 15, 2019, and interim periods therein. The Registrants will adoptadopted the ASU effective January 1, 2020. The adoption of the ASU did not have a significant impact on its effective date. The Registrants are currently assessing the impact of this standard on theirRegistrants’ 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. Early adoption is permitted.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, as amended. 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.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
NOTE 4 — ACQUISITIONS AND DISPOSITIONS 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 Acquisition Effective September 12, 2019, DTE Sustainable Generation closed on the purchase of an 89 MW of renewable energy projectprojects 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 arewere included in Operation and maintenance in DTE Energy's Consolidated Statements of Operations.Operations for the period incurred. The fair value of consideration provided for the acquisition was approximately $175 million, of which $174 million has been 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 | |
| | | | | | | (In millions) | | Contract intangibles | $ | 109 |
| | Property, plant, and equipment, net | 60 |
| | Working capital | 6 |
| | Total | $ | 175 |
|
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) 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. The acquired projects are non-utility operations and related revenues are classified accordingly as Operating Revenues - Non-utility operations within DTE Energy's Consolidated Statements of Operations and the Electric segment results of operations. Refer to Note 23 to the Consolidated Financial Statements, "Segment and Related Information." Gas Storage and Pipelines Segment Acquisitions Generation Pipeline Acquisition
Effective September 20, 2019, NEXUS closed on the purchase of Generation Pipeline, LLC, a pipeline system regulated by the Public Utilities Commission of Ohio. The 23-mile pipeline system supplies gas to industrial customers in the Toledo, OH area, has existing interconnects with ANR Pipeline Company and Panhandle Eastern Pipeline Company, and is located four miles from NEXUS. Total consideration paid for the acquired entity was approximately $163 million, of which DTE Energy's portion was 50%. DTE Energy accounts for its ownership interest in NEXUS under the equity method, which now includes equity in earnings related to Generation Pipeline, LLC.
Blue Union and LEAP 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 acquired assets are part of DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
The fair value of the consideration provided for the entities acquired was $2.74 billion and includesincluded $2.36 billion paid in cash and an estimated $378$380 million of contingent consideration to be paid upon completion of athe LEAP gathering pipeline in the second half of 2020. The contingent payment will range from $0 million to $385 million, with no payment due until the pipeline is completed. As of December 31, 2019, thepipeline. A liability for the contingent consideration payment was recorded upon acquisition and adjusted each period for accretion. Refer to the Acquisition related accretion expense of $1 million is included in a separatedeferred payment line in the Consolidated Statements of Financial Position. Position for the liability balance for the respective reporting periods. Accretion expense of $5 million and $1 million was recorded for the years ended December 31, 2020 and 2019, 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 2 equal installments. The acquisition was financed through the issuance of Equity Units, common stock, and Senior Notes. See Notes 12 andNote 15 to the Consolidated Financial Statements, "Common Stock and Earnings Per Share" and "Long-Term Debt," respectively, for more information. 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 (i) final working capital settlement adjustments, and (ii) resolution of any indemnification claims that might be deducted from the $100 million of cash consideration paid and held in escrow. As such, DTE Energy cannot estimate the potential amount of the additional revisions to the purchase price allocation in 2020. The excess purchase price over the fair value of net assets acquired totaled approximately $171 million and was classified as goodwill. The factors contributing to the recognition of goodwill arewere 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 deductiblebeing deducted for income tax purposes. December 3, 2020 marked the expiration of the one-year period from the acquisition to revise the fair value of assets acquired and liabilities assumed. As a result of purchase accounting adjustments through December 3, 2020, approximately $2 million of additional goodwill was recognized. The preliminarypurchase price is no longer subject to resolution of any indemnification claims and all cash consideration paid and held in escrow has been released.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) The final allocation of the purchase price iswas 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 preliminaryfinal 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 | 171 |
| | Customer relationship intangibles | 1,473 |
| | Other current assets | 1 |
| | | $ | 2,773 |
| | Liabilities | | | Accounts payable | $ | 26 |
| | Acquisition related deferred payment | 378 |
| | Other current liabilities | 2 |
| | Asset retirement obligations | 9 |
| | | $ | 415 |
| | Total cash consideration | $ | 2,358 |
|
| | | | | | | (In millions) | | Assets | | | Cash | $ | 62 | | | Accounts receivable | 31 | | | | | Property, plant, and equipment, net | 1,034 | | | Goodwill | 173 | | | 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-averageweighted average amortization life of 13 years and expected renewal rates, based on the estimated volume and production lives of gas resources in the region. See Note 2 to the Consolidated Financial Statements, "Significant Accounting Policies," for more information.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
DTE Energy has incurred $18 million of direct transaction costs for the year ended December 31, 2019. These costs arewere primarily related to advisory fees and are included in Operation and maintenance in DTE Energy's 2019 Consolidated Statements of Operations. Additionally, DTE Energy has incurred $49 million of issuance costs related to the acquisition financing, of which $10 million arewere included in Mortgage bonds, notes, and other, and $39 million arewere included in Common Stock in DTE Energy's Consolidated Statements of Financial Position.
DTE Energy's 2019 Consolidated Statements of Operations includeincluded 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 haswas not been presented for DTE Energy because the effects of the acquisition were not material to the Consolidated Statements of Operations.
On 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 ("DT Midstream"). The planned separation transaction is intended to be a tax-free spin-off for DTE Energy and its 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.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) NOTE 5 — REVENUE Significant Accounting Policy Upon the adoption of Topic 606, revenue is measured based upon the consideration specified in a contract with a customer at the time when performance obligations are satisfied. Under Topic 606, a performance obligation is a promise in a contract to transfer a distinct good or service or a series of distinct goods or services to the customer. The Registrants recognize revenue when performance obligations are satisfied by transferring control over a product or service to a customer. The Registrants have determined control to be transferred when the product is delivered or the service is provided to the customer. For the years ended December 31, 2020, 2019, and 2018, recognition of revenue for the Registrants subsequent to the adoption of Topic 606 is substantially similar in amount and approach to that prior to adoption. Rates for DTE Electric and DTE Gas include provisions to adjust billings for fluctuations in fuel and purchased power costs, cost of natural gas, and certain other costs. Revenues are adjusted for differences between actual costs subject to reconciliation and the amounts billed in current rates. Under or over recovered revenues related to these cost recovery mechanisms are included in Regulatory assets or liabilities on the Registrants' Consolidated Statements of Financial Position and are recovered or returned to customers through adjustments to the billing factors. For discussion of derivative contracts, see Note 14 to the Consolidated Financial Statements, "Financial and Other Derivative Instruments." Disaggregation of Revenue The following is a summary of revenues disaggregated by segment for DTE Energy: | | | | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | | | (In millions) | Electric(a) | | | | | | | | | Residential | $ | 2,825 | | | $ | 2,427 | | | $ | 2,494 | | | | | Commercial | 1,739 | | | 1,795 | | | 1,794 | | | | | Industrial | 592 | | | 659 | | | 690 | | | | Other(b) | 364 | | | 348 | | | 320 | | | | Total Electric operating revenues(c) | $ | 5,520 | | | $ | 5,229 | | | $ | 5,298 | | | | | | | | | | | | | Gas | | | | | | | | | Gas sales | $ | 971 | | | $ | 1,043 | | | $ | 1,055 | | | | | End User Transportation | 218 | | | 219 | | | 232 | | | | | Intermediate Transportation | 79 | | | 78 | | | 58 | | | | Other(b) | 146 | | | 142 | | | 91 | | | | Total Gas operating revenues(d) | $ | 1,414 | | | $ | 1,482 | | | $ | 1,436 | | | | | | | | | | | | | Other segment operating revenues | | | | | | | | Gas Storage and Pipelines(e) | $ | 754 | | | $ | 501 | | | $ | 485 | | | | Power and Industrial Projects(f) | $ | 1,224 | | | $ | 1,560 | | | $ | 2,204 | | | | Energy Trading(g) | $ | 3,863 | | | $ | 4,610 | | | $ | 5,557 | | | |
(a)Revenues generally represent those of DTE Electric, except $14 million and $5 million of Other revenues related to DTE Sustainable Generation for the years ended December 31, 2020 and 2019, respectively. (b)Includes revenue adjustments related to various regulatory mechanisms. (c)Includes $26 million, $22 million, and $21 million under Alternative Revenue Programs and $22 million, $19 million, and $20 million of other revenues, which are both outside the scope of Topic 606, for the years ended December 31, 2020, 2019, and 2018, respectively. (d)Includes $10 million, $8 million, and $2 million under Alternative Revenue Programs and $8 million, $7 million, and $7 million of other revenues, which are both outside the scope of Topic 606, for the years ended December 31, 2020, 2019, and 2018, respectively. (e)Includes revenues outside the scope of Topic 606 primarily related to $9 million of contracts accounted for as leases for each of the years ended December 31, 2020 and 2019. (f)Includes revenues outside the scope of Topic 606 primarily related to $99 million, $121 million, and $125 million of contracts accounted for as leases for the years ended December 31, 2020, 2019, and 2018, respectively. (g)Includes revenues outside the scope of Topic 606 primarily related to $2.7 billion, $3.4 billion, and $4.5 billion of derivatives for the years ended December 31, 2020, 2019, and 2018, respectively.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
Disaggregation of Revenue
The following is a summary of revenues disaggregated by segment for DTE Energy:
| | | | | | | | | | | 2019 | | 2018 | | | (In millions) | Electric(a) | | | | | Residential | $ | 2,427 |
| | $ | 2,494 |
| | Commercial | 1,795 |
| | 1,794 |
| | Industrial | 659 |
| | 690 |
| Other(b) | 348 |
| | 320 |
| Total Electric operating revenues(c) | $ | 5,229 |
| | $ | 5,298 |
| | | | | | | Gas | | | | | Gas sales | $ | 1,043 |
| | $ | 1,055 |
| | End User Transportation | 219 |
| | 232 |
| | Intermediate Transportation | 78 |
| | 58 |
| Other(b) | 142 |
| | 91 |
| Total Gas operating revenues(d) | $ | 1,482 |
| | $ | 1,436 |
| | | | | | | Other segment operating revenues | | | | Gas Storage and Pipelines(e) | $ | 501 |
| | $ | 485 |
| Power and Industrial Projects(f) | $ | 1,560 |
| | $ | 2,204 |
| Energy Trading(g) | $ | 4,610 |
| | $ | 5,557 |
|
| | (a) | Revenues under the Electric segment generally represent those of DTE Electric. |
| | (b) | Includes revenue adjustments related to various regulatory mechanisms. |
| | (c) | Includes $22 million under Alternative Revenue Programs and $19 million of other revenues, which are both outside the scope of Topic 606 for the year ended December 31, 2019 and includes $21 million under Alternative Revenue Programs and $20 million of other revenues, which are both outside the scope of Topic 606 for the year ended December 31, 2018. |
| | (d) | Includes $8 million under Alternative Revenue Programs and $7 million of other revenues, which are both outside the scope of Topic 606 for the year ended December 31, 2019 and includes $2 million under Alternative Revenue Programs and $7 million of other revenues, which are both outside the scope of Topic 606 for the year ended December 31, 2018. |
| | (e) | Includes revenues outside the scope of Topic 606 primarily related to $9 million of contracts accounted for as leases for the year ended December 31, 2019.
|
| | (f) | Includes revenues outside the scope of Topic 606 primarily related to $121 million and $125 million of contracts accounted for as leases for the years ended December 31, 2019 and December 31, 2018, respectively. |
| | (g) | Includes revenues outside the scope of Topic 606 primarily related to $3.4 billion and $4.5 billion of derivatives for the years ended December 31, 2019 and December 31, 2018, respectively. |
Nature of Goods and Services The following is a description of principal activities, separated by reportable segments, from which DTE Energy generates revenue. For more detailed information about reportable segments, see Note 23 to the Consolidated Financial Statements, “Segment and Related Information.” The Registrants have contracts with customers which may contain more than one performance obligation. When more than one performance obligation exists in a contract, the consideration under the contract is allocated to the performance obligations based on the relative standalone selling price. DTE Energy generally determines standalone selling prices based on the prices charged to customers or the use of the adjusted market assessment approach. The adjusted market assessment approach involves the evaluation of the market in which DTE Energy sells goods or services and estimating the price that a customer in that market would be willing to pay. Under Topic 606, when a customer simultaneously receives and consumes the product or service provided, revenue is considered to be recognized over time. Alternatively, if it is determined that the criteria for recognition of revenue over time is not met, the revenue is considered to be recognized at a point in time.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
Electric Electric consists principally of DTE Electric. Electric revenues are primarily comprised of the supply and delivery of electricity, and related capacity. Revenues are primarily associated with cancelablecancellable contracts, with the exception of certain long-term contracts with commercial and industrial customers. Revenues, including estimated unbilled amounts, are generally recognized over time based upon volumes delivered or through the passage of time ratably based upon providing a stand-ready service. The Registrants have determined that the above methods represent a faithful depiction of the transfer of control to the customer. Unbilled revenues are typically determined utilizing approved tariff rates and estimated meter volumes. Estimated unbilled amounts recognized in revenue are subject to adjustment in the following reporting period as actual volumes by customer class are known. Revenues are typically subject to tariff rates based upon customer class and type of service and are billed and received monthly. Tariff rates are determined by the MPSC on a per unit or monthly basis. Gas Gas consists principally of DTE Gas. Gas revenues are primarily comprised of the supply and delivery of natural gas, and other services including storage, transportation, and appliance maintenance. Revenues are primarily associated with cancelablecancellable contracts with the exception of certain long-term contracts with commercial and industrial customers. Revenues, including estimated unbilled amounts, are generally recognized over time based upon volumes delivered or through the passage of time ratably based upon providing a stand-ready service. DTE Energy has determined that the above methods represent a faithful depiction of the transfer of control to the customer. Unbilled revenues are typically determined using both estimated meter volumes and estimated usage based upon the number of unbilled days and historical temperatures. Estimated unbilled amounts recognized in revenue are subject to adjustment in the following reporting period as actual volumes by customer class and service type are known. Revenues are typically subject to tariff rates or other rates subject to regulatory oversight and are billed and received monthly. Tariff rates are determined by the MPSC on a per unit or monthly basis. Gas Storage and Pipelines Gas Storage and Pipelines revenues generally consist of services related to the gathering, transportation, and storage of natural gas. Contracts are primarily long-term in nature. Revenues, including estimated unbilled amounts, are generally recognized over time based upon services provided or through the passage of time ratably based upon providing a stand-ready service. Unbilled amounts are generally determined using estimated volumes based on preliminary meter data and contracted rates and typically result in minor adjustments in the following reporting period. DTE Energy has determined that the above methods represent a faithful depiction of the transfer of control to the customer. Revenues are typically billed and received monthly. Pricing for such revenues may consist of demand rates, commodity rates, transportation rates, and other associated fees. Consideration may consist of both fixed and variable components.components and may be subject to minimum volume commitments. Generally, uncertainties in the variable consideration components are resolved and revenues are known at the time of recognition.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) Power and Industrial Projects Power and Industrial Projects revenues include contracts accounted for as leases which are outside of the scope of Topic 606. For performance obligations within the scope of Topic 606, the timing of revenue recognition is dependent upon when control over the associated product or service is transferred. Revenues at Power and Industrial Projects, within the scope of Topic 606, generally consist of sales of refined coal, coal, blast furnace coke, coke oven gas, electricity, equipment maintenance services, and other energy related products and services. Revenues, including estimated unbilled amounts, for the sale of blast furnace coke are generally recognized at a point in time when the product is delivered, which represents the transfer of control to the customer. Other revenues are generally recognized over time based upon services provided or through the passage of time ratably based upon providing a stand-ready service. DTE Energy has determined that the above methods represent a faithful depiction of the transfer of control to the customer. Market based pricing structures exist in such contracts including adjustments for consumer price or other indices. Consideration may consist of both fixed and variable components. Generally, uncertainties in the variable consideration components are resolved and revenues are known at the time of recognition. Billing terms vary and are generally monthly with payment terms typically within 30 days following billing. Energy Trading Energy Trading revenues consist primarily of derivative contracts outside of the scope of Topic 606. For performance obligations within the scope of Topic 606, the timing of revenue recognition is dependent upon when control over the associated product or service is transferred.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
Revenues, including estimated unbilled amounts, within the scope of Topic 606 arising from the sale of natural gas, electricity, power capacity, and other energy related products are generally recognized over time based upon volumes delivered or through the passage of time ratably based upon providing a stand-ready service. DTE Energy has determined that the above methods represent a faithful depiction of the transfer of control to the customer. Revenues are known at the time of recognition. Payment for the aforementioned revenues is generally due from customers in the month following delivery. Revenues associated with RECs are recognized at a point in time when control of the RECs are transferred to the customer which is deemed to be when the subject RECs are entered for transfer to the customer in the applicable regulatory tracking system. Revenues associated with RECs under a wholesale full requirements power contract are deferred until control has been transferred. The deferred revenues represent a contract liability for which payment has been received and the amounts have been estimated using the adjusted market assessment approach. With the exception of RECs, generally all other performance obligations associated with wholesale full requirements power contracts are satisfied over time in conjunction with the delivery of power. At the time power is delivered, DTE Energy may not have control over the RECs as the RECs are not self-generated and may not yet have been procured resulting in deferred revenues. Deferred Revenue The following is a summary of deferred revenue activity: | | | | | | | DTE Energy | | | (In millions) | | Beginning Balance, January 1, 2019 | $ | 74 |
| | Increases due to cash received or receivable, excluding amounts recognized as revenue during the period | 51 |
| | Revenue recognized that was included in the deferred revenue balance at the beginning of the period | (50 | ) | | Ending Balance, December 31, 2019 | $ | 75 |
|
| | | | | | | 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 | 55 | | | Revenue recognized that was included in the deferred revenue balance at the beginning of the period | (43) | | | Ending Balance, December 31, 2020 | $ | 87 | |
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.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) 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 | $ | 43 |
| | 2021 | 6 |
| | 2022 | 7 |
| | 2023 | 6 |
| | 2024 | 3 |
| | 2025 and thereafter | 10 |
| | | $ | 75 |
|
| | | | | | | DTE Energy | | (In millions) | | 2021 | $ | 59 | | | 2022 | 7 | | | 2023 | 3 | | | 2024 | 3 | | | 2025 | 7 | | | 2026 and thereafter | 8 | | | $ | 87 | |
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.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
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 cancelablecancellable 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) | | 2021 | $ | 285 | | | $ | 8 | | | 2022 | 323 | | | 7 | | | 2023 | 263 | | | 7 | | | 2024 | 158 | | | 7 | | | 2025 | 113 | | | 1 | | | 2026 and thereafter | 501 | | | 0 | | | $ | 1,643 | | | $ | 30 | |
| | | | | | | | | | | DTE Energy | | DTE Electric | | | (In millions) | | 2020 | $ | 253 |
| | $ | 8 |
| | 2021 | 292 |
| | 8 |
| | 2022 | 232 |
| | 7 |
| | 2023 | 164 |
| | 7 |
| | 2024 | 126 |
| | 7 |
| | 2025 and thereafter | 538 |
| | — |
| | | $ | 1,605 |
| | $ | 37 |
|
Other Matters
The following table represents expenses recognized for estimated uncollectible accounts receivable:
| | | | | | | | | | | December 31, | | | 2019 | | 2018 | | | (In millions) | | DTE Energy | $ | 111 |
| | $ | 140 |
| | DTE Electric | $ | 65 |
| | $ | 85 |
|
NOTE 6 — GOODWILL DTE Energy has goodwill resulting from business combinations. The following is the summary of change in the carrying amount of goodwill for the years ended December 31: | | | | | | | | | | | | | 2020 | | 2019 | | (In millions) | | Balance as of January 1 | $ | 2,464 | | | $ | 2,293 | | | Goodwill attributable to Gas Storage and Pipelines 2019 acquisition of Blue Union and LEAP | 2 | | | 171 | | | Balance at December 31 | $ | 2,466 | | | $ | 2,464 | |
| | | | | | | | | | | 2019 | | 2018 | | | (In millions) | | Balance as of January 1 | $ | 2,293 |
| | $ | 2,293 |
| | Goodwill attributable to Gas Storage and Pipelines 2019 acquisition of Blue Union and LEAP | 171 |
| | — |
| | Balance at December 31 | $ | 2,464 |
| | $ | 2,293 |
|
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
NOTE 7 — PROPERTY, PLANT, AND EQUIPMENT The following is a summary of Property, plant, and equipment by classification as of December 31: | | | | | | | | | | | 2019 | | 2018 | | Property, plant, and equipment | (In millions) | | DTE Electric | | | | | Generation | $ | 12,028 |
| | $ | 11,027 |
| | Distribution | 9,715 |
| | 9,153 |
| | Other | 2,536 |
| | 2,567 |
| | Total DTE Electric | 24,279 |
|
| 22,747 |
| | DTE Gas | | | | | Distribution | 4,164 |
| | 3,823 |
| | Storage | 570 |
| | 548 |
| | Transmission and other | 1,244 |
| | 1,204 |
| | Total DTE Gas | 5,978 |
| | 5,575 |
| | Non-utility and other |
|
| |
|
| | Gas Storage and Pipelines | 3,524 |
| | 2,307 |
| | Power and Industrial Projects | 1,108 |
| | 1,070 |
| | Other | 183 |
| | 111 |
| | Non-utility and other | 4,815 |
| | 3,488 |
| | Total DTE Energy | 35,072 |
| | 31,810 |
| | Accumulated depreciation and amortization | | | | | DTE Electric | | | | | Generation | (3,460 | ) | | (3,609 | ) | | Distribution | (2,553 | ) | | (2,974 | ) | | Other | (693 | ) | | (727 | ) | | Total DTE Electric | (6,706 | ) | | (7,310 | ) | | DTE Gas | | | | | Distribution | (1,334 | ) | | (1,283 | ) | | Storage | (172 | ) | | (165 | ) | | Transmission and other | (409 | ) | | (404 | ) | | Total DTE Gas | (1,915 | ) | | (1,852 | ) | | Non-utility and other |
|
| |
|
| | Gas Storage and Pipelines | (459 | ) | | (390 | ) | | Power and Industrial Projects | (604 | ) | | (546 | ) | | Other | (71 | ) | | (62 | ) | | Non-utility and other | (1,134 | ) | | (998 | ) | | Total DTE Energy | (9,755 | ) | | (10,160 | ) | | Net DTE Energy Property, plant, and equipment | $ | 25,317 |
| | $ | 21,650 |
| | Net DTE Electric Property, plant, and equipment | $ | 17,573 |
| | $ | 15,437 |
|
| | | | | | | | | | | | | 2020 | | 2019 | | Property, plant, and equipment | (In millions) | | DTE Electric | | | | | Zero carbon generation | | | | | Nuclear | $ | 3,295 | | | $ | 3,022 | | | Renewables | 1,817 | | | 1,362 | | | Fossil and other generation | 8,031 | | | 7,644 | | | Distribution | 10,354 | | | 9,715 | | | Other | 2,674 | | | 2,536 | | | Total DTE Electric | 26,171 | | | 24,279 | | | DTE Gas | | | | | Distribution | 4,517 | | | 4,164 | | | Storage | 576 | | | 570 | | | Transmission and other | 1,341 | | | 1,244 | | | Total DTE Gas | 6,434 | | | 5,978 | | | Non-utility and other | | | | | Gas Storage and Pipelines | 3,981 | | | 3,524 | | | Power and Industrial Projects | 1,194 | | | 1,108 | | | Other | 217 | | | 183 | | | Non-utility and other | 5,392 | | | 4,815 | | | Total DTE Energy | 37,997 | | | 35,072 | | | Accumulated depreciation and amortization | | | | | DTE Electric | | | | | Zero carbon generation | | | | | Nuclear | (373) | | | (344) | | | Renewables | (295) | | | (243) | | | Fossil and other generation | (3,014) | | | (2,873) | | | Distribution | (2,686) | | | (2,553) | | | Other | (682) | | | (693) | | | Total DTE Electric | (7,050) | | | (6,706) | | | DTE Gas | | | | | Distribution | (1,215) | | | (1,334) | | | Storage | (146) | | | (172) | | | Transmission and other | (403) | | | (409) | | | Total DTE Gas | (1,764) | | | (1,915) | | | Non-utility and other | | | | | Gas Storage and Pipelines | (511) | | | (459) | | | Power and Industrial Projects | (619) | | | (604) | | | Other | (84) | | | (71) | | | Non-utility and other | (1,214) | | | (1,134) | | | Total DTE Energy | (10,028) | | | (9,755) | | | Net DTE Energy Property, plant, and equipment | $ | 27,969 | | | $ | 25,317 | | | Net DTE Electric Property, plant, and equipment | $ | 19,121 | | | $ | 17,573 | |
The following is a summary of the Registrants' AFUDC and Capitalized Interest
AFUDC represents the cost of financing construction projects for regulated businesses, including the estimated cost of debt and authorized return-on-equity. The debt component is recorded as a reduction to interest expense and the equity component is recorded as other income. Non-regulated businesses record capitalized for the years ended December 31:interest as a reduction to interest expense. | | | | | | | | | | | | | | | | | | | DTE Energy | | DTE Electric | | | 2019 | | 2018 | | 2019 | | 2018 | | | (In millions) | | Allowance for debt funds used during construction and interest capitalized | $ | 15 |
| | $ | 15 |
| | $ | 10 |
| | $ | 9 |
| | Allowance for equity funds used during construction | 24 |
| | 28 |
| | 22 |
| | 19 |
| | Total | $ | 39 |
| | $ | 43 |
| | $ | 32 |
| | $ | 28 |
|
96
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) The AFUDC and capitalized interest rates were as follows for the years ended December 31: | | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | DTE Electric AFUDC | 5.47 | % | | 5.43 | % | | 5.41 | % | | DTE Gas AFUDC | 5.56 | % | | 5.56 | % | | 5.71 | % | | Non-regulated businesses capitalized interest | 3.90 | % | | 4.00 | % | | 4.00 | % |
The following is a summary of AFUDC and interest capitalized for the years ended December 31: | | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | DTE Energy | (In millions) | | Allowance for debt funds used during construction and interest capitalized | $ | 22 | | | $ | 15 | | | $ | 15 | | | Allowance for equity funds used during construction | 25 | | | 24 | | | 28 | | | Total | $ | 47 | | | $ | 39 | | | $ | 43 | |
| | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | DTE Electric | (In millions) | | Allowance for debt funds used during construction | $ | 10 | | | $ | 10 | | | $ | 9 | | | Allowance for equity funds used during construction | 23 | | | 22 | | | 19 | | | Total | $ | 33 | | | $ | 32 | | | $ | 28 | |
Depreciation and Amortization The composite depreciation rate for DTE Electric was approximately 4.0%4.2%, 3.7%4.0%, and 3.6%3.7% in 2020, 2019 2018 and 2017,2018, respectively. The composite depreciation rate for DTE Gas was 2.7%2.8% for all periods. The average estimated useful life for each major class of utility Property, plant, and equipment as of December 31, 20192020 follows: | | | | | | | | | | | Estimated Useful Lives in Years | | Utility | | Generation | | Distribution | | Storage | | DTE Electric | | 34 | | 38 | | N/A | | DTE Gas | | N/A | | 50 | | 56 |
| | | | | | | | | | | | | | | | | | | | | | | Estimated Useful Lives in Years | | Utility | | Generation | | Distribution | | Storage | | DTE Electric | | 32 | | 38 | | N/A | | DTE Gas | | N/A | | 49 | | 58 |
The estimated useful lives for DTE Electric's Other utility assets range from 3 to 80 years, while the estimated useful lives for DTE Gas' Transmission and other utility assets range from 3 to 7080 years. The estimated useful lives for major classes of DTE Energy's non-utility assets and facilities range from 23 to 5570 years. The following is a summary of Depreciation and amortization expense for DTE Energy: | | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | (In millions) | | Property, plant, and equipment | $ | 1,120 | | | $ | 997 | | | $ | 878 | | | Regulatory assets and liabilities | 245 | | | 227 | | | 212 | | | Intangible assets | 71 | | | 33 | | | 27 | | | Other | 7 | | | 6 | | | 7 | | | $ | 1,443 | | | $ | 1,263 | | | $ | 1,124 | |
| | | | | | | | | | | | | | | 2019 | | 2018 | | 2017 | | | (In millions) | | Property, plant, and equipment | $ | 997 |
| | $ | 878 |
| | $ | 829 |
| | Regulatory assets and liabilities | 227 |
| | 212 |
| | 165 |
| | Intangible assets | 33 |
| | 27 |
| | 29 |
| | Other | 6 |
| | 7 |
| | 7 |
| | | $ | 1,263 |
| | $ | 1,124 |
| | $ | 1,030 |
|
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) The following is a summary of Depreciation and amortization expense for DTE Electric: | | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | (In millions) | | Property, plant, and equipment | $ | 831 | | | $ | 748 | | | $ | 652 | | | Regulatory assets and liabilities | 207 | | | 193 | | | 179 | | | | | | | | | Other | 5 | | | 5 | | | 5 | | | $ | 1,043 | | | $ | 946 | | | $ | 836 | |
| | | | | | | | | | | | | | | 2019 | | 2018 | | 2017 | | | (In millions) | | Property, plant, and equipment | $ | 748 |
| | $ | 652 |
| | $ | 615 |
| | Regulatory assets and liabilities | 193 |
| | 179 |
| | 133 |
| | Other | 5 |
| | 5 |
| | 5 |
| | | $ | 946 |
| | $ | 836 |
| | $ | 753 |
|
Capitalized software costs are classified as Property, plant, and equipment and the related amortization is included in accumulated depreciation and amortization on the Registrants' Consolidated Financial Statements. The Registrants capitalize the costs associated with computer software developed or obtained for use in their businesses. The Registrants amortize capitalized software costs on a straight-line basis over the expected period of benefit, ranging from 3 to 15 years for DTE Energy and 3 to 15 years for DTE Electric. The following balances for capitalized software relate to DTE Energy: | | | | | | | | | | | | | | | Year Ended December 31, | | | 2019 | | 2018 | | 2017 | | | (In millions) | | Amortization expense of capitalized software | $ | 123 |
| | $ | 108 |
| | $ | 101 |
| | Gross carrying value of capitalized software | $ | 906 |
| | $ | 905 |
| | | | Accumulated amortization of capitalized software | $ | 520 |
| | $ | 534 |
| | |
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
| | | | | | | | | | | | | | | | | | | Year Ended December 31, | | 2020 | | 2019 | | 2018 | | (In millions) | | Amortization expense of capitalized software | $ | 129 | | | $ | 123 | | | $ | 108 | | | Gross carrying value of capitalized software | $ | 866 | | | $ | 906 | | | | | Accumulated amortization of capitalized software | $ | 432 | | | $ | 520 | | | |
The following balances for capitalized software relate to DTE Electric: | | | | | | | | | | | | | | | | | | | Year Ended December 31, | | 2020 | | 2019 | | 2018 | | (In millions) | | Amortization expense of capitalized software | $ | 118 | | | $ | 112 | | | $ | 101 | | | Gross carrying value of capitalized software | $ | 756 | | | $ | 811 | | | | | Accumulated amortization of capitalized software | $ | 363 | | | $ | 462 | | | |
| | | | | | | | | | | | | | | Year Ended December 31, | | | 2019 | | 2018 | | 2017 | | | (In millions) | | Amortization expense of capitalized software | $ | 112 |
| | $ | 101 |
| | $ | 93 |
| | Gross carrying value of capitalized software | $ | 811 |
| | $ | 799 |
| | | | Accumulated amortization of capitalized software | $ | 462 |
| | $ | 463 |
| | |
NOTE 8 — JOINTLY-OWNED UTILITY PLANT DTE Electric has joint ownership interest in 2 power plants, Belle River and Ludington Hydroelectric Pumped Storage. DTE Electric’s share of direct expenses of the jointly-owned plants are included in Fuel, purchased power, and gas — utility and Operation and maintenance expenses in the DTE Energy Consolidated Statements of Operations and Fuel and purchased power— utility and Operation and maintenance expenses in the DTE Electric Consolidated Statements of Operations. DTE Electric's ownership information of the 2 utility plants as of December 31, 20192020 was as follows: | | | | | | | | | | | Belle River | | Ludington
Hydroelectric
Pumped Storage | | In-service date | 1984-1985 | | 1973 | | Total plant capacity | 1,270 MW | | 2,220 MW | | Ownership interest | 81% | | 49% | | Investment in Property, plant, and equipment (in millions) | $ | 1,903 |
| | $ | 616 |
| | Accumulated depreciation (in millions) | $ | 896 |
| | $ | 193 |
|
| | | | | | | | | | | | | Belle River | | Ludington
Hydroelectric
Pumped Storage | | In-service date | 1984-1985 | | 1973 | | Total plant capacity | 1,270 MW | | 2,220 MW | | Ownership interest | 81% | | 49% | | Investment in Property, plant, and equipment (in millions) | $ | 1,932 | | | $ | 609 | | | Accumulated depreciation (in millions) | $ | 945 | | | $ | 181 | |
Belle River The Michigan Public Power Agency (MPPA) has ownership interests in Belle River Unit No. 1 and other related facilities. The MPPA is entitled to 19% of the total capacity and energy of the plant and is responsible for the same percentage of the plant’s operation, maintenance, and capital improvement costs. Ludington Hydroelectric Pumped Storage Consumers Energy Company has an ownership interest in the Ludington Hydroelectric Pumped Storage Plant. Consumers Energy is entitled to 51% of the total capacity and energy of the plant and is responsible for the same percentage of the plant’s operation, maintenance, and capital improvement costs.
NOTE 9 — ASSET RETIREMENT OBLIGATIONS DTE Electric has a legal retirement obligation for the decommissioning costs for its Fermi 1 and Fermi 2 nuclear plants, dismantlement of facilities located on leased property, and various other operations. DTE Electric has conditional retirement obligations for asbestos and PCB removal at certain of its power plants and various distribution equipment. DTE Gas has conditional retirement obligations for gas pipelines, certain service centers, compressor and gate stations. The Registrants recognize such obligations as liabilities at fair market value when they are incurred, which generally is at the time the associated assets are placed in service. Fair value is measured using expected future cash outflows discounted at the Registrants' credit-adjusted risk-free rate. For its utility operations, the Registrants recognize in the Consolidated Statements of Operations removal costs in accordance with regulatory treatment. Any differences between costs recognized related to asset retirement and those reflected in rates are recognized as either a Regulatory asset or liability on the Consolidated Statements of Financial Position.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
If a reasonable estimate of fair value cannot be made in the period in which the retirement obligation is incurred, such as for assets with indeterminate lives, the liability is recognized when a reasonable estimate of fair value can be made. Natural gas storage system and certain other distribution assets for DTE Gas and substations, manholes, and certain other distribution assets for DTE Electric have an indeterminate life. Therefore, no liability has been recorded for these assets.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) Changes to asset retirement obligations for 2020, 2019, 2018, and 20172018 were as follows: | | | | | | | | | | | | | | | 2019 | | 2018 | | 2017 | | DTE Energy | (In millions) | | Asset retirement obligations at January 1 | $ | 2,469 |
| | $ | 2,320 |
| | $ | 2,197 |
| | Accretion | 149 |
| | 140 |
| | 131 |
| | Liabilities incurred | 20 |
| | 27 |
| | 2 |
| | Liabilities settled | (17 | ) | | (16 | ) | | (6 | ) | | Revision in estimated cash flows | 51 |
| | (2 | ) | | (4 | ) | | Asset retirement obligations at December 31 | $ | 2,672 |
| | $ | 2,469 |
| | $ | 2,320 |
|
| | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | DTE Energy | (In millions) | | Asset retirement obligations at January 1 | $ | 2,672 | | | $ | 2,469 | | | $ | 2,320 | | | Accretion | 157 | | | 149 | | | 140 | | | Liabilities incurred | 25 | | | 20 | | | 27 | | | Liabilities settled | (14) | | | (17) | | | (16) | | | Revision in estimated cash flows | (1) | | | 51 | | | (2) | | | Asset retirement obligations at December 31 | $ | 2,839 | | | $ | 2,672 | | | $ | 2,469 | |
| | | | | | | | | | | | | | | 2019 | | 2018 | | 2017 | | DTE Electric | (In millions) | | Asset retirement obligations at January 1 | $ | 2,271 |
| | $ | 2,125 |
| | $ | 2,012 |
| | Accretion | 138 |
| | 129 |
| | 120 |
| | Liabilities incurred | 1 |
| | 27 |
| | 1 |
| | Liabilities settled | (14 | ) | | (8 | ) | | (2 | ) | | Revision in estimated cash flows | 51 |
| | (2 | ) | | (6 | ) | | Asset retirement obligations at December 31 | $ | 2,447 |
| | $ | 2,271 |
| | $ | 2,125 |
|
| | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | DTE Electric | (In millions) | | Asset retirement obligations at January 1 | $ | 2,447 | | | $ | 2,271 | | | $ | 2,125 | | | Accretion | 145 | | | 138 | | | 129 | | | Liabilities incurred | 18 | | | 1 | | | 27 | | | Liabilities settled | (8) | | | (14) | | | (8) | | | Revision in estimated cash flows | 5 | | | 51 | | | (2) | | | Asset retirement obligations at December 31 | $ | 2,607 | | | $ | 2,447 | | | $ | 2,271 | |
Approximately $2.1$2.2 billion of the asset retirement obligations represent nuclear decommissioning liabilities that are funded through a surcharge to electric customers over the life of the Fermi 2 nuclear plant. The NRC has jurisdiction over the decommissioning of nuclear power plants and requires minimum decommissioning funding based upon a formula. The MPSC and FERC regulate the recovery of costs of decommissioning nuclear power plants and both require the use of external trust funds to finance the decommissioning of Fermi 2. Rates approved by the MPSC provide for the recovery of decommissioning costs of Fermi 2 and the disposal of low-level radioactive waste. DTE Electric believes the MPSC collections will be adequate to fund the estimated cost of decommissioning. The decommissioning assets, anticipated earnings thereon, and future revenues from decommissioning collections will be used to decommission Fermi 2. DTE Electric expects the liabilities to be reduced to 0 at the conclusion of the decommissioning activities. If amounts remain in the trust funds for Fermi 2 following the completion of the decommissioning activities, those amounts will be disbursed based on rulings by the MPSC and FERC. A portion of the funds recovered through the Fermi 2 decommissioning surcharge and deposited in external trust accounts is designated for the removal of non-radioactive assets and returning the site to greenfield. This removal and greenfielding is not considered a legal liability. Therefore, it is not included in the asset retirement obligation, but is reflected as the Nuclear decommissioning liability. The decommissioning of Fermi 1 is funded by DTE Electric. Contributions to the Fermi 1 trust are discretionary. For additional discussion of Nuclear decommissioning trust fund assets, see Note 13 to the Consolidated Financial Statements, "Fair Value."
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
NOTE 10 — REGULATORY MATTERS Regulation DTE Electric and DTE Gas are subject to the regulatory jurisdiction of the MPSC, which issues orders pertaining to rates, recovery of certain costs, including the costs of generating facilities and regulatory assets, conditions of service, accounting, and operating-related matters. DTE Electric is also regulated by the FERC with respect to financing authorization, and wholesale electric activities.market activities, certain affiliate transactions, the acquisition and disposition of certain generation and other facilities, and, in conjunction with the NERC, compliance with mandatory reliability standards. Regulation results in differences in the application of generally accepted accounting principles between regulated and non-regulated businesses. The Registrants are unable to predict the outcome of theany unresolved regulatory matters discussed herein. Resolution of these matters is dependent upon future MPSC and FERC orders and appeals, which may materially impact the Consolidated Financial Statements of the Registrants. Regulatory Assets and Liabilities DTE Electric and DTE Gas are required to record Regulatory assets and liabilities for certain transactions that would have been treated as revenue or expense in non-regulated businesses. Continued applicability of regulatory accounting treatment requires that rates be designed to recover specific costs of providing regulated services and be charged to and collected from customers. Future regulatory changes could result in the discontinuance of this accounting treatment for Regulatory assets and liabilities for some or all of the Registrants' businesses and may require the write-off of the portion of any Regulatory asset or liability that was no longer probable of recovery through regulated rates. Management believes that currently available facts support the continued use of Regulatory assets and liabilities and that all Regulatory assets and liabilities are recoverable or refundable in the current regulatory environment.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
The following are balances and a brief description of the Registrants' Regulatory assets and liabilities at December 31: | | | | DTE Energy | | DTE Electric | | DTE Energy | | DTE Electric | | | 2019 | | 2018 | | 2019 | | 2018 | | 2020 | | 2019 | | 2020 | | 2019 | | Assets | (In millions) | Assets | (In millions) | | Recoverable pension and other postretirement costs | | | | | | | | Recoverable pension and other postretirement costs | | | Pension | $ | 1,983 |
| | $ | 1,961 |
| | $ | 1,497 |
| | $ | 1,476 |
| Pension | $ | 1,938 | | | $ | 1,983 | | | $ | 1,477 | | | $ | 1,497 | | | Other postretirement costs | 201 |
| | 213 |
| | 131 |
| | 121 |
| Other postretirement costs | 165 | | | 201 | | | 108 | | | 131 | | | Recoverable undepreciated costs on retiring plants | | Recoverable undepreciated costs on retiring plants | 664 | | | 657 | | | 664 | | | 657 | | | Fermi 2 asset retirement obligation | 669 |
| | 778 |
| | 669 |
| | 778 |
| Fermi 2 asset retirement obligation | 645 | | | 669 | | | 645 | | | 669 | | | Recoverable undepreciated costs on retiring plants | 657 |
| | 630 |
| | 657 |
| | 630 |
| | | Recoverable Michigan income taxes | 189 |
| | 201 |
| | 152 |
| | 161 |
| Recoverable Michigan income taxes | 176 | | | 189 | | | 142 | | | 152 | | | Enhanced Tree Trimming Program deferred costs | | Enhanced Tree Trimming Program deferred costs | 119 | | | 43 | | | 119 | | | 43 | | | Accrued PSCR revenue | | Accrued PSCR revenue | 100 | | | 3 | | | 100 | | | 3 | | | Recoverable income taxes related to AFUDC equity | | Recoverable income taxes related to AFUDC equity | 64 | | | 56 | | | 54 | | | 47 | | | Energy Waste Reduction incentive | | Energy Waste Reduction incentive | 62 | | | 54 | | | 49 | | | 43 | | | Deferred environmental costs | 66 |
| | 69 |
| | — |
| | — |
| Deferred environmental costs | 57 | | | 66 | | | 0 | | | 0 | | | Recoverable income taxes related to AFUDC equity | 56 |
| | 51 |
| | 47 |
| | 41 |
| | | Unamortized loss on reacquired debt | 56 |
| | 60 |
| | 40 |
| | 43 |
| Unamortized loss on reacquired debt | 55 | | | 56 | | | 41 | | | 40 | | | Nuclear Performance Evaluation and Review Committee Tracker | | Nuclear Performance Evaluation and Review Committee Tracker | 55 | | | 48 | | | 55 | | | 48 | | | Customer360 deferred costs | 55 |
| | 42 |
| | 55 |
| | 42 |
| Customer360 deferred costs | 51 | | | 55 | | | 51 | | | 55 | | | Energy Waste Reduction incentive | 54 |
| | 49 |
| | 43 |
| | 39 |
| | | Nuclear Performance Evaluation and Review Committee Tracker | 48 |
| | 43 |
| | 48 |
| | 43 |
| | | Enhanced Tree Trimming Program deferred costs | 43 |
| | — |
| | 43 |
| | — |
| | | Non-service pension and other postretirement costs | | Non-service pension and other postretirement costs | 21 | | | 15 | | | 0 | | | 0 | | | Other recoverable income taxes | 20 |
| | 23 |
| | 20 |
| | 23 |
| Other recoverable income taxes | 19 | | | 20 | | | 19 | | | 20 | | | Non-service pension and other postretirement costs | 15 |
| | 10 |
| | — |
| | — |
| | | Transitional Reconciliation Mechanism | 10 |
| | 21 |
| | 10 |
| | 21 |
| Transitional Reconciliation Mechanism | 11 | | | 10 | | | 11 | | | 10 | | | Accrued PSCR/GCR revenue | 3 |
| | 116 |
| | 3 |
| | 116 |
| | | Removal costs asset | — |
| | 407 |
| | — |
| | 407 |
| | | | Other | 51 |
| | 47 |
| | 38 |
| | 36 |
| Other | 55 | | | 51 | | | 28 | | | 38 | | | | 4,176 |
| | 4,721 |
| | 3,453 |
| | 3,977 |
| | 4,257 | | | 4,176 | | | 3,563 | | | 3,453 | | | Less amount included in Current Assets | (5 | ) | | (153 | ) | | (5 | ) | | (148 | ) | Less amount included in Current Assets | (129) | | | (5) | | | (123) | | | (5) | | | | $ | 4,171 |
| | $ | 4,568 |
| | $ | 3,448 |
| | $ | 3,829 |
| | $ | 4,128 | | | $ | 4,171 | | | $ | 3,440 | | | $ | 3,448 | | |
| | | | | | | | | | | | | | | | | | | DTE Energy | | DTE Electric | | | 2019 | | 2018 | | 2019 | | 2018 | | Liabilities | (In millions) | | Refundable federal income taxes | $ | 2,359 |
| | $ | 2,410 |
| | $ | 1,911 |
| | $ | 1,958 |
| | Removal costs liability | 700 |
| | 253 |
| | 483 |
| | — |
| | Negative other postretirement offset | 93 |
| | 101 |
| | 69 |
| | 79 |
| | Renewable energy | 54 |
| | 86 |
| | 54 |
| | 86 |
| | Non-service pension and other postretirement costs | 46 |
| | 22 |
| | 21 |
| | 11 |
| | Accrued PSCR/GCR refund | 23 |
| | — |
| | — |
| | — |
| | TCJA rate reduction liability | 1 |
| | 118 |
| | — |
| | 93 |
| | Other | 53 |
| | 58 |
| | 48 |
| | 42 |
| | | 3,329 |
| | 3,048 |
| | 2,586 |
| | 2,269 |
| | Less amount included in Current Liabilities | (65 | ) | | (126 | ) | | (40 | ) | | (98 | ) | | | $ | 3,264 |
| | $ | 2,922 |
| | $ | 2,546 |
| | $ | 2,171 |
|
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) | | | | | | | | | | | | | | | | | | | | | | | | | DTE Energy | | DTE Electric | | 2020 | | 2019 | | 2020 | | 2019 | | Liabilities | (In millions) | | Refundable federal income taxes | $ | 2,255 | | | $ | 2,359 | | | $ | 1,827 | | | $ | 1,911 | | | Removal costs liability | 831 | | | 700 | | | 410 | | | 483 | | | Negative other postretirement offset | 122 | | | 93 | | | 86 | | | 69 | | | Non-service pension and other postretirement costs | 78 | | | 46 | | | 36 | | | 21 | | | COVID-19 voluntary refund | 30 | | | 0 | | | 30 | | | 0 | | | Renewable energy | 21 | | | 54 | | | 21 | | | 54 | | | | | | | | | | | Accrued GCR refund | 20 | | | 23 | | | 0 | | | 0 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | Other | 45 | | | 54 | | | 40 | | | 48 | | | 3,402 | | | 3,329 | | | 2,450 | | | 2,586 | | | Less amount included in Current Liabilities | (39) | | | (65) | | | (18) | | | (40) | | | $ | 3,363 | | | $ | 3,264 | | | $ | 2,432 | | | $ | 2,546 | |
As noted below, certain Regulatory assets for which costs have been incurred have been included (or are expected to be included, for costs incurred subsequent to the most recently approved rate case) in DTE Electric's or DTE Gas' rate base, thereby providing a return on invested costs (except as noted). Certain other regulatory assets are not included in rate base but accrue recoverable carrying charges until surcharges to collect the assets are billed. Certain Regulatory assets do not result from cash expenditures and therefore do not represent investments included in rate base or have offsetting liabilities that reduce rate base.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
ASSETS | | • | •Recoverable pension and other postretirement costs — Accounting standards for pension and other postretirement benefit costs require, among other things, the recognition in Other comprehensive income of the actuarial gains or losses and the prior service costs that arise during the period but that are not immediately recognized as components of net periodic benefit costs. DTE Electric and DTE Gas record the impact of actuarial gains or losses and prior service costs as Regulatory assets since the traditional rate setting process allows for the recovery of pension and other postretirement costs. The asset will reverse as the deferred items are amortized and recognized as components of net periodic benefit costs.(a) •Recoverable undepreciated costs on retiring plants — Deferral of estimated remaining balances associated with coal power plants expected to be retired by the end of 2022. •Fermi 2 asset retirement obligation — This obligation is for Fermi 2 decommissioning costs. The asset captures the timing differences between expense recognition and current recovery in rates and will reverse over the remaining life of the related plant.(a) •Recoverable Michigan income taxes — The State of Michigan enacted a corporate income tax resulting in the establishment of state deferred tax liabilities for DTE Energy's utilities. Offsetting Regulatory assets were also recorded as the impacts of the deferred tax liabilities will be reflected in rates as the related taxable temporary differences reverse and flow through current income tax expense. •Enhanced Tree Trimming Program deferred costs — The MPSC approved the deferral of costs for a tree trimming surge through 2022, aimed at reducing the number and duration of customer interruptions. Recovery of these costs and related amortization will be determined at a future rate proceeding. •Accrued PSCR revenue — Receivable for the temporary under-recovery of and carrying costs on fuel and purchased power costs incurred by DTE Electric which are recoverable through the PSCR mechanism. •Recoverable income taxes related to AFUDC equity — Accounting standards for income taxes require recognition of a deferred tax liability for the equity component of AFUDC. A Regulatory asset since the traditional rate setting process allows for the recovery of pension and other postretirement costs. The asset will reverse as the deferred items are amortized and recognized as components of net periodic benefit costs.(a) |
| | • | Fermi 2 asset retirement obligation — This obligation is for Fermi 2 decommissioning costs. The asset captures the timing differences between expense recognition and current recovery in rates and will reverse over the remaining life of the related plant.(a)
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| | • | Recoverable undepreciated costs on retiring plants — Deferral of estimated remaining balances associated with coal power plants expected to be retired by 2023.
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| | • | Recoverable Michigan income taxes — The State of Michigan enacted a corporate income tax resulting in the establishment of state deferred tax liabilities for DTE Energy's utilities. Offsetting Regulatory assets were also recorded as the impacts of the deferred tax liabilities will be reflected in rates as the related taxable temporary differences reverse and flow through current income tax expense.
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| | • | Deferred environmental costs — The MPSC approved the deferral of investigation and remediation costs associated with DTE Gas' former MGP sites. Amortization of deferred costs is over a ten-year period beginning in the year after costs were incurred, with recovery (net of any insurance proceeds) through base rate filings.(a)
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| | • | Recoverable income taxes related to AFUDC equity — Accounting standards for income taxes require recognition of a deferred tax liability for the equity component of AFUDC. A regulatory asset is required for the future increase in taxes payable related to the equity component of AFUDC that will be recovered from customers through future rates over the remaining life of the related plant.
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| | • | Unamortized loss on reacquired debt — The unamortized discount, premium, and expense related to debt redeemed with a refinancing are deferred, amortized, and recovered over the life of the replacement issue.
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| | • | Customer360 deferred costs — The MPSC approved the deferral and amortization of certain costs associated with implementing Customer360, an integrated software application that enables improved interface among customer service, billing, meter reading, credit and collections, device management, account management, and retail access. Amortization of deferred costs over a 15-year amortization period began after the billing system was put into operation during the second quarter of 2017.
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| | • | Energy Waste Reduction incentive — DTE Electric and DTE Gas operate MPSC approved energy waste reduction programs designed to reduce overall energy usage by their customers. The utilities are eligible to earn an incentive by exceeding statutory savings targets. The utilities have consistently exceeded the savings targets and recognize the incentive as a regulatory asset in the period earned.(a)
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| | • | Nuclear Performance Evaluation and Review Committee Tracker — Deferral and amortization of certain costs associated with oversight and review of DTE Electric's nuclear power generation program, including safety and regulatory compliance, nuclear leadership, nuclear facilities, as well as operation and financial performance, pursuant to the MPSC authorization. The approved five-year amortization period began January 1, 2018, with recovery through base rate filings.
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| | • | Enhanced Tree Trimming Program deferred costs — The MPSC approved the deferral of costs for the first three years of a tree trimming surge, aimed at reducing the number and duration of customer interruptions. The MPSC will review the surge program and amortization of deferred costs in future rate filings.
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| | • | Other recoverable income taxes — Income taxes receivable from DTE Electric's customers representing the difference in property-related deferred income taxes and amounts previously reflected in DTE Electric's rates. This asset will reverse over the remaining life of the related plant.
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DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
| | • | Non-service pension•Deferred environmental costs — The MPSC approved the deferral of investigation and remediation costs associated with DTE Gas' former MGP sites. Amortization of deferred costs is over a ten-year period beginning in the year after costs were incurred, with recovery (net of any insurance proceeds) through base rate filings.(a) •Unamortized loss on reacquired debt — The unamortized discount, premium, and expense related to debt redeemed with a refinancing are deferred, amortized, and recovered over the life of the replacement issue. •Nuclear Performance Evaluation and Review Committee Tracker — Deferral and amortization of certain costs associated with oversight and review of DTE Electric's nuclear power generation program, including safety and other postretirement costs — Upon adoption of ASU 2017-07 on January 1, 2018, certain non-service costs are no longer capitalized into Property, Plant & Equipment. Such costs may be recorded to regulatory compliance, nuclear leadership, nuclear facilities, as well as operation and financial performance, pursuant to the MPSC authorization. Deferrals are amortized over a five-year period with recovery through base rate filings. •Customer360 deferred costs — The MPSC approved the deferral and amortization of certain costs associated with implementing Customer360, an integrated software application that enables improved interface among customer service, billing, meter reading, credit and collections, device management, account management, and retail access. Amortization of deferred costs over a 15-year amortization period began after the billing system was put into operation during the second quarter of 2017. The deferred costs are recorded as Regulatory Assets at DTE Electric and DTE Gas receives an intercompany charge for their proportionate share of amortization expense. •Non-service pension and other postretirement costs — Upon adoption of ASU 2017-07 on January 1, 2018, certain non-service pension and other postretirement costs are no longer capitalized into Property, Plant & Equipment. Such costs may be recorded to Regulatory assets for ratemaking purposes and recovered as amortization expense based on the composite depreciation rate for plant-in-service. •Other recoverable income taxes — Income taxes receivable from DTE Electric's customers representing the difference in property-related deferred income taxes and amounts previously reflected in DTE Electric's rates. This asset will reverse over the remaining life of the related plant. •Transitional Reconciliation Mechanism — The MPSC approved the recovery of the deferred net incremental revenue requirement associated with the transition of PLD customers to DTE Electric's distribution system, effective July 1, 2014. Annual reconciliations are filed and surcharges are implemented to recover approved amounts. (a)Regulatory assets not earning a return or accruing carrying charges. |
| | • | Transitional Reconciliation Mechanism — The MPSC approved the recovery of the deferred net incremental revenue requirement associated with the transition of PLD customers to DTE Electric's distribution system, effective July 1, 2014. Annual reconciliations are filed and surcharges are implemented to recover approved amounts.
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| | • | Accrued PSCR/GCR revenue — Receivable for the temporary under-recovery of and carrying costs on fuel and purchased power costs incurred by DTE Electric which are recoverable through the PSCR mechanism and temporary under-recovery of and carrying costs on gas costs incurred by DTE Gas which are recoverable through the GCR mechanism.
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| | • | Removal costs asset — Receivable for the recovery of asset removal expenditures in excess of amounts collected from customers.(a) Cost of removal is included within depreciation rates approved by the MPSC. In connection with DTE Electric's recent rate order in 2019 which approved an updated depreciation study, DTE Electric re-measured the amount of historical depreciation expense that had been allocated between accumulated depreciation and cost of removal. The reallocation was performed following a settlement with the MPSC in which DTE Electric agreed to maintain specific, individual reserve accounts for the cost of removal for certain retiring plants. Based upon the reallocation, it was determined that the amounts collected for asset removal expenditures, as a component of depreciation, have exceeded actual asset removal expenditures. Accordingly, DTE Electric reallocated amounts from accumulated depreciation to the removal cost regulatory balance resulting in a net Removal costs liability as of December 31, 2019.
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| | (a) | Regulatory assets not earning a return or accruing carrying charges. |
LIABILITIES | | • | Refundable federal income taxes — DTE Electric and DTE Gas' remeasurement of deferred taxes due to the enactment of the TCJA, which reflects the net impact of the tax rate change on cumulative temporary differences expected to reverse after the effective date of January 1, 2018. Refer to "2017 Tax Reform" section below for additional information.•Refundable federal income taxes — In December 2017, the TCJA was enacted and reduced the corporate income tax rate, effective January 1, 2018. DTE Electric and DTE Gas remeasured deferred taxes, resulting in a reduction to deferred tax liabilities, to reflect the impact of the TCJA on the cumulative temporary differences expected to reverse after the effective date. Regulatory liabilities were also recorded to offset the impact of the deferred tax remeasurement reflected in rates. •Removal costs liability — The amounts collected from customers in excess of the estimated cost of future asset removal activities. Cost of removal is included within depreciation rates approved by the MPSC. In 2019, the MPSC approved a settlement agreement in DTE Gas' depreciation case to increase depreciation rates effective following an order in the next general rate case. The new depreciation rates became effective October 1, 2020. In connection with the settlement agreement and the new rates, DTE Gas also re-measured the amount of historical depreciation expense that had been allocated between accumulated depreciation and cost of removal. The reallocation was performed to provide a more accurate estimate of DTE Gas' reserve balances on assets under the group depreciation methodology. Based upon the reallocation, it was determined that the amounts collected for asset removal expenditures, as a component of depreciation, further exceeded actual asset removal expenditures. Accordingly, DTE Gas reallocated amounts from accumulated depreciation to the removal cost regulatory balance, resulting in an increase to the Removal cost liability as of December 31, 2020. |
| | • | Removal costs liability — The amount collected from customers for the funding of future asset removal activities. For 2019, the liability includes amounts previously reflected within the Removal costs asset for DTE Electric, as noted above.
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| | • | Negative other postretirement offset — DTE Electric and DTE Gas' negative other postretirement costs are not included as a reduction to their authorized rates; therefore, DTE Electric and DTE Gas are accruing a Regulatory liability to eliminate the impact on earnings of the negative other postretirement expense accrual. The Regulatory liabilities will reverse to the extent DTE Electric and DTE Gas' other postretirement expense is positive in future years.
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| | • | Renewable energy — Amounts collected in rates in excess of renewable energy expenditures.
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| | • | Non-service pension and other postretirement costs— Upon adoption of ASU 2017-07 on January 1, 2018, certain non-service cost activity is no longer credited to Property, Plant & Equipment. Such costs may be recorded to regulatory liabilities for ratemaking purposes and refunded through credits to amortization expense based on the composite depreciation rate for plant-in-service.
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| | • | Accrued PSCR/GCR refund - Liability for the temporary over-recovery of and a return on power supply costs and transmission costs incurred by DTE Electric which are recoverable through the PSCR mechanism and temporary over-recovery of and a return on gas costs incurred by DTE Gas which are recoverable through the GCR mechanism.
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| | • | TCJA rate reduction liability — Due to the change in the corporate Federal income tax rate from 35% to 21%, DTE Electric and DTE Gas reduced rates charged to customers during 2018. A regulatory liability equal to the difference between revenues billed based on a 35% rate, and revenues based on a 21% rate, was accrued for the period January 1, 2018 through the date the lower rates were implemented. The refund of the liability occurred from January 1, 2019 through June 30, 2019.
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DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
2018 Electric Rate Case Filing
•Negative other postretirement offset — DTE Electric filedand DTE Gas' negative other postretirement costs are not included as a rate case withreduction to their authorized rates; therefore, DTE Electric and DTE Gas are accruing a Regulatory liability to eliminate the MPSCimpact on July 6,earnings of the negative other postretirement expense accrual. The Regulatory liabilities will reverse to the extent DTE Electric and DTE Gas' other postretirement expense is positive in future years. •Non-service pension and other postretirement costs— Upon adoption of ASU 2017-07 on January 1, 2018, requesting an increase in base rates of $328 millioncertain non-service pension and other postretirement cost activity is no longer credited to Property, Plant & Equipment. Such costs may be recorded to regulatory liabilities for ratemaking purposes and refunded through credits to amortization expense based on a projected twelve-month period ending April 30, 2020.the composite depreciation rate for plant-in-service. •COVID-19 voluntary refund — The requested increase in base rates was primarilyone-time refund obligation owed to DTE Electric customers due to an increasecertain sales increases driven by the COVID-19 pandemic. Refer to the "2020 Accounting Applications" section below for additional information related to the voluntary refund. •Renewable energy — Amounts collected in net plant resulting from infrastructure investments, depreciation expense, as requestedrates in excess of renewable energy expenditures. •Accrued GCR refund— Liability for the 2016 DTE Electric Depreciation Case Filing,temporary over-recovery of and reliability improvement projects. The rate filing also requested an increase ina return on equity from 10.0%gas costs incurred by DTE Gas which are recoverable through the GCR mechanism. 2020 COVID-19 Response In response to 10.5% and included projected changes in sales, operation and maintenance expenses, and working capital. In addition, the rate filing requested an Infrastructure Recovery Mechanism to recover the incremental revenue requirement associated with certain distribution, fossil generation, and nuclear generation capital expenditures through 2022. Finally, as noted in the 2017 Tax Reform section below, DTE Electric proposed an amortization schedule for Calculation C in this filing. On February 1, 2019 DTE Electric reduced its initial requested increase in base rates to $248.6 million, primarily reflecting the reduction in requested depreciation expense resulting from the MPSC's approval of new depreciation rates. On May 2, 2019,COVID-19 pandemic, the MPSC issued an order approvingon 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. With the approval of DTE Electric's October 26, 2020 accounting application as noted below, DTE Electric voluntarily reversed its 2020 deferral and recorded as expense, with deferrals resuming in January 2021. DTE Gas deferred $2 million of uncollectible expense as Regulatory assets through December 31, 2020 as a result of the MPSC's COVID-19 response order. On July 23, 2020, the MPSC further ordered that utilities seeking to recover COVID-19 related expenses beyond uncollectible expense may make an annual revenue increase of $125 million for services rendered on or after May 9, 2019.informational filing no later than November 2, 2020. The Registrants did not make a filing, but will continue to monitor MPSC authorized a return on equity of 10.0%. In addition, the order approved the proposed amortization schedule for Calculation C but denied the requested Infrastructure Recovery Mechanism.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 iswas primarily due to an increase in net plant resulting from distribution infrastructure and generation investments. The rate filing also requestsrequested an increase in return on equity from 10.0% to 10.5% and includesincluded projected changes in sales and operating and maintenance expenses. A final MPSC order in this case is expected byOn May 2020. 2016 DTE Electric Depreciation Case Filing
DTE Electric filed a depreciation case with8, 2020, the MPSC on November 1, 2016 requesting an increase in depreciation rates for plant in service balances as of December 31, 2015. The MPSC issued an order on December 6, 2018 authorizing DTE Electric toapproving an annual revenue increase its composite depreciation rate from 3.06% to 3.72%. The new rates are effectiveof $188 million for serviceservices 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 year ended December 31, 2020.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) 2020 Accounting Applications On July 9, 2019, per2020, the final order inMPSC approved DTE Electric's 2018request to accelerate amortization of the portion of its Refundable federal income taxes regulatory liability related to non-plant 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 portion of the 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 issued on May 2, 2019.filing previously set for July 2020 to at least March 2021. 2017 Tax Reform
On December 27, 2017, the MPSC issued an order to consider changes in the rates of all Michigan rate-regulated utilities to reflect the effects of the federal TCJA. On January 19, 2018,October 26, 2020, DTE Electric and DTE Gas filed informationan application with the MPSC regarding the potential change in revenue requirements due to the TCJA effective January 1, 2018 and outlined their recommended method to flow the current and deferred tax benefits of those impacts to ratepayers. On February 22, 2018, the MPSC issued an order in this case requiring utilities, including DTE Electric and DTE Gas, to followrequesting accounting authority for a 3-step approach of credits and calculations. In 2018, MPSC orders for the first two steps, Credit A and Credit B, were issued for DTE Electric and DTE Gas. The third step is to perform Calculation C to address all remaining issues relative to the new tax law, which is primarily the remeasurement of deferred taxes and how the amounts deferred as Regulatory liabilities will flow to ratepayers. DTE Gas filed its Calculation C case on November 16, 2018 to reduce the annual revenue requirement by $12 million related to the amortization of deferred tax remeasurement. On August 20, 2019, the MPSC issued an order in this case approving a $13 million reduction to DTE Gas' annual revenue requirement. This reduction in revenue will be offset by a corresponding reduction in income tax expenses with the Consolidated Statement of Operations.one-time regulatory liability. DTE Electric proposed an amortization schedule for Calculation Caccruing 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. On December 9, 2020, the MPSC approved DTE Electric's request. Accordingly, DTE Electric recorded a regulatory liability and reduction to Operating revenues of $30 million. Amortization of the regulatory liability will be used to offset the cost of service related to new plant in 2022. The regulatory liability will be amortized beginning January 1, 2022 through the earlier of new base rates or December 31, 2022. The one-time accounting treatment does not impact customer rates and will allow DTE Electric to further defer its generalnext rate case filed July 6, 2018, which wasfiling from March 2021 to May 2021.
Additionally, as noted above, DTE Electric began deferring uncollectible expense in the second quarter 2020 as a result of the MPSC's COVID-19 response order. With the approval of the October 26th accounting application, DTE Electric voluntarily reversed this deferral and recorded as expense. This action only applies to DTE Electric in 2020 and the deferral of uncollectible expense will resume beginning in January 2021, as approved by the MPSC in the May 2, 2019 rateon its December 9, 2020 order. 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 was primarily due to an increase in net plant resulting from infrastructure investments and operating and maintenance expenses. The rate filing also requested an increase in return on equity from 10.0% to 10.5% and included projected changes in sales and working capital. On July 17, 2020, DTE Gas reached a settlement with all intervening parties in the case and filed a settlement agreement authorizing the company to increase base rates by $110 million, reflecting a return on equity of 9.9%. The resulting rates are a net increase to customers of $51 million as an existing Infrastructure Recovery Mechanism (IRM) surcharge will be rolled into the new base rates. The settlement agreement also approved a $20 million annual increase to the amortization of the portion of the Refundable federal income taxes regulatory liability related to non-plant accumulated deferred income tax balances resulting from the TCJA. This increased amortization will cease upon DTE Gas receiving its next rate order. The MPSC approved the settlement agreement on August 20, 2020 and DTE Gas implemented the increases to rates and amortization effective October 1, 2020. In addition, the settlement agreement disallowed capitalized expenditures related to incentive compensation, consistent with the MPSC order issued for DTE Electric on May 8, 2020. In anticipation of this result, DTE Gas recorded a disallowance of $14 million during the second quarter 2020, which is included in Asset (gains) losses and impairment, net on the Consolidated Statements of Operations for the year ended December 31, 2020. 2021 Gas Rate Case Filing DTE Gas filed a rate case with the MPSC on February 12, 2021 requesting an increase in base rates of $195 million based on a projected twelve-month period ending December 31, 2022. 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 requestsrequested an increase in return on equity from 10.0%9.9% to 10.5%10.25% and includes projected changes in sales and working capital. A final MPSC order in this case is expected by September 2020.December 2021.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) NOTE 11 — INCOME TAXES Income Tax Summary DTE Energy files a consolidated federal income tax return. DTE Electric is a part of the consolidated federal income tax return of DTE Energy. DTE Energy and its subsidiaries file consolidated and/or separate company income tax returns in various states and localities, including a consolidated return in the State of Michigan. DTE Electric is part of the Michigan consolidated income tax return of DTE Energy. The federal, state and local income tax expense for DTE Electric is determined on an individual company basis with no allocation of tax expenses or benefits from other affiliates of DTE Energy. DTE Electric had income tax receivables with DTE Energy of $14$8 million and $8$14 million at December 31, 20192020 and 2018,2019, respectively. The Registrants' total Income Tax Expense varied from the statutory federal income tax rate for the following reasons: | | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | DTE Energy | (In millions) | | Income Before Income Taxes | $ | 1,538 | | | $ | 1,324 | | | $ | 1,216 | | | Income tax expense at 21% statutory rate | $ | 323 | | | $ | 278 | | | $ | 255 | | | State and local income taxes, net of federal benefit | 81 | | | 48 | | | 60 | | | Production tax credits | (121) | | | (128) | | | (223) | | | TCJA regulatory liability amortization | (76) | | | (38) | | | 0 | | | Net operating loss carryback | (34) | | | 0 | | | 0 | | | AFUDC equity | (4) | | | (4) | | | (14) | | | Employee Stock Ownership Plan dividends | (4) | | | (3) | | | (3) | | | Investment tax credits | (4) | | | (4) | | | (4) | | | Stock based compensation | (3) | | | (7) | | | (3) | | | Enactment of the Tax Cuts and Jobs Act | 0 | | | 0 | | | 21 | | | Noncontrolling interests | 1 | | | 0 | | | 2 | | | Depreciation | 2 | | | 2 | | | 2 | | | Other, net | 6 | | | 8 | | | 5 | | | Income Tax Expense | $ | 167 | | | $ | 152 | | | $ | 98 | | | Effective income tax rate | 10.9 | % | | 11.5 | % | | 8.1 | % |
| | | | | | | | | | 2020 | | 2019 | | 2018 | | | 2019 | | 2018 | | 2017 | | | DTE Energy | (In millions) | | | DTE Electric | | DTE Electric | (In millions) | | Income Before Income Taxes | $ | 1,324 |
| | $ | 1,216 |
| | $ | 1,287 |
| Income Before Income Taxes | $ | 887 | | | $ | 854 | | | $ | 857 | | | Income tax expense at statutory rate - 21% in 2019 and 2018 - 35% in 2017 | $ | 278 |
| | $ | 255 |
| | $ | 450 |
| | | Income tax expense at 21% statutory rate | | Income tax expense at 21% statutory rate | $ | 186 | | | $ | 179 | | | $ | 180 | | | State and local income taxes, net of federal benefit | | State and local income taxes, net of federal benefit | 50 | | | 49 | | | 49 | | | TCJA regulatory liability amortization | | TCJA regulatory liability amortization | (62) | | | (35) | | | 0 | | | Production tax credits | (128 | ) | | (223 | ) | | (189 | ) | Production tax credits | (55) | | | (45) | | | (35) | | | Investment tax credits | (4 | ) | | (4 | ) | | (4 | ) | Investment tax credits | (4) | | | (4) | | | (3) | | | TCJA regulatory liability amortization | (38 | ) | | — |
| | — |
| | | Depreciation | 2 |
| | 2 |
| | (4 | ) | | | Noncontrolling interests | — |
| | 2 |
| | 8 |
| | | AFUDC equity | (4 | ) | | (14 | ) | | (18 | ) | AFUDC equity | (4) | | | (4) | | | (3) | | | Employee Stock Ownership Plan dividends | (3 | ) | | (3 | ) | | (5 | ) | Employee Stock Ownership Plan dividends | (2) | | | (2) | | | (2) | | | Stock based compensation | (7 | ) | | (3 | ) | | (14 | ) | | | State and local income taxes, net of federal benefit | 48 |
| | 60 |
| | 51 |
| | | | Enactment of the Tax Cuts and Jobs Act | — |
| | 21 |
| | (105 | ) | Enactment of the Tax Cuts and Jobs Act | 0 | | | 0 | | | 7 | | | Depreciation | | Depreciation | 2 | | | 2 | | | 2 | | | Other, net | 8 |
| | 5 |
| | 5 |
| Other, net | (2) | | | (2) | | | (2) | | | Income Tax Expense | $ | 152 |
| | $ | 98 |
| | $ | 175 |
| Income Tax Expense | $ | 109 | | | $ | 138 | | | $ | 193 | | | Effective income tax rate | 11.5 | % | | 8.1 | % | | 13.6 | % | Effective income tax rate | 12.3 | % | | 16.2 | % | | 22.5 | % |
| | | | | | | | | | | | | | | 2019 | | 2018 | | 2017 | | DTE Electric | (In millions) | | Income Before Income Taxes | $ | 854 |
| | $ | 857 |
| | $ | 928 |
| | Income tax expense at statutory rate - 21% in 2019 and 2018 - 35% in 2017 | $ | 179 |
| | $ | 180 |
| | $ | 325 |
| | Production tax credits | (45 | ) | | (35 | ) | | (36 | ) | | Investment tax credits | (4 | ) | | (3 | ) | | (4 | ) | | TCJA regulatory liability amortization | (35 | ) | | — |
| | — |
| | Depreciation | 2 |
| | 2 |
| | 3 |
| | AFUDC equity | (4 | ) | | (3 | ) | | (5 | ) | | Employee Stock Ownership Plan dividends | (2 | ) | | (2 | ) | | (3 | ) | | State and local income taxes, net of federal benefit | 49 |
| | 49 |
| | 48 |
| | Enactment of the Tax Cuts and Jobs Act | — |
| | 7 |
| | — |
| | Other, net | (2 | ) | | (2 | ) | | (1 | ) | | Income Tax Expense | $ | 138 |
| | $ | 193 |
| | $ | 327 |
| | Effective income tax rate | 16.2 | % | | 22.5 | % | | 35.2 | % |
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
Components of the Registrants' Income Tax Expense were as follows: | | | | | | | | | | | | | | | 2019 | | 2018 | | 2017 | | DTE Energy | (In millions) | | Current income tax expense (benefit) | | | | | | | Federal | $ | (184 | ) | | $ | (17 | ) | | $ | (22 | ) | | State and other income tax | 7 |
| | 1 |
| | 1 |
| | Total current income taxes | (177 | ) | | (16 | ) | | (21 | ) | | Deferred income tax expense | | | | | | | Federal | 275 |
| | 38 |
| | 118 |
| | State and other income tax | 54 |
| | 76 |
| | 78 |
| | Total deferred income taxes | 329 |
| | 114 |
| | 196 |
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| $ | 152 |
| | $ | 98 |
| | $ | 175 |
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| | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | DTE Energy | (In millions) | | Current income tax expense (benefit) | | | | | | | Federal | $ | (247) | | | $ | (184) | | | $ | (17) | | | State and other income tax | 7 | | | 7 | | | 1 | | | Total current income taxes | (240) | | | (177) | | | (16) | | | Deferred income tax expense | | | | | | | Federal | 310 | | | 275 | | | 38 | | | State and other income tax | 97 | | | 54 | | | 76 | | | Total deferred income taxes | 407 | | | 329 | | | 114 | | | | | | | | | | | | | | | $ | 167 | | | $ | 152 | | | $ | 98 | |
| | | | | | | | | | | | | | | 2019 | | 2018 | | 2017 | | DTE Electric | (In millions) | | Current income tax expense (benefit) | | | | | | | Federal | $ | 25 |
| | $ | — |
| | $ | (17 | ) | | State and other income tax | 16 |
| | 4 |
| | (1 | ) | | Total current income taxes | 41 |
| | 4 |
| | (18 | ) | | Deferred income tax expense | | | | | | | Federal | 51 |
| | 131 |
| | 270 |
| | State and other income tax | 46 |
| | 58 |
| | 75 |
| | Total deferred income taxes | 97 |
| | 189 |
| | 345 |
|
| $ | 138 |
| | $ | 193 |
| | $ | 327 |
|
| | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | DTE Electric | (In millions) | | Current income tax expense | | | | | | | Federal | $ | 15 | | | $ | 25 | | | $ | 0 | | | State and other income tax | 5 | | | 16 | | | 4 | | | Total current income taxes | 20 | | | 41 | | | 4 | | | Deferred income tax expense | | | | | | | Federal | 30 | | | 51 | | | 131 | | | State and other income tax | 59 | | | 46 | | | 58 | | | Total deferred income taxes | 89 | | | 97 | | | 189 | | | | | | | | | | | | | | | $ | 109 | | | $ | 138 | | | $ | 193 | |
Deferred tax assets and liabilities are recognized for the estimated future tax effect of temporary differences between the tax basis of assets or liabilities and the reported amounts in the Registrant's Consolidated Financial Statements. Consistent with the original establishment of these deferred tax liabilities (assets), recognition of these non-cash transactions are not reflected in the Consolidated Statements of Cash Flows. The Registrants' deferred tax assets (liabilities) were comprised of the following at December 31: | | | | | | | | | | | | | | | | | | | | | | | | | DTE Energy | | DTE Electric | | 2020 | | 2019 | | 2020 | | 2019 | | (In millions) | | Property, plant, and equipment | $ | (4,032) | | | $ | (3,755) | | | $ | (3,099) | | | $ | (2,956) | | | Regulatory assets and liabilities | (108) | | | (47) | | | (53) | | | 4 | | | Tax credit carry-forwards | 1,144 | | | 1,161 | | | 278 | | | 252 | | | Pension and benefits | 321 | | | 300 | | | 264 | | | 258 | | | Federal net operating loss carry-forward | 265 | | | 276 | | | 0 | | | 0 | | | | | | | | | | | | | | | | | | | State and local net operating loss carry-forwards | 155 | | | 117 | | | 0 | | | 0 | | | Investments in equity method investees | (667) | | | (465) | | | 0 | | | 0 | | | Other | 141 | | | 138 | | | 85 | | | 87 | | | (2,781) | | | (2,275) | | | (2,525) | | | (2,355) | | | Less valuation allowance | (41) | | | (40) | | | 0 | | | 0 | | | Long-term deferred income tax liabilities | $ | (2,822) | | | $ | (2,315) | | | $ | (2,525) | | | $ | (2,355) | | | | | | | | | | | Deferred income tax assets | $ | 2,241 | | | $ | 2,264 | | | $ | 883 | | | $ | 865 | | | Deferred income tax liabilities | (5,063) | | | (4,579) | | | (3,408) | | | (3,220) | | | $ | (2,822) | | | $ | (2,315) | | | $ | (2,525) | | | $ | (2,355) | |
| | | | | | | | | | | | | | | | | | | DTE Energy | | DTE Electric | | | 2019 | | 2018 | | 2019 | | 2018 | | | (In millions) | | Property, plant, and equipment | $ | (3,755 | ) | | $ | (3,462 | ) | | $ | (2,956 | ) | | $ | (2,840 | ) | | Regulatory assets and liabilities | (47 | ) | | (54 | ) | | 4 |
| | (3 | ) | | Tax credit carry-forwards | 1,161 |
| | 1,178 |
| | 252 |
| | 250 |
| | Pension and benefits | 300 |
| | 311 |
| | 258 |
| | 258 |
| | Federal net operating loss carry-forward | 276 |
| | 117 |
| | — |
| | 2 |
| | State and local net operating loss carry-forwards | 117 |
| | 59 |
| | — |
| | 1 |
| | Investments in equity method investees | (465 | ) | | (216 | ) | | — |
| | (1 | ) | | Other | 138 |
| | 125 |
| | 87 |
| | 87 |
| | | (2,275 | ) | | (1,942 | ) | | (2,355 | ) | | (2,246 | ) | | Less valuation allowance | (40 | ) | | (33 | ) | | — |
| | — |
| | Long-term deferred income tax liabilities | $ | (2,315 | ) | | $ | (1,975 | ) | | $ | (2,355 | ) | | $ | (2,246 | ) | | | | | | | | | | | Deferred income tax assets | $ | 2,264 |
| | $ | 2,021 |
| | $ | 865 |
| | $ | 855 |
| | Deferred income tax liabilities | (4,579 | ) | | (3,996 | ) | | (3,220 | ) | | (3,101 | ) | | | $ | (2,315 | ) | | $ | (1,975 | ) | | $ | (2,355 | ) | | $ | (2,246 | ) |
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
Tax credit carry-forwards for DTE Energy include $1.01 billion of general business credits that expire from 2034 through 2039 and $153 million of alternative minimum tax credits that will be refundable over the next three years. The alternative minimum tax credits are production tax credits earned prior to 2006 but not utilized. The majority of these alternative minimum tax credits were generated from projects that had received a private letter ruling (PLR) from the IRS. These PLRs provide assurance as to the appropriateness of using these credits to offset taxable income, however, these tax credits are subject to IRS audit and adjustment. No valuation allowance is required for the tax credits carry-forward deferred tax asset.
DTE Energy has a pre-tax federal net operating loss carry-forward of $1.3 billion as of December 31, 2019.2020. The net operating loss carry-forwards generated in 2015 and 2016 will expire from 2035 through 2036, and the net operating loss carry-forward generated in 2018 and subsequent years will be carried forward indefinitely. No valuation allowance is required for the federal net operating loss deferred tax asset. DTE Energy has state and local deferred tax assets related to net operating loss carry-forwards of $117$155 million and $59$117 million at December 31, 20192020 and 2018,2019, respectively. The state and local net operating loss carry-forwards expire from 20202021 through 2039.2040. DTE Energy has recorded valuation allowances at December 31, 20192020 and 20182019 of approximately $40$41 million and $33$40 million, respectively, which are primarily related to these deferred tax assets. In assessing the realizability of deferred tax assets, DTE Energy considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. Tax credit carry-forwards for DTE Electric include $252$278 million of general business credits that expire from 2036 through 2039.2040. No valuation allowance is required for the tax credits carry-forward deferred tax asset. DTE Electric has 0 state and local deferred tax assets related to net operating loss carry-forwards at December 31, 2019, while there was $1 million of state and local deferred tax assets related to net operating loss carry-forwards at2020 or December 31, 2018. No valuation allowance is required for DTE Electric's state and local net operating loss carry-forwards.2019. The above tables exclude unamortized investment tax credits that are shown separately on the Registrants' Consolidated Statements of Financial Position. Investment tax credits are deferred and amortized to income over the average life of the related property. Tax CutsCARES Act
To assist individuals and Jobsemployers with the impacts of the COVID-19 pandemic, the CARES Act On December 22, 2017, was signed into law in March 2020. The CARES Act included certain tax relief provisions applicable to the TCJA was enacted reducingRegistrants including a) the immediate refund of the corporate incomeAMT credit, b) the ability to carryback net operating losses five years for tax rate from 35% to 21%, effective January 1, 2018. years 2018 through 2020, c) the employee retention credit, and d) delayed payment of employer payroll taxes.
As a result of these provisions, DTE Energy received $220 million of refunds from the enactment, the deferred tax assets and liabilities were remeasured to reflect the impact of the TCJA on the cumulative temporary differences expected to reverse after the effective date. The net impact of this remeasurement was a decrease in deferred tax liabilities of $2.56 billion, of which $2.45 billion was attributable to regulated utilities and offset to regulatory assets and liabilities. This regulatory treatment is consistent with prior precedent set by the MPSC from previous tax law changes. The remaining $105 million was attributable to the non-utility entities and was recognized as a net reduction to income tax expense in 2017. DuringU.S. Treasury during the year ended December 31, 2018, DTE Energy and DTE Electric finalized their analysis and recorded true-up adjustments to2020, including $153 million for the remeasurement of deferred taxes of $21 million and $7 million, respectively. The impactimmediate refund of the true-up adjustments was an increase2018 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 year ended December 31, 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 $17$3 million wasis attributable to DTE Electric. These amounts are included in Taxes other than income in the regulated utilities and increased Regulatory liabilities. During 2019,Consolidated Statements of Operations for the year ended December 31, 2020. The Registrants have also deferred employer payroll taxes of $44 million, of which $23 million is attributable to DTE Electric, increasing the amount of Current Liabilities - Other and DTE Gas began amortizing excess deferred tax liabilities in accordance with orders issued byOther Liabilities - Other on the Michigan Public Service Commission. Refer to Note 10 to theRegistrants' Consolidated Statements of Financial Statements, "Regulatory Matters," for further detail regarding these orders.Position as of December 31, 2020.
Uncertain Tax Positions A reconciliation of the beginning and ending amount of unrecognized tax benefits for the Registrants is as follows: | | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | DTE Energy | (In millions) | | Balance at January 1 | $ | 10 | | | $ | 10 | | | $ | 10 | | | Additions for tax positions of prior years | 0 | | | 0 | | | 0 | | | | | | | | | | | | | | | | | | | | | | | | | | | Balance at December 31 | $ | 10 | | | $ | 10 | | | $ | 10 | |
| | | | | | | | | | | | | | | 2019 | | 2018 | | 2017 | | DTE Energy | (In millions) | | Balance at January 1 | $ | 10 |
| | $ | 10 |
| | $ | 10 |
| | Additions for tax positions of prior years | — |
| | — |
| | — |
| | Balance at December 31 | $ | 10 |
| | $ | 10 |
| | $ | 10 |
|
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
| | | | | | | | | | | | | | | 2019 | | 2018 | | 2017 | | DTE Electric | (In millions) | | Balance at January 1 | $ | 13 |
| | $ | 13 |
| | $ | 13 |
| | Additions for tax positions of prior years | — |
| | — |
| | — |
| | Balance at December 31 | $ | 13 |
| | $ | 13 |
| | $ | 13 |
|
| | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | DTE Electric | (In millions) | | Balance at January 1 | $ | 13 | | | $ | 13 | | | $ | 13 | | | Additions for tax positions of prior years | 0 | | | 0 | | | 0 | | | | | | | | | | | | | | | | | | | | | | | | | | | Balance at December 31 | $ | 13 | | | $ | 13 | | | $ | 13 | |
DTE Energy had $8 million of unrecognized tax benefits at December 31, 20192020 and 20182019 that, if recognized, would favorably impact its effective tax rate. DTE Energy does not anticipate any material decrease in unrecognized tax benefits in the next twelve months. DTE Electric had $10 million of unrecognized tax benefits at December 31, 20192020 and 20182019 that, if recognized, would favorably impact its effective tax rate. DTE Electric doesThe Registrants do not anticipate any material decrease in unrecognized tax benefits in the next twelve months. The Registrants recognize interest and penalties pertaining to income taxes in Interest expense and Other expenses, respectively, on their Consolidated Statements of Operations. Accrued interest pertaining to income taxes for DTE Energy totaled $5 million and $4 million at December 31, 2020 and 2019, and 2018.respectively. DTE Energy recognized interest expense related to income taxes of $1 million in 2020, 2019, and 2018, and a nominal amount in 2017.2018. DTE Energy hadhas 0t accrued noany penalties pertaining to income taxes. Accrued interest pertaining to income taxes for DTE Electric totaled $6 million and $5 million at December 31, 20192020 and 2018, respectively.2019. DTE Electric recognized interest expense related to income taxes of a nominal amount in 2020 and $1 million in 2019 and 2018, and a nominal amount in 2017.2018. DTE Electric hadhas 0t accrued noany penalties pertaining to income taxes. In 2019,2020, DTE Energy, including DTE Electric, settled a federal tax audit for the 20172018 tax year. DTE Energy's federal income tax returns for 20182019 and subsequent years remain subject to examination by the IRS. DTE Energy's Michigan Business Tax returns for the years 2008-2011 and Michigan Corporate Income Tax returns for the year 2015 and subsequent years remain subject to examination by the State of Michigan. DTE Energy also files tax returns in numerous state and local jurisdictions with varying statutes of limitation.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) NOTE 12 — COMMON STOCK AND EARNINGS PER SHARE Common Stock
On October 1, 2019, DTE Energy issued approximately 5.87 million shares of common stock under the stock repurchase contracts associated with DTE Energy's 2016 Series C Equity Units for $675 million. Refer to Note 15 to the Consolidated Financial Statements, "Long-Term Debt" for additional information.
In conjunction with the acquisition of Blue Union and LEAP, in November 2019 DTE Energy issued 2.76 million shares of common stock at $126.00 per share grossing $348 million. Net proceeds from the offering were approximately $339 million. Refer to Note 4 to the Consolidated Financial Statements, "Acquisitions" for additional information.
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, performance shares, and stock options do not receive cash dividends; as such, these awards are not considered participating securities. For additional information, see Notes 15 and 22 to the Consolidated Financial Statements, "Long-Term Debt" and "Stock-Based Compensation," respectively.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
The following is a reconciliation of DTE Energy's basic and diluted income per share calculation for the years ended December 31: | | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | (In millions, except per share amounts) | | Basic Earnings per Share | | | | | | | Net Income Attributable to DTE Energy Company | $ | 1,368 | | | $ | 1,169 | | | $ | 1,120 | | | Less: Allocation of earnings to net restricted stock awards | (2) | | | (2) | | | (2) | | | Net income available to common shareholders — basic | $ | 1,366 | | | $ | 1,167 | | | $ | 1,118 | | | | | | | | | Average number of common shares outstanding — basic | 193 | | | 185 | | | 181 | | | Basic Earnings per Common Share | $ | 7.09 | | | $ | 6.32 | | | $ | 6.18 | | | | | | | | | Diluted Earnings per Share | | | | | | | Net Income Attributable to DTE Energy Company | $ | 1,368 | | | $ | 1,169 | | | $ | 1,120 | | | Less: Allocation of earnings to net restricted stock awards | (2) | | | (2) | | | (2) | | | Net income available to common shareholders — diluted | $ | 1,366 | | | $ | 1,167 | | | $ | 1,118 | | | | | | | | | | | | | | | | | | | | | | | | | | | Average number of common shares outstanding - diluted | 193 | | | 185 | | | 181 | | Diluted Earnings per Common Share(a) | $ | 7.08 | | | $ | 6.31 | | | $ | 6.17 | |
(a)Equity Units excluded from the calculation of diluted EPS were approximately 10.3 million for the years ended December 31, 2020 and 2019, respectively, and 6.3 million for the year ended December 31, 2018, as the dilutive stock price threshold was not met. For more information, see Note 15 to the Consolidated Financial Statements, "Long-Term Debt."
| | | | | | | | | | | | | | | 2019 | | 2018 | | 2017 | | | (In millions, except per share amounts) | | Basic Earnings per Share | | | | | | | Net Income Attributable to DTE Energy Company | $ | 1,169 |
| | $ | 1,120 |
| | $ | 1,134 |
| | Less: Allocation of earnings to net restricted stock awards | (2 | ) | | (2 | ) | | (2 | ) | | Net income available to common shareholders — basic | $ | 1,167 |
| | $ | 1,118 |
| | $ | 1,132 |
| | | | | | | | | Average number of common shares outstanding — basic | 185 |
| | 181 |
| | 179 |
| | Basic Earnings per Common Share | $ | 6.32 |
| | $ | 6.18 |
| | $ | 6.32 |
| | | | | | | | | Diluted Earnings per Share | | | | | | | Net Income Attributable to DTE Energy Company | $ | 1,169 |
| | $ | 1,120 |
| | $ | 1,134 |
| | Less: Allocation of earnings to net restricted stock awards | (2 | ) | | (2 | ) | | (2 | ) | | Net income available to common shareholders — diluted | $ | 1,167 |
| | $ | 1,118 |
| | $ | 1,132 |
| | | | | | | | | Average number of common shares outstanding - diluted | 185 |
| | 181 |
| | 179 |
| Diluted Earnings per Common Share(a) | $ | 6.31 |
| | $ | 6.17 |
| | $ | 6.32 |
|
| | (a) | Equity Units excluded from the calculation of diluted EPS were approximately 9.9 million for the year ended December 31, 2019 and 6.3 million for the years ended December 31, 2018 and 2017, as the dilutive stock price threshold was not met. For more information, see Note 15 to the Consolidated Financial Statements, "Long-Term Debt." |
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) NOTE 13 — FAIR VALUE Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable inputs. The Registrants make certain assumptions they believe that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. Credit risk of the Registrants and their counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at December 31, 20192020 and 2018.2019. 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. • — 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. |
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
The following table presents assets and liabilities for DTE Energy measured and recorded at fair value on a recurring basis(a): | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | December 31, 2020 | | December 31, 2019 | | Level 1 | | Level 2 | | Level 3 | | Other(b) | | Netting(c) | | Net Balance | | Level 1 | | Level 2 | | Level 3 | | Other(b) | | Netting(c) | | Net Balance | | (In millions) | | Assets | | | | | | | | | | | | | | | | | | | | | | | | Cash equivalents(d) | $ | 438 | | | $ | 0 | | | $ | 0 | | | $ | — | | | $ | — | | | $ | 438 | | | $ | 15 | | | $ | 0 | | | $ | 0 | | | $ | — | | | $ | — | | | $ | 15 | | | Nuclear decommissioning trusts | | | | | | | | | | | | | | | | | | | | | | | | | Equity securities | 947 | | | 0 | | | 0 | | | 222 | | | — | | | 1,169 | | | 1,046 | | | 0 | | | 0 | | | 0 | | | — | | | 1,046 | | | Fixed income securities | 102 | | | 371 | | | 0 | | | 82 | | | — | | | 555 | | | 160 | | | 378 | | | 0 | | | 0 | | | — | | | 538 | | | Private equity and other | 0 | | | 0 | | | 0 | | | 104 | | | — | | | 104 | | | 0 | | | 0 | | | 0 | | | 43 | | | — | | | 43 | | | Cash equivalents | 27 | | | 0 | | | 0 | | | — | | | — | | | 27 | | | 34 | | | 0 | | | 0 | | | — | | | — | | | 34 | | Other investments(e) | | | | | | | | | | | | | | | | | | | | | | | | | Equity securities | 55 | | | 0 | | | 0 | | | — | | | — | | | 55 | | | 140 | | | 0 | | | 0 | | | — | | | — | | | 140 | | | Fixed income securities | 8 | | | 0 | | | 0 | | | — | | | — | | | 8 | | | 79 | | | 0 | | | 0 | | | — | | | — | | | 79 | | | Cash equivalents | 97 | | | 0 | | | 0 | | | — | | | — | | | 97 | | | 4 | | | 0 | | | 0 | | | — | | | — | | | 4 | | | | | | | | | | | | | | | | | | | | | | | | | | | Derivative assets | | | | | | | | | | | | | | | | | | | | | | | | Commodity contracts(f) | | | | | | | | | | | | | | | | | | | | | | | | | Natural gas | 99 | | | 74 | | | 60 | | | — | | | (156) | | | 77 | | | 205 | | | 76 | | | 74 | | | — | | | (266) | | | 89 | | | Electricity | 0 | | | 128 | | | 52 | | | — | | | (120) | | | 60 | | | 0 | | | 223 | | | 83 | | | — | | | (225) | | | 81 | | | Environmental & Other | 0 | | | 150 | | | 4 | | | — | | | (135) | | | 19 | | | 0 | | | 110 | | | 3 | | | — | | | (110) | | | 3 | | | Foreign currency exchange contracts | 0 | | | 0 | | | 0 | | | — | | | 0 | | | 0 | | | 0 | | | 1 | | | 0 | | | — | | | 0 | | | 1 | | | Total derivative assets | 99 | | | 352 | | | 116 | | | — | | | (411) | | | 156 | | | 205 | | | 410 | | | 160 | | | — | | | (601) | | | 174 | | | Total | $ | 1,773 | | | $ | 723 | | | $ | 116 | | | $ | 408 | | | $ | (411) | | | $ | 2,609 | | | $ | 1,683 | | | $ | 788 | | | $ | 160 | | | $ | 43 | | | $ | (601) | | | $ | 2,073 | | | | | | | | | | | | | | | | | | | | | | | | | | | Liabilities | | | | | | | | | | | | | | | | | | | | | | | | | Derivative liabilities | | | | | | | | | | | | | | | | | | | | | | | | Commodity contracts(f) | | | | | | | | | | | | | | | | | | | | | | | | | Natural gas | $ | (88) | | | $ | (59) | | | $ | (76) | | | $ | — | | | $ | 151 | | | $ | (72) | | | $ | (221) | | | $ | (41) | | | $ | (89) | | | $ | — | | | $ | 266 | | | $ | (85) | | | Electricity | 0 | | | (126) | | | (42) | | | — | | | 125 | | | (43) | | | 0 | | | (231) | | | (67) | | | — | | | 225 | | | (73) | | | Environmental & Other | 0 | | | (137) | | | 0 | | | — | | | 129 | | | (8) | | | 0 | | | (121) | | | 0 | | | — | | | 110 | | | (11) | | | | | | | | | | | | | | | | | | | | | | | | | | | Foreign currency exchange contracts | 0 | | | (5) | | | 0 | | | — | | | 0 | | | (5) | | | 0 | | | 0 | | | 0 | | | — | | | 0 | | | 0 | | | | | | | | | | | | | | | | | | | | | | | | | | | Total | $ | (88) | | | $ | (327) | | | $ | (118) | | | $ | — | | | $ | 405 | | | $ | (128) | | | $ | (221) | | | $ | (393) | | | $ | (156) | | | $ | — | | | $ | 601 | | | $ | (169) | | | Net Assets (Liabilities) at end of period | $ | 1,685 | | | $ | 396 | | | $ | (2) | | | $ | 408 | | | $ | (6) | | | $ | 2,481 | | | $ | 1,462 | | | $ | 395 | | | $ | 4 | | | $ | 43 | | | $ | 0 | | | $ | 1,904 | | | Assets | | | | | | | | | | | | | | | | | | | | | | | | | Current | $ | 532 | | | $ | 260 | | | $ | 92 | | | $ | — | | | $ | (330) | | | $ | 554 | | | $ | 218 | | | $ | 320 | | | $ | 123 | | | $ | — | | | $ | (513) | | | $ | 148 | | | Noncurrent | 1,241 | | | 463 | | | 24 | | | 408 | | | (81) | | | 2,055 | | | 1,465 | | | 468 | | | 37 | | | 43 | | | (88) | | | 1,925 | | | Total Assets | $ | 1,773 | | | $ | 723 | | | $ | 116 | | | $ | 408 | | | $ | (411) | | | $ | 2,609 | | | $ | 1,683 | | | $ | 788 | | | $ | 160 | | | $ | 43 | | | $ | (601) | | | $ | 2,073 | | | Liabilities | | | | | | | | | | | | | | | | | | | | | | | | | Current | $ | (84) | | | $ | (223) | | | $ | (79) | | | $ | — | | | $ | 318 | | | $ | (68) | | | $ | (211) | | | $ | (300) | | | $ | (85) | | | $ | — | | | $ | 513 | | | $ | (83) | | | Noncurrent | (4) | | | (104) | | | (39) | | | — | | | 87 | | | (60) | | | (10) | | | (93) | | | (71) | | | — | | | 88 | | | (86) | | | Total Liabilities | $ | (88) | | | $ | (327) | | | $ | (118) | | | $ | — | | | $ | 405 | | | $ | (128) | | | $ | (221) | | | $ | (393) | | | $ | (156) | | | $ | — | | | $ | 601 | | | $ | (169) | | | Net Assets (Liabilities) at end of period | $ | 1,685 | | | $ | 396 | | | $ | (2) | | | $ | 408 | | | $ | (6) | | | $ | 2,481 | | | $ | 1,462 | | | $ | 395 | | | $ | 4 | | | $ | 43 | | | $ | 0 | | | $ | 1,904 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | December 31, 2019 | | December 31, 2018 | | | Level 1 | | Level 2 | | Level 3 | | Other(b) | | Netting(c) | | Net Balance | | Level 1 | | Level 2 | | Level 3 | | Other(b) | | Netting(c) | | Net Balance | | | (In millions) | | Assets | | | | | | | | | | | | | | | | | | | | | | | | Cash equivalents(d) | $ | 15 |
| | $ | — |
| | $ | — |
| | $ | — |
| | $ | — |
| | $ | 15 |
| | $ | 16 |
| | $ | 2 |
| | $ | — |
| | $ | — |
| | $ | — |
| | $ | 18 |
| | Nuclear decommissioning trusts | | | | | | | | | | | | | | | | | | | | | | | | | Equity securities | 1,046 |
| | — |
| | — |
| | — |
| | — |
| | 1,046 |
| | 851 |
| | — |
| | — |
| | — |
| | — |
| | 851 |
| | Fixed income securities | 160 |
| | 378 |
| | — |
| | — |
| | — |
| | 538 |
| | 12 |
| | 490 |
| | — |
| | — |
| | — |
| | 502 |
| | Private equity and other | — |
| | — |
| | — |
| | 43 |
| | — |
| | 43 |
| | — |
| | — |
| | — |
| | 20 |
| | — |
| | 20 |
| | Cash equivalents | 34 |
| | — |
| | — |
| | — |
| | — |
| | 34 |
| | 5 |
| | — |
| | — |
| | — |
| | — |
| | 5 |
| Other investments(e) | | | | | | | | | | |
|
| | | | | | | | | | | |
|
| | Equity securities | 140 |
| | — |
| | — |
| | — |
| | — |
| | 140 |
| | 110 |
| | — |
| | — |
| | — |
| | — |
| | 110 |
| | Fixed income securities | 79 |
| | — |
| | — |
| | — |
| | — |
| | 79 |
| | 69 |
| | — |
| | — |
| | — |
| | — |
| | 69 |
| | Cash equivalents | 4 |
| | — |
| | — |
| | — |
| | — |
| | 4 |
| | 4 |
| | — |
| | — |
| | — |
| | — |
| | 4 |
| | Derivative assets | | | | | | | | | | | | | | | | | | | | | | | | | Commodity contracts | | | | | | | | | | | | | | | | | | | | | | | | | Natural gas | 205 |
| | 76 |
| | 74 |
| | — |
| | (266 | ) | | 89 |
| | 199 |
| | 87 |
| | 63 |
| | — |
| | (277 | ) | | 72 |
| | Electricity | — |
| | 223 |
| | 83 |
| | — |
| | (225 | ) | | 81 |
| | — |
| | 247 |
| | 56 |
| | — |
| | (252 | ) | | 51 |
| | Environmental & Other | — |
| | 110 |
| | 3 |
| | — |
| | (110 | ) | | 3 |
| | — |
| | — |
| | 7 |
| | — |
| | (1 | ) | | 6 |
| | Foreign currency exchange contracts | — |
| | 1 |
| | — |
| | — |
| | — |
| | 1 |
| | — |
| | 4 |
| | — |
| | — |
| | — |
| | 4 |
| | Total derivative assets | 205 |
| | 410 |
| | 160 |
| | — |
| | (601 | ) | | 174 |
| | 199 |
| | 338 |
| | 126 |
| | — |
| | (530 | ) | | 133 |
| | Total | $ | 1,683 |
| | $ | 788 |
| | $ | 160 |
| | $ | 43 |
| | $ | (601 | ) | | $ | 2,073 |
| | $ | 1,266 |
| | $ | 830 |
| | $ | 126 |
| | $ | 20 |
| | $ | (530 | ) | | $ | 1,712 |
| | | | | | | | | | | | | | | | | | | | | | | | | | | Liabilities | | | | | | | | | | | | | | | | | | | | | | | | | Derivative liabilities | | | | | | | | | | | | | | | | | | | | | | | | | Commodity contracts | | | | | | | | | | | | | | | | | | | | | | | | | Natural gas | $ | (221 | ) | | $ | (41 | ) | | $ | (89 | ) | | $ | — |
| | $ | 266 |
| | $ | (85 | ) | | $ | (197 | ) | | $ | (71 | ) | | $ | (112 | ) | | $ | — |
| | $ | 272 |
| | $ | (108 | ) | | Electricity | — |
| | (231 | ) | | (67 | ) | | — |
| | 225 |
| | (73 | ) | | — |
| | (227 | ) | | (58 | ) | | — |
| | 240 |
| | (45 | ) | | Environmental & Other | — |
| | (121 | ) | | — |
| | — |
| | 110 |
| | (11 | ) | | — |
| | (1 | ) | | — |
| | — |
| | 1 |
| | — |
| | Interest rate contracts | — |
| | — |
| | — |
| | — |
| | — |
| | — |
| | — |
| | (3 | ) | | — |
| | — |
| | — |
| | (3 | ) | | Total | $ | (221 | ) | | $ | (393 | ) | | $ | (156 | ) | | $ | — |
| | $ | 601 |
| | $ | (169 | ) | | $ | (197 | ) | | $ | (302 | ) | | $ | (170 | ) | | $ | — |
| | $ | 513 |
| | $ | (156 | ) | | Net Assets (Liabilities) at end of period | $ | 1,462 |
| | $ | 395 |
| | $ | 4 |
| | $ | 43 |
| | $ | — |
| | $ | 1,904 |
| | $ | 1,069 |
| | $ | 528 |
| | $ | (44 | ) | | $ | 20 |
| | $ | (17 | ) | | $ | 1,556 |
| | Assets | | | | | | | | | | | | | | | | | | | | | | | | | Current | $ | 218 |
| | $ | 320 |
| | $ | 123 |
| | $ | — |
| | $ | (513 | ) | | $ | 148 |
| | $ | 212 |
| | $ | 273 |
| | $ | 96 |
| | $ | — |
| | $ | (461 | ) | | $ | 120 |
| | Noncurrent | 1,465 |
| | 468 |
| | 37 |
| | 43 |
| | (88 | ) | | 1,925 |
| | 1,054 |
| | 557 |
| | 30 |
| | 20 |
| | (69 | ) | | 1,592 |
| | Total Assets | $ | 1,683 |
| | $ | 788 |
| | $ | 160 |
| | $ | 43 |
| | $ | (601 | ) | | $ | 2,073 |
| | $ | 1,266 |
| | $ | 830 |
| | $ | 126 |
| | $ | 20 |
| | $ | (530 | ) | | $ | 1,712 |
| | Liabilities | | | | | | | | | | | | | | | | | | | | | | | | | Current | $ | (211 | ) | | $ | (300 | ) | | $ | (85 | ) | | $ | — |
| | $ | 513 |
| | $ | (83 | ) | | $ | (191 | ) | | $ | (251 | ) | | $ | (76 | ) | | $ | — |
| | $ | 451 |
| | $ | (67 | ) | | Noncurrent | (10 | ) | | (93 | ) | | (71 | ) | | — |
| | 88 |
| | (86 | ) | | (6 | ) | | (51 | ) | | (94 | ) | | — |
| | 62 |
| | (89 | ) | | Total Liabilities | $ | (221 | ) | | $ | (393 | ) | | $ | (156 | ) | | $ | — |
| | $ | 601 |
| | $ | (169 | ) | | $ | (197 | ) | | $ | (302 | ) | | $ | (170 | ) | | $ | — |
| | $ | 513 |
| | $ | (156 | ) | | Net Assets (Liabilities) at end of period | $ | 1,462 |
| | $ | 395 |
| | $ | 4 |
| | $ | 43 |
| | $ | — |
| | $ | 1,904 |
| | $ | 1,069 |
| | $ | 528 |
| | $ | (44 | ) | | $ | 20 |
| | $ | (17 | ) | | $ | 1,556 |
|
| | (a) | See footnotes on following page. |
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
| | (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 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. At December 31, 2018, the $18 million consisted of $3 million, $5 million, and $10 million of cash equivalents included in Cash and Cash equivalents, Restricted cash, and Other investments on DTE Energy's Consolidated Statements of Financial Position, respectively. |
| | (e) | Excludes cash surrender value of life insurance investments. |
(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 December 31, 2020, the $438 million consisted of $436 million and $2 million of cash equivalents included in Cash and cash equivalents and Restricted cash, respectively, on DTE Energy's Consolidated Statements of Financial Position. 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, respectively, on DTE Energy's Consolidated Statements of Financial Position. (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: | | | | December 31, 2019 | | December 31, 2018 | | December 31, 2020 | | December 31, 2019 | | | Level 1 | | Level 2 | | Level 3 | | Other(a) | | Net Balance | | Level 1 | | Level 2 | | Level 3 | | Other(a) | Net Balance | | Level 1 | | Level 2 | | Level 3 | | Other(a) | | Net Balance | | Level 1 | | Level 2 | | Level 3 | | Other(a) | Net Balance | | | (In millions) | | (In millions) | | Assets | | | | | | | | | | | | | | | | | | Assets | | Cash equivalents(b) | $ | 11 |
| | $ | — |
| | $ | — |
| | $ | — |
| | $ | 11 |
| | $ | 8 |
| | $ | 2 |
| | $ | — |
| | $ | — |
| $ | 10 |
| Cash equivalents(b) | $ | 4 | | | $ | 0 | | | $ | 0 | | | $ | — | | | $ | 4 | | | $ | 11 | | | $ | 0 | | | $ | 0 | | | $ | — | | $ | 11 | | | Nuclear decommissioning trusts | | | | | | | | | | | | | | | | | | Nuclear decommissioning trusts | | | Equity securities | 1,046 |
| | — |
| | — |
| | — |
| | 1,046 |
| | 851 |
| | — |
| | — |
| | — |
| 851 |
| Equity securities | 947 | | | 0 | | | 0 | | | 222 | | | 1,169 | | | 1,046 | | | 0 | | | 0 | | | 0 | | 1,046 | | | Fixed income securities | 160 |
| | 378 |
| | — |
| | — |
| | 538 |
| | 12 |
| | 490 |
| | — |
| | — |
| 502 |
| Fixed income securities | 102 | | | 371 | | | 0 | | | 82 | | | 555 | | | 160 | | | 378 | | | 0 | | | 0 | | 538 | | | Private equity and other | — |
| | — |
| | — |
| | 43 |
| | 43 |
| | — |
| | — |
| | — |
| | 20 |
| 20 |
| Private equity and other | 0 | | | 0 | | | 0 | | | 104 | | | 104 | | | 0 | | | 0 | | | 0 | | | 43 | | 43 | | | Cash equivalents | 34 |
| | — |
| | — |
| | — |
| | 34 |
| | 5 |
| | — |
| | — |
| | — |
| 5 |
| Cash equivalents | 27 | | | 0 | | | 0 | | | — | | | 27 | | | 34 | | | 0 | | | 0 | | | — | | 34 | | | Other investments | | | | | | | | | | | | | | | | | | Other investments | | | Equity securities | 13 |
| | — |
| | — |
| | — |
| | 13 |
| | 10 |
| | — |
| | — |
| | — |
| 10 |
| Equity securities | 16 | | | 0 | | | 0 | | | — | | | 16 | | | 13 | | | 0 | | | 0 | | | — | | 13 | | | Fixed income securities | | Fixed income securities | 11 | | | 0 | | | 0 | | | — | | | 11 | | | 0 | | | 0 | | | 0 | | | — | | 0 | | | | Derivative assets — FTRs | — |
| | — |
| | 3 |
| | — |
| | 3 |
| | — |
| | — |
| | 6 |
| | — |
| 6 |
| Derivative assets — FTRs | 0 | | | 0 | | | 4 | | | — | | | 4 | | | 0 | | | 0 | | | 3 | | | — | | 3 | | | Total | $ | 1,264 |
| | $ | 378 |
| | $ | 3 |
| | $ | 43 |
| | $ | 1,688 |
| | $ | 886 |
| | $ | 492 |
| | $ | 6 |
| | $ | 20 |
| $ | 1,404 |
| Total | $ | 1,107 | | | $ | 371 | | | $ | 4 | | | $ | 408 | | | $ | 1,890 | | | $ | 1,264 | | | $ | 378 | | | $ | 3 | | | $ | 43 | | $ | 1,688 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | Assets | | | | | | | | | | | | | | | | | | Assets | | | Current | $ | 11 |
| | $ | — |
| | $ | 3 |
| | $ | — |
| | $ | 14 |
| | $ | 8 |
| | $ | 2 |
| | $ | 6 |
| | $ | — |
| $ | 16 |
| Current | $ | 4 | | | $ | 0 | | | $ | 4 | | | $ | — | | | $ | 8 | | | $ | 11 | | | $ | 0 | | | $ | 3 | | | $ | — | | $ | 14 | | | Noncurrent | 1,253 |
| | 378 |
| | — |
| | 43 |
| | 1,674 |
| | 878 |
| | 490 |
| | — |
| | 20 |
| 1,388 |
| Noncurrent | 1,103 | | | 371 | | | 0 | | | 408 | | | 1,882 | | | 1,253 | | | 378 | | | 0 | | | 43 | | 1,674 | | | Total Assets | $ | 1,264 |
| | $ | 378 |
| | $ | 3 |
| | $ | 43 |
| | $ | 1,688 |
| | $ | 886 |
| | $ | 492 |
| | $ | 6 |
| | $ | 20 |
| $ | 1,404 |
| Total Assets | $ | 1,107 | | | $ | 371 | | | $ | 4 | | | $ | 408 | | | $ | 1,890 | | | $ | 1,264 | | | $ | 378 | | | $ | 3 | | | $ | 43 | | $ | 1,688 | |
| | (a) | Amounts represent assets valued at NAV as a practical expedient for fair value. |
| | (b) | At December 31, 2019, the $11 million consisted of cash equivalents included in Other investments on DTE Electric's Consolidated Statements of Financial Position. At December 31, 2018, the $10 million consisted of cash equivalents included in Other investments on DTE Electric's Consolidated Statements of Financial Position. |
(a)Amounts represent assets valued at NAV as a practical expedient for fair value. (b)At December 31, 2020, the $4 million consisted of cash equivalents included in Cash and cash equivalents on DTE Electric's Consolidated Statements of Financial Position. At December 31, 2019, the $11 million consisted of cash equivalents 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. Commingled funds that hold exchange-traded equity or debt securities are valued based on stated NAVs. Non-exchange traded fixed income securities are valued based upon quotations available from brokers or pricing services. Other 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.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) Private equity and other assets such as private equity investmentsinclude a diversified group of funds that are classified as NAV assets. AThese 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 $183 million and $151 million as of December 31, 2020 and 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 price 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.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
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.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) The following table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for DTE Energy: | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | Year Ended December 31, 2020 | | Year Ended December 31, 2019 | | Natural Gas | | Electricity | | Other | | Total | | Natural Gas | | Electricity | | Other | | Total | | (In millions) | | Net Assets (Liabilities) as of January 1 | $ | (15) | | | $ | 16 | | | $ | 3 | | | $ | 4 | | | $ | (49) | | | $ | (2) | | | $ | 7 | | | $ | (44) | | | | | | | | | | | | | | | | | | | Transfers from Level 3 into Level 2 | (2) | | | 0 | | | 0 | | | (2) | | | 0 | | | 0 | | | 0 | | | 0 | | | Total gains (losses) | | | | | | | | | | | | | | | | | Included in earnings | (75) | | | 113 | | | (7) | | | 31 | | | 15 | | | 77 | | | (1) | | | 91 | | | Recorded in Regulatory liabilities | 0 | | | 0 | | | 20 | | | 20 | | | 0 | | | 0 | | | 2 | | | 2 | | | Purchases, issuances, and settlements: | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | Settlements | 76 | | | (119) | | | (12) | | | (55) | | | 19 | | | (59) | | | (5) | | | (45) | | | Net Assets (Liabilities) as of December 31 | $ | (16) | | | $ | 10 | | | $ | 4 | | | $ | (2) | | | $ | (15) | | | $ | 16 | | | $ | 3 | | | $ | 4 | | Total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31(a) | $ | (4) | | | $ | 70 | | | $ | (70) | | | $ | (4) | | | $ | (1) | | | $ | 59 | | | $ | (38) | | | $ | 20 | | | Total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31 | $ | 0 | | | $ | 0 | | | $ | 4 | | | $ | 4 | | | $ | 0 | | | $ | 0 | | | $ | 3 | | | $ | 3 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | Year Ended December 31, 2019 | | Year Ended December 31, 2018 | | | Natural Gas | | Electricity | | Other | | Total | | Natural Gas | | Electricity | | Other | | Total | | | (In millions) | | Net Assets (Liabilities) as of January 1 | $ | (49 | ) | | $ | (2 | ) | | $ | 7 |
| | $ | (44 | ) | | $ | (29 | ) | | $ | 12 |
| | $ | 8 |
| | $ | (9 | ) | | Transfers from Level 3 into Level 2 | — |
| | — |
| | — |
| | — |
| | (3 | ) | | — |
| | — |
| | (3 | ) | | Total gains (losses) | | | | | | | | | | | | | | | | | Included in earnings | 15 |
| | 77 |
| | (1 | ) | | 91 |
| | (146 | ) | | 29 |
| | 1 |
| | (116 | ) | | Recorded in Regulatory liabilities | — |
| | — |
| | 2 |
| | 2 |
| | — |
| | — |
| | 9 |
| | 9 |
| | Purchases, issuances, and settlements: | | | | | | | | | | | | | | | | | Settlements | 19 |
| | (59 | ) | | (5 | ) | | (45 | ) | | 129 |
| | (43 | ) | | (11 | ) | | 75 |
| | Net Assets (Liabilities) as of December 31 | $ | (15 | ) | | $ | 16 |
| | $ | 3 |
| | $ | 4 |
| | $ | (49 | ) | | $ | (2 | ) | | $ | 7 |
| | $ | (44 | ) | | The amount of total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2019 and 2018 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations | $ | (1 | ) | | $ | 59 |
| | $ | (38 | ) | | $ | 20 |
| | $ | (119 | ) | | $ | 15 |
| | $ | (16 | ) | | $ | (120 | ) |
The following table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for DTE Electric: | | | | | | | | | | | Year Ended December 31, | | | 2019 | | 2018 | | | (In millions) | | Net Assets as of January 1 | $ | 6 |
| | $ | 9 |
| | Change in fair value recorded in Regulatory liabilities | 2 |
| | 9 |
| | Purchases, issuances, and settlements: | | | | | Settlements | (5 | ) | | (12 | ) | | Net Assets as of December 31 | $ | 3 |
| | $ | 6 |
| | The amount of total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2019 and 2018 and reflected in DTE Electric's Consolidated Statements of Financial Position | $ | 3 |
| | $ | 6 |
|
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
| | | | | | | | | | | | | Year Ended December 31, | | 2020 | | 2019 | | (In millions) | | Net Assets as of January 1 | $ | 3 | | | $ | 6 | | | Change in fair value recorded in Regulatory liabilities | 20 | | | 2 | | | Purchases, issuances, and settlements: | | | | | Settlements | (19) | | | (5) | | | Net Assets as of December 31 | $ | 4 | | | $ | 3 | | | Total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31 | $ | 4 | | | $ | 3 | |
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 between Levels 1 and 2 for the Registrants during the years ended December 31, 2019 and 2018, and there were no transfers from or into Level 3 for DTE Electric during the same periods.years ended December 31, 2020 and 2019. The following tables present the unobservable inputs related to DTE Energy's Level 3 assets and liabilities: | | | | | December 31, 2019 | | | | | | | | December 31, 2020 | | | Commodity Contracts | | Derivative Assets | | Derivative Liabilities | | Valuation Techniques | | Unobservable Input | | Range | | Weighted Average | Commodity Contracts | | Derivative Assets | | Derivative Liabilities | | Valuation Techniques | | Unobservable Input | | Range | | Weighted Average | | | | (In millions) | | | | | | | | | (In millions) | | | | | | | | | | Natural Gas | | $ | 74 |
| | $ | (89 | ) | | Discounted Cash Flow | | Forward basis price (per MMBtu) | | $ | (1.78 | ) | — | | $ | 5.78 | /MMBtu | | $ | (0.09 | )/MMBtu | Natural Gas | | $ | 60 | | | $ | (76) | | | Discounted Cash Flow | | Forward basis price (per MMBtu) | | $ | (0.86) | | — | | $ | 2.50 | /MMBtu | | $ | (0.07) | /MMBtu | | Electricity | | $ | 83 |
| | $ | (67 | ) | | Discounted Cash Flow | | Forward basis price (per MWh) | | $ | (10 | ) | — | | $ | 6 | /MWh | | $ | — |
| Electricity | | $ | 52 | | | $ | (42) | | | Discounted Cash Flow | | Forward basis price (per MWh) | | $ | (9) | | — | | $ | 6 | /MWh | | $ | 0 | /MWh |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | December 31, 2018 | | | | | | | | | | | | | Commodity Contracts | | Derivative Assets | | Derivative Liabilities | | Valuation Techniques | | Unobservable Input | | Range | | Weighted Average | | | | (In millions) | | | | | | | | | | | | | Natural Gas | | $ | 63 |
| | $ | (112 | ) | | Discounted Cash Flow | | Forward basis price (per MMBtu) | | $ | (2.15 | ) | — | | $ | 5.59 | /MMBtu | | $ | (0.10 | )/MMBtu | | Electricity | | $ | 56 |
| | $ | (58 | ) | | Discounted Cash Flow | | Forward basis price (per MWh) | | $ | (7 | ) | — | | $ | 9 | /MWh | | $ | 1 | /MWh |
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | 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 | | $ | 0 | /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 resulthave resulted in a higher (lower) fair value for long positions, with offsetting impacts to short positions. Fair Value of Financial Instruments The following table presents the carrying amount and fair value of financial instruments for DTE Energy: | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | December 31, 2019 | | December 31, 2018 | | | 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 | $ | 184 |
| | $ | — |
| | $ | — |
| | $ | 184 |
| | $ | 40 |
| | $ | — |
| | $ | — |
| | $ | 40 |
| | Dividends payable | $ | 195 |
| | $ | 195 |
| | $ | — |
| | $ | — |
| | $ | 172 |
| | $ | 172 |
| | $ | — |
| | $ | — |
| | Short-term borrowings | $ | 828 |
| | $ | — |
| | $ | 828 |
| | $ | — |
| | $ | 609 |
| | $ | — |
| | $ | 609 |
| | $ | — |
| Notes payable — Other(b), excluding lessee finance leases | $ | 25 |
| | $ | — |
| | $ | — |
| | $ | 25 |
| | $ | 41 |
| | $ | — |
| | $ | — |
| | $ | 41 |
| Long-term debt(c) | $ | 16,606 |
| | $ | 2,572 |
| | $ | 14,207 |
| | $ | 1,252 |
| | $ | 13,622 |
| | $ | 1,796 |
| | $ | 10,712 |
| | $ | 1,317 |
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | December 31, 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(a), excluding lessor finance leases | $ | 141 | | | $ | 0 | | | $ | 0 | | | $ | 141 | | | $ | 184 | | | $ | 0 | | | $ | 0 | | | $ | 184 | | | Short-term borrowings | $ | 38 | | | $ | 0 | | | $ | 38 | | | $ | 0 | | | $ | 828 | | | $ | 0 | | | $ | 828 | | | $ | 0 | | Notes payable(b) | $ | 19 | | | $ | 0 | | | $ | 0 | | | $ | 19 | | | $ | 25 | | | $ | 0 | | | $ | 0 | | | $ | 25 | | Long-term debt(c) | $ | 19,439 | | | $ | 2,547 | | | $ | 18,230 | | | $ | 1,397 | | | $ | 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. |
(b)Included in Current Liabilities — Other and Other Liabilities — Other on DTE Energy Company — DTE Electric CompanyEnergy's Consolidated Statements of Financial Position. Combined Notes to Consolidated Financial Statements — (Continued)
The following table presents the carrying amount and fair value of financial instruments for DTE Electric: | | | | | | | | | | | | | | | | | | | | December 31, 2020 | | December 31, 2019 | | | December 31, 2019 | | December 31, 2018 | | Carrying | | Fair Value | | Carrying | | Fair Value | | | Carrying | | Fair Value | | Carrying | | Fair Value | | Amount | | Level 1 | | Level 2 | | Level 3 | | Amount | | Level 1 | | Level 2 | | Level 3 | | | Amount | | Level 1 | | Level 2 | | Level 3 | | Amount | | Level 1 | | Level 2 | | Level 3 | | (In millions) | | | (In millions) | | Notes receivable — Other(a), excluding lessor finance leases | $ | 9 |
| | $ | — |
| | $ | — |
| | $ | 9 |
| | $ | 6 |
| | $ | — |
| | $ | — |
| | $ | 6 |
| | Notes receivable — Other(a) | | Notes receivable — Other(a) | $ | 16 | | | $ | 0 | | | $ | 0 | | | $ | 16 | | | $ | 9 | | | $ | 0 | | | $ | 0 | | | $ | 9 | | | Short-term borrowings — affiliates | $ | 97 |
| | $ | — |
| | $ | — |
| | $ | 97 |
| | $ | 101 |
| | $ | — |
| | $ | — |
| | $ | 101 |
| Short-term borrowings — affiliates | $ | 101 | | | $ | 0 | | | $ | 0 | | | $ | 101 | | | $ | 97 | | | $ | 0 | | | $ | 0 | | | $ | 97 | | | Short-term borrowings — other | $ | 354 |
| | $ | — |
| | $ | 354 |
| | $ | — |
| | 149 |
| | $ | — |
| | $ | 149 |
| | $ | — |
| Short-term borrowings — other | $ | 0 | | | $ | 0 | | | $ | 0 | | | $ | 0 | | | 354 | | | $ | — | | | $ | 354 | | | $ | 0 | | Notes payable — Other(b), excluding lessee finance leases | $ | 21 |
| | $ | — |
| | $ | — |
| | $ | 21 |
| | $ | 21 |
| | $ | — |
| | $ | — |
| | $ | 21 |
| | Notes payable(b) | | Notes payable(b) | $ | 17 | | | $ | 0 | | | $ | 0 | | | $ | 17 | | | $ | 21 | | | $ | 0 | | | $ | 0 | | | $ | 21 | | Long-term debt(c) | $ | 7,180 |
| | $ | — |
| | $ | 7,916 |
| | $ | 173 |
| | $ | 6,538 |
| | $ | — |
| | $ | 6,552 |
| | $ | 161 |
| Long-term debt(c) | $ | 8,236 | | | $ | 0 | | | $ | 9,579 | | | $ | 379 | | | $ | 7,180 | | | $ | 0 | | | $ | 7,916 | | | $ | 173 | |
| | (a) | Included in Current 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. |
(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 14 to the Consolidated Financial Statements, "Financial and Other Derivative Instruments."
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) Nuclear Decommissioning Trust Funds DTE Electric has a legal obligation to decommission its nuclear power plants following the expiration of its operating licenses. This obligation is reflected as an Asset retirement obligation on DTE Electric's Consolidated Statements of Financial Position. Rates approved by the MPSC provide for the recovery of decommissioning costs of Fermi 2 and the disposal of low-level radioactive waste. See Note 9 to the Consolidated Financial Statements, "Asset Retirement Obligations." The following table summarizes DTE Electric's fair value of the nuclear decommissioning trust fund assets: | | | | | | | | | | | December 31, | | | 2019 | | 2018 | | | (In millions) | | Fermi 2 | $ | 1,650 |
| | $ | 1,372 |
| | Fermi 1 | 3 |
| | 3 |
| | Low-level radioactive waste | 8 |
| | 3 |
|
| $ | 1,661 |
| | $ | 1,378 |
|
| | | | | | | | | | | | | December 31, | | 2020 | | 2019 | | (In millions) | | Fermi 2 | $ | 1,841 | | | $ | 1,650 | | | Fermi 1 | 3 | | | 3 | | | Low-level radioactive waste | 11 | | | 8 | | | $ | 1,855 | | | $ | 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: | | | | | | | | | | | | | | | Year Ended December 31, | | | 2019 | | 2018 | | 2017 | | | (In millions) | | Realized gains | $ | 56 |
| | $ | 65 |
| | $ | 83 |
| | Realized losses | $ | (31 | ) | | $ | (42 | ) | | $ | (29 | ) | | Proceeds from sale of securities | $ | 788 |
| | $ | 1,203 |
| | $ | 1,240 |
|
| | | | | | | | | | | | | | | | | | | Year Ended December 31, | | 2020 | | 2019 | | 2018 | | (In millions) | | Realized gains | $ | 192 | | | $ | 56 | | | $ | 65 | | | Realized losses | $ | (111) | | | $ | (31) | | | $ | (42) | | | Proceeds from sale of securities | $ | 2,350 | | | $ | 788 | | | $ | 1,203 | |
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 assetassets and the Nuclear decommissioning liability. Realized gains and losses from the sale of securities and unrealized gains and losses on the low-level radioactive waste funds are recorded to the Nuclear decommissioning liability.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
The following table sets forth DTE Electric's fair value and unrealized gains and losses for the nuclear decommissioning trust funds: | | | | | | | | | | | | | | | | | | | | | | | | | | | December 31, 2019 | | December 31, 2018 | | | Fair
Value | | Unrealized
Gains | | Unrealized Losses | | Fair
Value | | Unrealized
Gains | | Unrealized Losses | | | (In millions) | | Equity securities | $ | 1,046 |
| | $ | 396 |
| | $ | (39 | ) | | $ | 851 |
| | $ | 235 |
| | $ | (79 | ) | | Fixed income securities | 538 |
| | 24 |
| | (1 | ) | | 502 |
| | 7 |
| | (8 | ) | | Private equity and other | 43 |
| | — |
| | — |
| | 20 |
| | — |
| | — |
| | Cash equivalents | 34 |
| | — |
| | — |
| | 5 |
| | — |
| | — |
| | | $ | 1,661 |
| | $ | 420 |
|
| $ | (40 | ) | | $ | 1,378 |
| | $ | 242 |
|
| $ | (87 | ) |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | December 31, 2020 | | December 31, 2019 | | Fair
Value | | Unrealized
Gains | | Unrealized Losses | | Fair
Value | | Unrealized
Gains | | Unrealized Losses | | (In millions) | | Equity securities | $ | 1,169 | | | $ | 481 | | | $ | (6) | | | $ | 1,046 | | | $ | 396 | | | $ | (39) | | | Fixed income securities | 555 | | | 20 | | | (1) | | | 538 | | | 24 | | | (1) | | | Private equity and other | 104 | | | — | | | — | | | 43 | | | — | | | — | | | Cash equivalents | 27 | | | — | | | — | | | 34 | | | — | | | — | | | $ | 1,855 | | | $ | 501 | | | $ | (7) | | | $ | 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: | | | | | | | December 31, 2020 | | (In millions) | | Due within one year | $ | 51 | | | Due after one through five years | 101 | | | Due after five through ten years | 89 | | | Due after ten years | 232 | | | $ | 473 | |
| | | | | | | December 31, 2019 | | | (In millions) | | Due within one year | $ | 15 |
| | Due after one through five years | 102 |
| | Due after five through ten years | 109 |
| | Due after ten years | 312 |
| | | $ | 538 |
|
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) Fixed income securities held in nuclear decommissioning trust funds include $82 million of non-publicly traded commingled funds that do not have a contractual maturity date. Other Securities At December 31, 20192020 and 2018,2019, the Registrants' securities included in Other investments on the Consolidated Statements of Financial Position were comprised primarily of moneyinvestments 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 equity securities. Net gains related to equity securities held at December 31, 2019 were $37 million. Net losses related to equity securities held at December 31, 2018 were $11 million and net gains related to equity securities held at December 31, 2017 were $26 million. Gains or losses related to the Rabbi Trust assets are allocated from DTE Energy to DTE Electric.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:
| | | | | | | | | | | | | | | | | | | Year Ended December 31, | | 2020 | | 2019 | | 2018 | | (In millions) | | Gains (losses) related to equity securities | $ | (1) | | | $ | 27 | | | $ | (8) | | | Gains (losses) related to fixed income securities | (2) | | | 10 | | | (3) | | | $ | (3) | | | $ | 37 | | | $ | (11) | |
NOTE 14 — FINANCIAL AND OTHER DERIVATIVE INSTRUMENTS The Registrants recognize all derivatives at their fair value as Derivative assets or liabilities on their respective Consolidated Statements of Financial Position unless they qualify for certain scope exceptions, including the normal purchases and normal sales exception. Further, derivatives that qualify and are designated for hedge accounting are classified as either hedges of a forecasted transaction or the variability of cash flows to be received or paid related to a recognized asset or liability (cash flow hedge); or as hedges of the fair value of a recognized asset or liability or of an unrecognized firm commitment (fair value hedge). For cash flow hedges, the derivative gain or loss is deferred in Accumulated other comprehensive income (loss) and later reclassified into earnings when the underlying transaction occurs. For fair value hedges, changes in fair values for the derivative and hedged item are recognized in earnings each period. For derivatives that do not qualify or are not designated for hedge accounting, changes in fair value are recognized in earnings each period. The Registrants' primary market risk exposure is associated with commodity prices, credit, and interest rates. The Registrants have risk management policies to monitor and manage market risks. The Registrants use derivative instruments to manage some of the exposure. DTE Energy uses derivative instruments for trading purposes in its Energy Trading segment. Contracts classified as derivative instruments include electricity, natural gas, oil, certain environmental contracts, forwards, futures, options, swaps, and foreign currency exchange contracts. Items not classified as derivatives include natural gas and environmental inventory, pipeline transportation contracts, some environmental contracts, and natural gas storage assets.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
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 capacity, and sells storage capacity. DTE Gas has fixed-priced contracts for portions of its expected natural gas supply requirements through March 2022.2023. Substantially all of these contracts meet the normal purchases and normal sales exception and are therefore accounted for under the accrual method. DTE Gas may also sell forward transportation and storage capacity contracts. 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.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) 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 December 31, 20192020 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.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
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. • — 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 forcontracts at DTE Energy:
| | | | | | | | | | | | | | | | | | | December 31, 2019 | | December 31, 2018 | | | Derivative
Assets | | Derivative
Liabilities | | Derivative
Assets | | Derivative
Liabilities | | | (In millions) | | Derivatives designated as hedging instruments | | | | | | | | | Interest rate contracts | $ | — |
| | $ | — |
| | $ | — |
| | $ | (3 | ) | | Derivatives not designated as hedging instruments | | | | | | | | | Commodity contracts | | | | | | | | | Natural gas | $ | 355 |
| | $ | (351 | ) | | $ | 349 |
| | $ | (380 | ) | | Electricity | 306 |
| | (298 | ) | | 303 |
| | (285 | ) | | Environmental & Other | 113 |
| | (121 | ) | | 7 |
| | (1 | ) | | Foreign currency exchange contracts | 1 |
| | — |
| | 4 |
| | — |
| | Total derivatives not designated as hedging instruments | $ | 775 |
| | $ | (770 | ) | | $ | 663 |
| | $ | (666 | ) | | | | | | | | | | | Current | $ | 646 |
| | $ | (596 | ) | | $ | 563 |
| | $ | (518 | ) | | Noncurrent | 129 |
| | (174 | ) | | 100 |
| | (151 | ) | | Total derivatives | $ | 775 |
| | $ | (770 | ) | | $ | 663 |
| | $ | (669 | ) |
The following table presentsElectric are recorded as Derivative assets or liabilities, with an offset to Regulatory assets or liabilities as the fairsettlement value of derivative instruments for DTE Electric:
| | | | | | | | | | | December 31, | | | 2019 | | 2018 | | | (In millions) | | FTRs — Other current assets | $ | 3 |
| | $ | 6 |
| | Total derivatives not designated as hedging instruments | $ | 3 |
| | $ | 6 |
|
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
| | | | | | | | | | | | | | | | | | | | | | | | | December 31, 2020 | | December 31, 2019 | | Derivative
Assets | | Derivative
Liabilities | | Derivative
Assets | | Derivative
Liabilities | | (In millions) | | Derivatives designated as hedging instruments | | | | | | | | | Foreign currency exchange contracts | $ | 0 | | | $ | (4) | | | $ | 0 | | | $ | 0 | | | Derivatives not designated as hedging instruments | | | | | | | | | Commodity contracts | | | | | | | | | Natural gas | $ | 233 | | | $ | (223) | | | $ | 355 | | | $ | (351) | | | Electricity | 180 | | | (168) | | | 306 | | | (298) | | | Environmental & Other | 154 | | | (137) | | | 113 | | | (121) | | | Foreign currency exchange contracts | 0 | | | (1) | | | 1 | | | 0 | | | Total derivatives not designated as hedging instruments | $ | 567 | | | $ | (529) | | | $ | 775 | | | $ | (770) | | | | | | | | | | | Current | $ | 446 | | | $ | (386) | | | $ | 646 | | | $ | (596) | | | Noncurrent | 121 | | | (147) | | | 129 | | | (174) | | | Total derivatives | $ | 567 | | | $ | (533) | | | $ | 775 | | | $ | (770) | |
The following table presents the fair value of derivative instruments for DTE Electric: | | | | | | | | | | | | | December 31, | | 2020 | | 2019 | | (In millions) | | FTRs — Other current assets | $ | 4 | | | $ | 3 | | | Total derivatives not designated as hedging instruments | $ | 4 | | | $ | 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 $6$7 million outstanding at December 31, 20192020 and $4$6 million at December 31, 2018,2019, 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 $4$9 million and $8$4 million at December 31, 20192020 and 2018,2019, 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:
| | | | | | | | | | | December 31, | | | 2019 | | 2018 | | | (In millions) | | Cash collateral netted against Derivative assets | $ | — |
| | $ | (17 | ) | Cash collateral recorded in Accounts receivable(a) | 13 |
| | 10 |
| Cash collateral recorded in Accounts payable(a) | (3 | ) | | (6 | ) | | Total net cash collateral posted (received) | $ | 10 |
| | $ | (13 | ) |
| | (a) | Amounts are recorded net by counterparty. |
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
| | | | | | | | | | | | | December 31, | | 2020 | | 2019 | | (In millions) | | Cash collateral netted against Derivative assets | $ | (12) | | | $ | 0 | | | Cash collateral netted against Derivative liabilities | 6 | | | 0 | | Cash collateral recorded in Accounts receivable(a) | 14 | | | 13 | | Cash collateral recorded in Accounts payable(a) | (1) | | | (3) | | | Total net cash collateral posted (received) | $ | 7 | | | $ | 10 | |
(a)Amounts are recorded net by counterparty. The following table presents the netting offsets of Derivative assets and liabilities for DTE Energy: | | | | | | | | | | | | | | | | | | | | | | | | | | | December 31, 2019 | | December 31, 2018 | | | 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 | $ | 355 |
| | $ | (266 | ) | | $ | 89 |
| | $ | 349 |
| | $ | (277 | ) | | $ | 72 |
| | Electricity | 306 |
| | (225 | ) | | 81 |
| | 303 |
| | (252 | ) | | 51 |
| | Environmental & Other | 113 |
| | (110 | ) | | 3 |
| | 7 |
| | (1 | ) | | 6 |
| | Foreign currency exchange contracts | 1 |
| | — |
| | 1 |
| | 4 |
| | — |
| | 4 |
| | Total derivative assets | $ | 775 |
| | $ | (601 | ) | | $ | 174 |
| | $ | 663 |
| | $ | (530 | ) | | $ | 133 |
| | | | | | | | | | | | | | | Derivative liabilities | | | | | | | | | | | | | Commodity contracts | | | | | | | | | | | | | Natural gas | $ | (351 | ) | | $ | 266 |
| | $ | (85 | ) | | $ | (380 | ) | | $ | 272 |
| | $ | (108 | ) | | Electricity | (298 | ) | | 225 |
| | (73 | ) | | (285 | ) | | 240 |
| | (45 | ) | | Environmental & Other | (121 | ) | | 110 |
| | (11 | ) | | (1 | ) | | 1 |
| | — |
| | Interest rate contracts | — |
| | — |
| | — |
| | (3 | ) | | — |
| | (3 | ) | | Total derivative liabilities | $ | (770 | ) | | $ | 601 |
| | $ | (169 | ) | | $ | (669 | ) | | $ | 513 |
| | $ | (156 | ) |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | December 31, 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 | $ | 233 | | | $ | (156) | | | $ | 77 | | | $ | 355 | | | $ | (266) | | | $ | 89 | | | Electricity | 180 | | | (120) | | | 60 | | | 306 | | | (225) | | | 81 | | | Environmental & Other | 154 | | | (135) | | | 19 | | | 113 | | | (110) | | | 3 | | | Foreign currency exchange contracts | 0 | | | 0 | | | 0 | | | 1 | | | 0 | | | 1 | | | Total derivative assets | $ | 567 | | | $ | (411) | | | $ | 156 | | | $ | 775 | | | $ | (601) | | | $ | 174 | | | | | | | | | | | | | | | Derivative liabilities | | | | | | | | | | | | | Commodity contracts | | | | | | | | | | | | | Natural gas | $ | (223) | | | $ | 151 | | | $ | (72) | | | $ | (351) | | | $ | 266 | | | $ | (85) | | | Electricity | (168) | | | 125 | | | (43) | | | (298) | | | 225 | | | (73) | | | Environmental & Other | (137) | | | 129 | | | (8) | | | (121) | | | 110 | | | (11) | | | Interest rate contracts | 0 | | | 0 | | | 0 | | | 0 | | | 0 | | | 0 | | | Foreign currency exchange contracts | (5) | | | 0 | | | (5) | | | 0 | | | 0 | | | 0 | | | Total derivative liabilities | $ | (533) | | | $ | 405 | | | $ | (128) | | | $ | (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: | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | December 31, 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 | $ | 446 | | | $ | 121 | | | $ | (386) | | | $ | (147) | | | $ | 646 | | | $ | 129 | | | $ | (596) | | | $ | (174) | | | Counterparty netting | (318) | | | (81) | | | 318 | | | 81 | | | (513) | | | (88) | | | 513 | | | 88 | | | Collateral adjustment | (12) | | | 0 | | | 0 | | | 6 | | | 0 | | | 0 | | | 0 | | | 0 | | | Total derivatives as reported | $ | 116 | | | $ | 40 | | | $ | (68) | | | $ | (60) | | | $ | 133 | | | $ | 41 | | | $ | (83) | | | $ | (86) | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | December 31, 2019 | | December 31, 2018 | | | Derivative Assets | | Derivative Liabilities | | Derivative Assets | | Derivative Liabilities | | | Current | | Noncurrent | | Current | | Noncurrent | | Current | | Noncurrent | | Current | | Noncurrent | | | (In millions) | | Total fair value of derivatives | $ | 646 |
| | $ | 129 |
| | $ | (596 | ) | | $ | (174 | ) | | $ | 563 |
| | $ | 100 |
| | $ | (518 | ) | | $ | (151 | ) | | Counterparty netting | (513 | ) | | (88 | ) | | 513 |
| | 88 |
| | (451 | ) | | (62 | ) | | 451 |
| | 62 |
| | Collateral adjustment | — |
| | — |
| | — |
| | — |
| | (10 | ) | | (7 | ) | | — |
| | — |
| | Total derivatives as reported | $ | 133 |
| | $ | 41 |
| | $ | (83 | ) | | $ | (86 | ) | | $ | 102 |
| | $ | 31 |
| | $ | (67 | ) | | $ | (89 | ) |
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
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 Years Ended December 31, | | | | | 2019 | | 2018 | | 2017 | | | | | | (In millions) | | Commodity contracts | | | | | | | | | | Natural gas | | Operating Revenues — Non-utility operations | | $ | 44 |
| | $ | (42 | ) | | $ | (74 | ) | | Natural gas | | Fuel, purchased power, and gas — non-utility | | (5 | ) | | (94 | ) | | 97 |
| | Electricity | | Operating Revenues — Non-utility operations | | 44 |
| | 49 |
| | 105 |
| | Environmental & Other | | Operating Revenues — Non-utility operations | | (26 | ) | | (1 | ) | | 2 |
| | Foreign currency exchange contracts | | Operating Revenues — Non-utility operations | | (2 | ) | | 7 |
| | (2 | ) | | Total | | | | $ | 55 |
| | $ | (81 | ) | | $ | 128 |
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | Location of Gain (Loss) Recognized in Income on Derivatives | | Gain (Loss) Recognized in Income on Derivatives for Years Ended December 31, | | | | 2020 | | 2019 | | 2018 | | | | | (In millions) | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | Commodity contracts | | | | | | | | | | Natural gas | | Operating Revenues — Non-utility operations | | $ | (70) | | | $ | 44 | | | $ | (42) | | | Natural gas | | Fuel, purchased power, gas, and other — non-utility | | 20 | | | (5) | | | (94) | | | Electricity | | Operating Revenues — Non-utility operations | | 91 | | | 44 | | | 49 | | | Environmental & Other | | Operating Revenues — Non-utility operations | | (118) | | | (26) | | | (1) | | | Foreign currency exchange contracts | | Operating Revenues — Non-utility operations | | (6) | | | (2) | | | 7 | | | Total | | | | $ | (83) | | | $ | 55 | | | $ | (81) | |
Revenues and energy costs related to trading contracts are presented on a net basis in DTE Energy's Consolidated Statements of Operations. Commodity derivatives used for trading purposes, and financial non-trading commodity derivatives, are accounted for using the MTM method with unrealized and realized gains and losses recorded in Operating Revenues — Non-utility operations. Non-trading physical commodity sale and purchase derivative contracts are generally accounted for using the MTM method with unrealized and realized gains and losses for sales recorded in Operating Revenues — Non-utility operations and purchases recorded in Fuel, purchased power, gas, and gasother — non-utility. The following represents the cumulative gross volume of DTE Energy's derivative contracts outstanding as of December 31, 2019:2020: | | | | | | | | | | Commodity | | Number of Units | | Natural gas (MMBtu) | | 1,699,804,8051,757,668,006 |
| | Electricity (MWh) | | 31,351,22929,383,355 |
| | | | Foreign currency exchange (CAD)($ CAD) | | 78,563,487144,655,453 |
| | | | | Renewable Energy Certificates (MWh) | | 9,221,803 | | | Carbon emissions (Metric Ton) | | 12,495,202 | |
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 December 31, 2019,2020, 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 $527$428 million. As of December 31, 2019,2020, DTE Energy had $678$451 million of derivatives in net liability positions, for which hard triggers exist. There is 0 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 $593$401 million. The net remaining amount of $85$50 million is derived from the $527$428 million noted above.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
NOTE 15 — LONG-TERM DEBT Long-Term Debt DTE Energy's long-term debt outstanding and weighted average interest rates of debt outstanding at December 31 were: | | | | | | | | | | | | | | | Interest Rate(a) | | Maturity Date | | 2019 | | 2018 | | | | | | | (In millions) | | Mortgage bonds, notes, and other | | | | | | | | | DTE Energy Debt, Unsecured | 3.2% | | 2022 — 2033 | | $ | 6,625 |
| | $ | 4,425 |
| | DTE Electric Taxable Debt, Principally Secured | 4.2% | | 2020 — 2049 | | 6,930 |
| | 6,280 |
| DTE Electric Tax-Exempt Revenue Bonds(b) | 4.3% | | 2020 — 2030 | | 310 |
| | 310 |
| | DTE Gas Taxable Debt, Principally Secured | 4.3% | | 2020 — 2049 | | 1,710 |
| | 1,550 |
| | Other Long-Term Debt, including Non-Recourse Debt | | | | | — |
| | 1 |
| | | | | | | 15,575 |
| | 12,566 |
| | Unamortized debt discount | | | | | (24 | ) | | (16 | ) | | Unamortized debt issuance costs | | | | | (91 | ) | | (73 | ) | | Long-term debt due within one year | | | | | (682 | ) | | (1,495 | ) | | | | | | | $ | 14,778 |
| | $ | 10,982 |
| | Junior Subordinated Debentures | | | | | | | | | Subordinated Debentures | 5.5% | | 2062 — 2077 | | $ | 1,180 |
| | $ | 1,180 |
| | Unamortized debt issuance costs | | | | | (34 | ) | | (35 | ) | | | | | | | $ | 1,146 |
| | $ | 1,145 |
|
| | | | | | | | | | | | | | | | | | | | | | | | | Interest Rate(a) | | Maturity Date | | 2020 | | 2019 | | | | | | (In millions) | | Mortgage bonds, notes, and other | | | | | | | | | DTE Energy Debt, Unsecured | 2.7% | | 2022 — 2033 | | $ | 8,175 | | | $ | 6,625 | | | DTE Electric Taxable Debt, Principally Secured | 3.9% | | 2021 — 2050 | | 8,030 | | | 6,930 | | DTE Electric Tax-Exempt Revenue Bonds(b) | 4.1% | | 2021 — 2030 | | 278 | | | 310 | | | DTE Gas Taxable Debt, Principally Secured | 4% | | 2023 — 2050 | | 1,910 | | | 1,710 | | | | | | | | | | | | | | | 18,393 | | | 15,575 | | | Unamortized debt discount | | | | | (25) | | | (24) | | | Unamortized debt issuance costs | | | | | (104) | | | (91) | | | Long-term debt due within one year | | | | | (462) | | | (682) | | | | | | | $ | 17,802 | | | $ | 14,778 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | Junior Subordinated Debentures | | | | | | | | | Subordinated Debentures | 5.3% | | 2076 — 2080 | | $ | 1,210 | | | $ | 1,180 | | | Unamortized debt issuance costs | | | | | (35) | | | (34) | | | | | | | $ | 1,175 | | | $ | 1,146 | |
| | (a) | Weighted average interest rate as of December 31, 2019. |
| | (b) | DTE Electric Tax-Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds. |
(a)Weighted average interest rate as of December 31, 2020. (b)DTE Electric Tax-Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds. DTE Electric's long-term debt outstanding and weighted average interest rates of debt outstanding at December 31 were: | | | | Interest Rate(a) | | Maturity Date | | 2019 | | 2018 | | Interest Rate(a) | | Maturity Date | | 2020 | | 2019 | | | | (In millions) | | | | | | (In millions) | | Mortgage bonds, notes, and other | | | | | Mortgage bonds, notes, and other | | | Taxable Debt, Principally Secured | 4.2% | | 2020 — 2049 | | $ | 6,930 |
| | $ | 6,280 |
| Taxable Debt, Principally Secured | 3.9% | | 2021 — 2050 | | $ | 8,030 | | | $ | 6,930 | | Tax-Exempt Revenue Bonds(b) | 4.3% | | 2020 — 2030 | | 310 |
| | 310 |
| Tax-Exempt Revenue Bonds(b) | 4.1% | | 2021 — 2030 | | 278 | | | 310 | | | | | | 7,240 |
| | 6,590 |
| | | 8,308 | | | 7,240 | | | Unamortized debt discount | | (15 | ) | | (11 | ) | Unamortized debt discount | | (16) | | | (15) | | | Unamortized debt issuance costs | | (45 | ) | | (41 | ) | Unamortized debt issuance costs | | (56) | | | (45) | | | Long-term debt due within one year | | (632 | ) | | — |
| Long-term debt due within one year | | (462) | | | (632) | | | | | $ | 6,548 |
| | $ | 6,538 |
| | $ | 7,774 | | | $ | 6,548 | | |
| | (a) | Weighted average interest rate as of December 31, 2019. |
| | (b) | Tax-Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds. |
(a)Weighted average interest rate as of December 31, 2020. (b)Tax-Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
Debt Issuances In 2019,2020, the following debt was issued: | | | | | | | | | | | | | | | Company | | Month | | Type | | Interest Rate | | Maturity Date | | Amount | | | | | | | | | | | | (In millions) | | DTE Electric | | February | | Mortgage Bonds(a) | | 3.95% | | 2049 | | $ | 650 |
| | DTE Energy | | June | | Senior Notes(b) | | 2.60% | | 2022 | | 300 |
| | DTE Energy | | June | | Senior Notes(b) | | 3.40% | | 2029 | | 500 |
| | DTE Gas | | October | | Mortgage Bonds(b) | | 2.95% | | 2029 | | 140 |
| | DTE Gas | | October | | Mortgage Bonds(b) | | 3.72% | | 2049 | | 140 |
| | DTE Energy | | November | | Senior Notes(c) | | 2.25% | | 2022 | | 500 |
| | DTE Energy | | November | | Senior Notes(c) | | 2.95% | | 2030 | | 300 |
| | DTE Energy | | November | | Equity Units(c) | | (d) | | 2025 | | 1,300 |
| | | | | | | | | | | | $ | 3,830 |
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | 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 | | | DTE Energy | | October | | Junior Subordinated Debentures(e) | | 4.38% | | 2080 | | 230 | | | DTE Energy | | October | | Senior Notes(f) | | 0.55% | | 2022 | | 750 | | | | | | | | | | | | $ | 3,730 | |
| | (a) | Bonds were issued as Green Bonds and the proceeds will be used to finance expenditures for solar and wind energy, payments under power purchase agreements for solar and wind energy, and energy optimization programs. |
| | (b) | Proceeds were used for the repayment of short-term borrowings and general corporate purposes. |
| | (c) | Proceeds were used to pay a portion of the purchase price of the Blue Union and LEAP acquisition. Refer to "Acquisition Financing" below for additional information. |
| | (d) | See "Acquisition Financing" below for more information regarding the rates associated with the Equity Units. |
(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. (e)Proceeds used for the repayment of $200 million of DTE Energy's 2012 Series C 5.25% Junior Subordinated Debentures due 2062 and for general corporate purposes. (f)Proceeds used for the repayment of DTE Energy's $500 million unsecured term loan expiring March 2021, repayment of DTE Energy's $167 million unsecured term loan expiring June 2021, and general corporate purposes. Debt Redemptions In 2019,2020, the following debt was redeemed: | | | | | | | | | | | | | | | Company | | Month | | Type | | Interest Rate | | Maturity Date | | Amount | | | | | | | | | | | | (In millions) | | DTE Energy | | October | | Senior Notes | | 1.50% | | 2019 | | $ | 400 |
| | DTE Gas | | October | | Senior Notes | | 5.00% | | 2019 | | 120 |
| | DTE Energy | | December | | Senior Notes | | 2.40% | | 2019 | | 300 |
| | DTE Energy | | Various | | Other long-term debt | | Various | | 2019 | | 1 |
| | | | | | | | | | | | $ | 821 |
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | 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 | | | DTE Energy | | October | | Junior Subordinated Debentures | | 5.25% | | 2062 | | 200 | | | | | | | | | | | | | | | | | | | | | | | $ | 882 | |
The following table shows the Registrants' scheduled debt maturities, excluding any unamortized discount on debt: | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | 2020 | | 2021 | | 2022 | | 2023 | | 2024 | | 2025 and Thereafter | | Total | | | (In millions) | DTE Energy(a) | $ | 682 |
| | $ | 462 |
| | $ | 2,716 |
| | $ | 1,177 |
| | $ | 1,425 |
| | $ | 10,293 |
| | $ | 16,755 |
| | DTE Electric | $ | 632 |
| | $ | 462 |
| | $ | 316 |
| | $ | 202 |
| | $ | 400 |
| | $ | 5,228 |
| | $ | 7,240 |
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | 2021 | | 2022 | | 2023 | | 2024 | | 2025 | | 2026 and Thereafter | | Total | | (In millions) | DTE Energy(a) | $ | 462 | | | $ | 3,466 | | | $ | 1,177 | | | $ | 1,425 | | | $ | 1,220 | | | $ | 11,853 | | | $ | 19,603 | | | DTE Electric | $ | 462 | | | $ | 316 | | | $ | 202 | | | $ | 400 | | | $ | 350 | | | $ | 6,578 | | | $ | 8,308 | |
| | (a) | (a)Amounts include DTE Electric's scheduled debt maturities. |
In January 2020, DTE Electric sent notice to optionally redeem its $300 million 2010 Series A 4.89% Senior Notes due September 2020. The notes are expected to be redeemed in March 2020.Electric's scheduled debt maturities.
Junior Subordinated Debentures DTE Energy has the right to defer interest payments on the Junior Subordinated Debentures. Should DTE Energy exercise this right, it cannot declare or pay dividends on, or redeem, purchase or acquire, any of its capital stock during the deferral period. Any deferred interest payments will bear additional interest at the rate associated with the related debt issue. As of December 31, 2019,2020, no interest payments have been deferred on the Junior Subordinated Debentures.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
Cross Default Provisions Substantially all of the net utility properties of DTE Electric and DTE Gas are subject to the lien of mortgages. Should DTE Electric or DTE Gas fail to timely pay their indebtedness under these mortgages, such failure may create cross defaults in the indebtedness of DTE Energy. 2016 Acquisition Senior Notes Remarketing
In October 2016, DTE Energy issued $675 million of 2016 Equity Units, initially in the form of Corporate Units. The Corporate Units were listed on the New York Stock Exchange under the symbol DTV. Each Corporate Unit consisted of a stock purchase contract and a 1/20 interest in a RSN issued by DTE Energy. The stock purchase contract obligated the holders to purchase shares of DTE Energy's common stock at a future settlement date. The purchase price under the stock purchase contracts was $50 per Corporate Unit and the number of shares purchased was determined by a formula based upon the average closing price of DTE Energy common stock near the settlement date. The RSNs were pledged as collateral to secure the purchase of common stock under the related stock purchase contracts.
In August 2019, DTE Energy remarketed the $675 million 2016 Series C 1.5% RSNs due 2024 pursuant to the terms of the 2016 Equity Units. As a result of the remarketing, the interest rate was reset to 2.529%, payable semi-annually at the new rate beginning October 1, 2019. DTE Energy did not receive any proceeds from the remarketing. All proceeds belonged to the investors holding the related 2016 Equity Units and were temporarily used to purchase a portfolio of treasury securities. The securities were released on behalf of investors on October 1, 2019 to satisfy the related stock purchase contracts and pay the purchase price to DTE Energy for the issuance of approximately 5.87 million shares of common stock.
Gas Storage and Pipelines Segment Acquisition Financing In December 2019, DTE Energy closed on the purchase of midstream natural gas assets. The acquisition was financed through the issuance of Equity Units, Senior Notes, and common stock. For information on the common stock issuance, refer toSee Note 124 to the Consolidated Financial Statements, "Common Stock"Acquisitions and Earnings Per Share.Dispositions," for more information on the acquisition. In November 2019, DTE issued $1.3 billion of 2019 Equity Units. Each Equity Unit has a stated amount of $50 and was initially issued in the form of a Corporate Unit, comprised of (i) a forward purchase contract to buy DTE Energy common stock (stock purchase contract) and (ii) a 1/20 undivided beneficial ownership interest in a $1,000 principal amount of DTE Energy’s 2019 Series F 2.25% RSNs due 2025. The RSN debt instruments and the stock purchase contract equity instruments are deemed to be separate instruments as the investor may trade the RSNs separately from the stock purchase contracts and may also settle the stock purchase contracts separately. The Corporate Units are listed on the New York Stock Exchange under the symbol DTP. The stock purchase contract obligates the holder to purchase from DTE Energy on the settlement date, November 1, 2022, for a price of $50 per stock purchase contract, the following number of shares of DTE Energy’s common stock, subject to anti-dilution adjustments: •if the AMV of DTE Energy’s common stock, which is the average volume-weighted average price of DTE Energy’s common stock for the trading days during the 20 consecutive scheduled trading day period ending on the third scheduled trading day immediately preceding the stock purchase contract settlement date, is equal to or greater than $157.50, 0.3175 shares of common stock; •if the AMV is less than $157.50 but greater than $126.00, a number of shares of common stock equal to $50 divided by the AMV; and •if the AMV is less than or equal to $126.00, 0.3968 shares of common stock. The RSNs bear interest at a rate of 2.25% per year, payable quarterly, and mature on November 1, 2025. The RSNs will be remarketed in 2022. If this remarketing is successful, the interest rate on the RSNs will be reset, and interest thereafter interest will be payable semi-annually at the reset rate. If there is no successful remarketing, the interest rate on the RSNs will not be reset, and thereset. The holders of the RSNs willwould have the right to put the RSNs to DTE Energy at a price equal to 100% of the principal amount, and the proceeds of the put right willwould be deemed to have been applied against the holders’ obligation under the stock purchase contracts. DTE Energy may also redeem, in whole or in part, the RSNs in the event of a failed final remarketing.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
DTE Energy will also pay the stock purchase contract holders quarterly contract adjustment payments at a rate of 4% per year of the stated amount of $50 per Equity Unit, or $2 per year, commencing on February 1, 2020. The present value of the future contract adjustment payments of $150 million iswas recorded as a reduction of shareholders’ equity, offset by the stock purchase contract liability. The stock purchase contract liability is included in Current Liabilities — Other and Other Liabilities — Other on DTE Energy’s Consolidated Statements of Financial Position. On February 1, 2020, DTE Energy began paying the stock purchase contract holders quarterly contract adjustment payments at a rate of 4% per year of the stated amount of $50 per Equity Unit, or $2 per year. Interest payments on the RSNs are being recorded as interest expense and stock purchase contract payments are being charged against the liability. Accretion of the stock purchase contract liability is recorded as imputed interest expense.
The treasury stock method will beis used to compute diluted EPS for the stock purchase contract. Under the treasury stock method, the stock purchase contract will only have a dilutive effect when the settlement rate is based on the market value of DTE’s common stock that is greater than $157.50 (the threshold appreciation price). At December 31, 2020, the stock purchase price contract was anti-dilutive and, therefore, not included in the computation of diluted earnings per share. If payments for the stock purchase contract are deferred, DTE Energy may not make any cash distributions related to its capital stock, including dividends, redemptions, repurchases, liquidation payments or guarantee payments. Also, during the deferral period, DTE Energy may not make any payments on or redeem or repurchase any debt securities that are equal in right of payment with, or subordinated to, the RSNs.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) Until settlement of the stock purchase contracts, the shares of stock underlying each contract are not outstanding. Under the terms of the stock purchase contracts, assuming no anti-dilution or other adjustments, DTE Energy will issue between 8.3 million and 10.3 million shares of its common stock in November 2022. A total of 13 million shares of DTE Energy’s common stock have been reserved for issuance in connection with the stock purchase contracts. Selected information about DTE Energy’s 2019 Equity Units is presented below: | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | Issuance Date | | Units Issued | | Total Net Proceeds | | Total Long-Term Debt | | RSN Annual Interest Rate | | Stock Purchase Contract Annual Rate | | Stock Purchase Settlement Date | | Stock Purchase Contract Liability(a) | | RSN Maturity Date | | (In millions, except interest rates) | | 11/1/19 | | 26 | | $ | 1,268 | | | $ | 1,300 | | | 2.25% | | 4.0% | | 11/1/2022 | | $ | 150 | | | 11/1/2025 |
| | | | | | | | | | | | | | | | | | | | | | | | | Issuance Date | | Units Issued | | Total Net Proceeds | | Total Long-Term Debt | | RSN Annual Interest Rate | | Stock Purchase Contract Annual Rate | | Stock Purchase Settlement Date | | Stock Purchase Contract Liability | | RSN Maturity Date | | (In millions, except interest rates) | | 11/1/19 | | 26 | | $ | 1,268 |
| | $ | 1,300 |
| | 2.25% | | 4.0% | | 11/1/2022 | | $ | 150 |
| | 11/1/2025 |
In November 2019, DTE Energy issued $500 million of 2019 Series G 2.25% Senior Notes due 2022 and $300 million of Series H 2.95% Senior Notes due 2030. The proceeds from the Senior Notes were used for the acquisition.
NOTE 16 — PREFERRED AND PREFERENCE SECURITIES As of December 31, 2019,2020, the amount of authorized and unissued stock is as follows: | | | | | | | | | | | | | | | | | | | | | | Company | | Type of Stock | | Par Value | | Shares Authorized | | DTE Energy | | Preferred | | $ | 0 | | | 5,000,000 | | | DTE Electric | | Preferred | | $ | 100 | | | 6,747,484 | | | DTE Electric | | Preference | | $ | 1 | | | 30,000,000 | | | DTE Gas | | Preferred | | $ | 1 | | | 7,000,000 | | | DTE Gas | | Preference | | $ | 1 | | | 4,000,000 | |
| | | | | | | | | | | | Company | | Type of Stock | | Par Value | | Shares Authorized | | DTE Energy | | Preferred | | $ | — |
| | 5,000,000 |
| | DTE Electric | | Preferred | | $ | 100 |
| | 6,747,484 |
| | DTE Electric | | Preference | | $ | 1 |
| | 30,000,000 |
| | DTE Gas | | Preferred | | $ | 1 |
| | 7,000,000 |
| | DTE Gas | | Preference | | $ | 1 |
| | 4,000,000 |
|
NOTE 17 — 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. Additionally, DTE Energy also has other facilities to support letter of credit issuance. During 2020, the Registrants entered into a series of unsecured term loans to raise additional liquidity, including terms consistent with the unsecured revolving credit agreements. Several of these term loans were entered into and subsequently repaid in 2020. One unsecured term loan remains as of December 31, 2020, a $200 million loan entered into by DTE Electric in November 2020 with a maturity date in November 2021. Through December 31, 2020, 0 amounts have been drawn and commitment fees have not been material. The loan will terminate if no amounts are drawn by April 30, 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$49 million outstanding as of December 31, 2020. The revolving credit agreement expires in May 2023 and has terms consistent with DTE Energy's unsecured revolving credit agreements.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
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 December 31, 2019,2020, the total funded debt to total capitalization ratios for DTE Energy, DTE Electric, and DTE Gas were 0.580.59 to 1, 0.51 to 1, and 0.48 to 1, respectively, and were in compliance with this financial covenant. The availability under the facilities in place at December 31, 20192020 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 revolving credit facility, expiring April 2024 | 1,500 |
| | 500 |
| | 300 |
| | 2,300 |
| | | 1,760 |
| | 500 |
| | 300 |
| | 2,560 |
| | Amounts outstanding at December 31, 2019 | | | | | | | | | Commercial paper issuances | 280 |
| | 354 |
| | 194 |
| | 828 |
| | Letters of credit | 229 |
| | — |
| | — |
| | 229 |
| | | 509 |
| | 354 |
| | 194 |
| | 1,057 |
| | Net availability at December 31, 2019 | $ | 1,251 |
| | $ | 146 |
| | $ | 106 |
| | $ | 1,503 |
|
| | | | | | | | | | | | | | | | | | | | | | | | | DTE Energy | | DTE Electric | | DTE Gas | | Total | | (In millions) | | Unsecured letter of credit facility, expiring in February 2021 | $ | 150 | | | $ | 0 | | | $ | 0 | | | $ | 150 | | | Unsecured letter of credit facility, expiring in August 2021 | 110 | | | 0 | | | 0 | | | 110 | | | Unsecured term loan, expiring in November 2021 | 0 | | | 200 | | | 0 | | | 200 | | | Unsecured Canadian revolving credit facility, expiring May 2023 | 86 | | | 0 | | | 0 | | | 86 | | | Unsecured revolving credit facility, expiring April 2024 | 1,500 | | | 500 | | | 300 | | | 2,300 | | | 1,846 | | | 700 | | | 300 | | | 2,846 | | | Amounts outstanding at December 31, 2020 | | | | | | | | | | | | | | | | | Letters of credit | 193 | | | 0 | | | 0 | | | 193 | | | | | | | | | | | Revolver borrowings | 38 | | | 0 | | | 0 | | | 38 | | | 231 | | | 0 | | | 0 | | | 231 | | | Net availability at December 31, 2020 | $ | 1,615 | | | $ | 700 | | | $ | 300 | | | $ | 2,615 | |
DTE Energy has $9$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. TheFor DTE Energy, the weighted average interest rate for short-term borrowings was 2.0%1.1% and 2.9%2.0% at December 31, 2020 and 2019, and 2018, respectively, forrespectively. For DTE Energy. TheElectric, the weighted average interest rate for short-term borrowings was 1.9% and 2.9% at December 31, 2019 and 2018, respectively, for DTE Electric.2019. There were no short-term borrowings outstanding as of December 31, 2020.
In conjunction with maintaining certain exchange-traded risk management positions, DTE Energy may be required to post collateral with its clearing agent.agents. DTE Energy has a demand financing agreements with its clearing agents, including an agreement for up to $100 million with its clearing agent.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 and allowsamount. Both agreements allow the right of setoff with posted collateral. At December 31, 2019,2020, the capacity under this facilitythese facilities was $150$300 million. The amount outstanding under this agreementthese agreements was $114$49 million and $93$114 million at December 31, 20192020 and 2018,2019, respectively, and was fully offset by the posted collateral. Dividend Restrictions Certain of DTE Energy’s credit facilities contain a provision requiring DTE Energy to maintain a total funded debt to capitalization ratio, as defined in the agreements, of no more than 0.65 to 1, which has the effect of limiting the amount of dividends DTE Energy can pay in order to maintain compliance with this provision. At December 31, 2019,2020, the effect of this provision was a restriction on dividend payments to restrict the payment of approximately $3.2no more than $2.8 billion of DTE Energy's Retained earnings totaling $6.6of $7.2 billion. There are 0 other effective limitations with respect to DTE Energy’s ability to pay dividends.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) NOTE 18 — LEASES Disclosures related to the year ended December 31, 2019 are presented as required under Topic 842. Prior period disclosures for the year ended December 31, 2018 are presented under Topic 840. The Registrants have elected to use a practical expedient provided by Topic 842 whereby comparative disclosures for prior periods are allowed to be presented under Topic 840. As a result, the disclosures presented under Topic 842 and Topic 840 will not be fully comparable in specific disclosure requirements.
Lessee Topic 842 — Leases at DTE Energy are primarily comprised of various forms of equipment, computer hardware, coal railcars, production facilities, buildings, and certain easement leases with terms ranging from approximately 2 to 40 years. Leases at DTE Electric are primarily comprised of various forms of equipment, computer hardware, coal railcars, and certain easement leases with terms ranging from approximately 2 to 40 years.
A lease is deemed to exist when the Registrants have the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration paid. The right to control is deemed to occur when the Registrants have the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets. Lease liabilities are determined utilizing a discount rate to determine the present values of lease payments. Topic 842 requires the use of the rate implicit in the lease when it is readily determinable. When the rate implicit in the lease is not readily determinable, the incremental borrowing rate is used. The Registrants have determined their respective incremental borrowing rates based upon the rate of interest that would have been paid on a collateralized basis over similar tenors to that of the leases. The incremental borrowing rates for DTE Electric and DTE Gas have been determined utilizing respective secured borrowing rates for first mortgage bonds with like tenors of remaining lease terms. Incremental borrowing rates for non-utility entities have been determined utilizing an implied secured borrowing rate based upon an unsecured rate for a similar tenor of remaining lease terms, which is then adjusted for the estimated impact of collateral. Certain leases of the Registrants contain escalation clauses whereby the payments are adjusted for consumer price or labor indices. DTE Energy has leases with non-index based escalation clauses for fixed dollar or percentage increases. DTE Electric has leases with non-index based escalation clauses for fixed dollar increases. DTE Energy also has leases with variable payments based upon usage of, or revenues associated with, the leased assets. DTE Electric also has leases with variable payments based upon the usage of the leased assets. Certain leases of easements and coal railcars contain provisions whereby the Registrants have the option to terminate the lease agreement by giving notice of such termination during the time frames specified in the respective lease. The Registrants have considered such provisions in the determination of the lease term when it is reasonably certain that the lease would be terminated. The Registrants have certain leases which contain purchase options. Based upon the nature of the leased property and terms of the purchase options, the Registrants have determined it is not reasonably certain that such purchase options will be utilized. Thus, the impact of the purchase options has not been included in the determination of right-of-use assets and lease liabilities for the subject leases. The Registrants have certain leases which contain renewal options. Where the renewal options were deemed reasonably certain to occur, the impacts of such options were included in the determination of the right of use assets and lease liabilities. The Registrants have agreements with lease and non-lease components, which are generally accounted for separately. Consideration in a lease is allocated between lease and non-lease components based upon the estimated relative standalone prices. The Registrants have certain coal railcar leases for which non-lease and lease components are accounted for as a single lease component, as permitted under Topic 842.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
The following is a summary of the components of lease cost for the yearyears ended December 31, 2019 were as follows:31: | | | | | | | | | | | DTE Energy | | DTE Electric | | | (In millions) | | Operating lease cost | $ | 41 |
| | $ | 17 |
| | Finance lease cost: | | | | | Amortization of right-of-use assets | 4 |
| | 4 |
| | Interest of lease liabilities | — |
| | — |
| | Total finance lease cost | 4 |
| | 4 |
| | Variable lease cost | 10 |
| | — |
| | Short-term lease cost | 10 |
| | 3 |
| | | $ | 65 |
| | $ | 24 |
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | DTE Energy | | DTE Electric | | 2020 | | 2019 | | 2020 | | 2019 | | | | (In millions) | | Operating lease cost | $ | 39 | | | $ | 41 | | | $ | 14 | | | $ | 17 | | | | | Finance lease cost: | | | | | | | | | | | Amortization of right-of-use assets | 5 | | | 4 | | | 4 | | | 4 | | | | | Interest of lease liabilities | 0 | | | 0 | | | 0 | | | 0 | | | | | Total finance lease cost | 5 | | | 4 | | | 4 | | | 4 | | | | | Variable lease cost | 10 | | | 10 | | | 0 | | | 0 | | | | | Short-term lease cost | 12 | | | 10 | | | 6 | | | 3 | | | | | | | | | | | | | | | $ | 66 | | | $ | 65 | | | $ | 24 | | | $ | 24 | | | |
The Registrants have elected not to apply the recognition requirements of Topic 842 to leases with a term of 12 months or less. DTE Energy and DTE Electric record operating, variable, and short-term lease costs as Operating Expenses on the Consolidated Statements of Operations, except for certain amounts that may be capitalized to other assets. OtherThe following is a summary of other information related to leases for the yearyears ended December 31, 2019 were as follows:31:
| | | | | | | | | | | DTE Energy | | DTE Electric | | | (In millions) | | Supplemental Cash Flows Information | | | | | Cash paid for amounts included in the measurement of these liabilities: | | | | | Operating cash flows for finance leases | $ | 5 |
| | $ | 5 |
| | Operating cash flows for operating leases | $ | 40 |
| | $ | 16 |
| | Right-of-use assets obtained in exchange for lease obligations: | | | | | Operating leases | $ | 68 |
| | $ | 27 |
| | Finance leases | $ | 8 |
| | $ | — |
| | | | | | | Weighted Average Remaining Lease Term | | | | | Operating leases | 9.7 years | | 10.6 years | | Finance leases | 9.1 years | | 2.0 years | | | | | | | Weighted Average Discount Rate | | | | | Operating leases | 3.5% | | 3.3% | | Finance leases | 3.1% | | 3.1% |
| | | | | | | | | | | | | | | | | | | | | | | | | DTE Energy | | DTE Electric | | 2020 | | 2019 | | 2020 | | 2019 | | (In millions) | | Supplemental Cash Flows Information | | | | | | | | | Cash paid for amounts included in the measurement of these liabilities: | | | | | | | | | Operating cash flows for finance leases | $ | 3 | | | $ | 5 | | | $ | 2 | | | $ | 5 | | | Operating cash flows for operating leases | $ | 40 | | | $ | 40 | | | $ | 14 | | | $ | 16 | | | | | | | | | | | Right-of-use assets obtained in exchange for lease obligations: | | | | | | | | | Operating leases | $ | 18 | | | $ | 68 | | | $ | 0 | | | $ | 27 | | | Finance leases | $ | 19 | | | $ | 8 | | | $ | 14 | | | $ | 0 | | | | | | | | | | | Weighted Average Remaining Lease Term (Years) | | | | | | | | | Operating leases | 9.3 | | 9.7 | | 10.4 | | 10.6 | | Finance leases | 7.6 | | 9.1 | | 3.1 | | 2.0 | | | | | | | | | | Weighted Average Discount Rate | | | | | | | | | Operating leases | 3.4 | % | | 3.5 | % | | 3.3 | % | | 3.3 | % | | Finance leases | 2.0 | % | | 3.1 | % | | 1.0 | % | | 3.1 | % |
The Registrants' future minimum lease payments under leases for remaining periods as of December 31, 2019 were2020 are as follows: | | | | | | | | | | | | | | | | | | | | | | | | | DTE Energy | | DTE Electric | | Operating Leases | | Finance Leases | | Operating Leases | | Finance Leases | | (In millions) | | 2021 | $ | 37 | | | $ | 8 | | | $ | 13 | | | $ | 6 | | | 2022 | 31 | | | 8 | | | 12 | | | 6 | | | 2023 | 22 | | | 8 | | | 10 | | | 6 | | | 2024 | 13 | | | 2 | | | 8 | | | 1 | | | 2025 | 8 | | | 1 | | | 6 | | | 0 | | | 2026 and thereafter | 61 | | | 7 | | | 32 | | | 0 | | | Total future minimum lease payments | 172 | | | 34 | | | 81 | | | 19 | | | Imputed interest | (28) | | | (3) | | | (14) | | | 0 | | | Lease liabilities | $ | 144 | | | $ | 31 | | | $ | 67 | | | $ | 19 | |
| | | | | | | | | | | | | | | | | | | DTE Energy | | DTE Electric | | | Operating Leases | | Finance Leases | | Operating Leases | | Finance Leases | | | (In millions) | | 2020 | $ | 38 |
| | $ | 5 |
| | $ | 14 |
| | $ | 3 |
| | 2021 | 30 |
| | 5 |
| | 13 |
| | 4 |
| | 2022 | 26 |
| | 1 |
| | 12 |
| | — |
| | 2023 | 20 |
| | 1 |
| | 10 |
| | — |
| | 2024 | 12 |
| | 1 |
| | 8 |
| | — |
| | 2025 and thereafter | 67 |
| | 4 |
| | 38 |
| | — |
| | Total future minimum lease payments | 193 |
| | 17 |
| | 95 |
| | 7 |
| | Imputed interest | (33 | ) | | (2 | ) | | (16 | ) | | — |
| | | $ | 160 |
| | $ | 15 |
| | $ | 79 |
| | $ | 7 |
|
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
Finance leases reported on the Consolidated StatementStatements of Financial Position wereare as follows: | | | | | | | | | | | DTE Energy | | DTE Electric | | | December 31, 2019 | | | (In millions) | | Right-of-use assets, within Property, plant, and equipment, net | $ | 15 |
| | $ | 7 |
| | Current lease liabilities, within Current Liabilities — Other | $ | 4 |
| | $ | 3 |
|
Topic 840 — The following disclosures are presented under Topic 840follows for the yearyears ended December 31, 2018.31:
The Registrants lease various assets under operating leases, including coal railcars, office buildings, a warehouse, computers, vehicles, and other equipment. The lease arrangements expire at various dates through 2051 and 2046 for | | | | | | | | | | | | | | | | | | | | | | | | | DTE Energy | | DTE Electric | | 2020 | | 2019 | | 2020 | | 2019 | | (In millions) | | Right-of-use assets, within Property, plant, and equipment, net | $ | 29 | | | $ | 15 | | | $ | 16 | | | $ | 7 | | | Current lease liabilities, within Current Liabilities — Other | $ | 7 | | | $ | 4 | | | $ | 6 | | | $ | 3 | | | Long-term lease liabilities | $ | 24 | | | $ | 11 | | | $ | 13 | | | $ | 4 | |
Lessor During 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 finance leases of $8 million and selling profit of $11 million. Also in 2020, DTE Electric, respectively.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 Registrants' future minimum lease payments under non-cancelable operating leases at December 31, 2018 were as follows:
| | | | | | | | | | | DTE Energy | | DTE Electric | | | (In millions) | | 2019 | $ | 42 |
| | $ | 17 |
| | 2020 | 30 |
| | 12 |
| | 2021 | 18 |
| | 10 |
| | 2022 | 11 |
| | 7 |
| | 2023 | 8 |
| | 5 |
| | 2024 and thereafter | 45 |
| | 29 |
| | | $ | 154 |
| | $ | 80 |
|
The Registrants are the lessee under certain capital leases related to software and information technology related equipment. Property under capital leases for the Registrants as of December 31, 2018 were as follows:
| | | | | | | | | | | DTE Energy | | DTE Electric | | | (In millions) | | Gross property under capital leases | $ | 18 |
| | $ | 18 |
| | Accumulated amortization of property under capital leases | $ | 7 |
| | $ | 7 |
|
Lessor
Topic 842 — DTE Energy leases a portion of its pipeline system to the Vector Pipeline through a finance lease contract that has been renewed through 2025, with additional renewal options reasonably certain to be exercised through 2040. DTE Energy owns a 40% interest in the Vector Pipeline. In addition, DTE Energy has an energy services agreement that expiresEnergy's net investment in 2026, of which a portionfinance leases relating to Vector Pipeline was $39 million at December 31, 2020, and is accounted for as aincluded in the finance lease.leases table below.
DTE Energy also leases various assets under operating leases for a pipeline, energy facilities and related equipment. Such leases are comprised of both fixed payments and variable payments which are contingent on volumes, with terms ranging from 32 to 24 years. Generally, the operating leases do not have renewal provisions or options to purchase the assets at the end of the lease. The operating leases generally do not have termination for convenience provisions. Termination may be allowed under specific circumstances stated in the lease contract, such as under an event of default. Certain of the finance and operating leases have lease terms that extend to the end of the estimated economic life of the leased assets, thereby resulting in no residual value. Any remaining residual values under the finance and operating leases are expected to be recovered through rates, renewals or new lease contracts. Residual values have been determined using the estimated economic life of the leased assets. The finance and operating leases do not contain residual value guarantees. Certain of the operating leases have both lease and non-lease components. The lease and non-lease components are allocated based upon estimated relative standalone selling prices.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
A lease is deemed to exist when the Registrants have provided other parties with the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration received. The right to control is deemed to occur when the Registrants have provided other parties with the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets. DTE Energy’s lease income associated with operating leases was as follows for the yearyears ended December 31, 2019:31: | | | | DTE Energy | | 2020 | | 2019 | | | | (In millions) | | (In millions) | Fixed payments(a) | $ | 65 |
| Fixed payments(a) | $ | 66 | | | $ | 65 | | | Variable payments(a) | 128 |
| Variable payments(a) | 124 | | | 128 | | | | | $ | 193 |
| | $ | 190 | | | $ | 193 | | |
| | (a) | (a)Includes $108 million and $130 million of lease payments reported in Operating Revenues and $82 million and $63 million of lease payments reported in Other income on DTE Energy's Consolidated Statements of Operations. |
DTE Energy’s minimum future rental revenues under operating leases for remaining periodsEnergy's Consolidated Statements of Operations as of December 31, 2020 and 2019, were as follows: | | | | | | | DTE Energy | | | (In millions) | | 2020 | $ | 64 |
| | 2021 | 62 |
| | 2022 | 22 |
| | 2023 | 22 |
| | 2024 | 22 |
| | 2025 and thereafter | 194 |
| | | $ | 386 |
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Depreciation expense associated with DTE Energy's property under operating leases was $26 million for the year ended December 31, 2019.
Property under operating leases for DTE Energy as of December 31, 2019 were as follows:
| | | | | | | DTE Energy | | | (In millions) | | Gross property under operating leases | $ | 445 |
| | Accumulated amortization of property under operating leases | $ | 173 |
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DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
| | | | | | | DTE Energy | | (In millions) | | 2021 | $ | 62 | | | 2022 | 22 | | | 2023 | 22 | | | 2024 | 22 | | | 2025 | 19 | | | 2026 and thereafter | 175 | | | $ | 322 | |
Depreciation expense associated with DTE Energy's property under operating leases was $27 million and $26 million for the years ended December 31, 2020 and 2019, respectively. The following is a summary of property under operating leases for DTE Energy as of December 31: | | | | | | | | | | | | | 2020 | | 2019 | | (In millions) | | Gross property under operating leases | $ | 447 | | | $ | 445 | | | Accumulated amortization of property under operating leases | $ | 197 | | | $ | 173 | |
The components of DTE Energy’s net investment in finance leases for remaining periods as of December 31, 2019 were2020 are as follows: | | | | | | | DTE Energy | | | (In millions) | | 2020 | $ | 9 |
| | 2021 | 4 |
| | 2022 | 4 |
| | 2023 | 5 |
| | 2024 | 5 |
| | 2025 and thereafter | 55 |
| | Total minimum future lease receipts | 82 |
| | Residual value of leased pipeline | 19 |
| | Less unearned income | 55 |
| | Net investment in finance lease | 46 |
| | Less current portion | 5 |
| | | $ | 41 |
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| | | | | | | | | DTE Energy | | (In millions) | | 2021 | $ | 24 | | | | | 2022 | 20 | | | | | 2023 | 19 | | | | | 2024 | 19 | | | | | 2025 | 19 | | | | | 2026 and thereafter | 253 | | | | | Total minimum future lease receipts | 354 | | | | | Residual value of leased pipeline | 17 | | | | | Less unearned income | 193 | | | | | Net investment in finance lease | 178 | | | | | Less current portion | 9 | | | | | $ | 169 | | | |
Interest income recognized under finance leases was $16 million and $5 million for the yearyears ended December 31, 2019.2020 and 2019, respectively, including $4 million relating to Vector Pipeline for both periods. Topic 840 — DTE Energy leases various assets under operating leases for energy facilities and related equipment.
DTE Energy’s minimum future rental revenues under non-cancelable operating leases as of December 31, 2018 were as follows:
| | | | | | | DTE Energy | | | (In millions) | | 2019 | $ | 66 |
| | 2020 | 66 |
| | 2021 | 64 |
| | 2022 | 20 |
| | 2023 | 20 |
| | 2024 and thereafter | 196 |
| | | $ | 432 |
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The amounts listed above do not include contingent rentals associated with the leased assets. DTE Energy had contingent rental revenues of $107 million, $91 million, and $101 million in 2018, 2017, and 2016, respectively.
DTE Energy leases a portion of its pipeline system to the Vector Pipeline through a capital lease contract that was set to expire in 2020, with renewal options extending for five years. DTE Energy owns a 40% interest in the Vector Pipeline. In addition, DTE Energy has 2 energy services agreements, for which a portion of are accounted for as capital leases. These agreements were set to expire in 2019 and 2026.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
The components of DTE Energy’s net investment in capital leases at December 31, 2018 were as follows:
| | | | | | | DTE Energy | | | (In millions) | | 2019 | $ | 10 |
| | 2020 | 9 |
| | 2021 | — |
| | 2022 | — |
| | 2023 | — |
| | 2024 and thereafter | 1 |
| | Total minimum future lease receipts | 20 |
| | Residual value of leased pipeline | 40 |
| | Less unearned income | 9 |
| | Net investment in capital lease | 51 |
| | Less current portion | 5 |
| | | $ | 46 |
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Property under operating leases for DTE Energy as of December 31, 2018 were as follows:
| | | | | | | DTE Energy | | | (In millions) | | Gross property under operating leases | $ | 447 |
| | Accumulated amortization of property under operating leases | $ | 148 |
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DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
NOTE 19 — COMMITMENTS AND CONTINGENCIES Environmental DTE Electric Air — DTE Electric is subject to the EPA ozone and fine particulate transport and acid rain regulations that limit power plant emissions of SO2 and NOX. The EPA and the State of Michigan have also issued emission reduction regulations relating to ozone, fine particulate, regional haze, mercury, and other air pollution. These rules have led to controls on fossil-fueled power plants to reduce SO2, NOX, mercury, and other emissions. Additional rulemakings may occur over the next few years which could require additional controls for SO2, NOX, and other hazardous air pollutants.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) 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 5 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 (Separate Agreement) between the Registrants and Sierra Club. The proceedings atConsent Decree was submitted and received by the U.S. District Court remain stayed whileand the parties discuss potential resolutionpublic 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. Sierra Club submitted the Separate Agreement for entry by the U.S. District Court on May 22, 2020; however, the United States opposed the entry of the matter.Separate Agreement. After reviewing the matter, the U.S. District Court determined that the Separate Agreement is a private settlement agreement and therefore, it should not be incorporated into the Consent Decree or entered by the Court. Based on this, Sierra Club voluntarily withdrew its initial complaint in the case, acknowledging that it has resolved the matter privately with DTE Electric by way of the Separate Agreement. On December 3, 2020, the U.S. District Court entered an Opinion and Order Granting Intervenor's Motion for Voluntary Dismissal. As of December 31, 2020, $5 million remains accrued for the settlement with spend expected to begin in early 2021. The Separate Agreement also requires DTE to contribute at least $2 million to community based environmental projects, no later than June 30, 2021. 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. Depending upon the outcome of the litigation and further discussions with the EPA regarding the 2 NOVs/FOVs, DTE Electric could beis required to install additional pollution control equipmentretire, repower, refuel, or retrofit units at some or all of the4 power plants by the dates set forth in question,the Consent Decree and implement early retirement of facilities where control equipment is not economical, engage ina supplemental environmental programs, and/or pay fines.project. The Registrants do not expect the outcome of this matter to have a material impact on their Consolidated Financial Statements.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
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 revised commitment for its electric utility operations to reduce carbon emissions 32% by the early 2020s,2023, 50% by 2030, and 80% by 2040 from 2005 carbon emissions levels, or its goal of net 0 emissions for its electric utility operations by 2050 for DTE Electric, from the 2005 carbon emissions levels.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 through 2019.billion. DTE Electric does 0t anticipate additional capital expenditures for air pollution requirements through 2026,2025, 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 National Pollutant Discharge Elimination System (NPDES)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 3 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 aboveground storage tank locations. The findings of these investigations indicated that the estimated cost to remediate these sites is expected to be incurred over the next several years. At December 31, 20192020 and 2018,2019, DTE Electric had $8$10 million and $7$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.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
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, September 2020, and July 2018.November 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 3 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 the installationongoing 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. At other facilities, 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 requires ash laden waters be moved from earthen basins to steelamends certain reporting requirements and concrete tanks. DTE Electric has estimated the impact of the current rule to be $608 million. CCR website requirements. On December 2, 2019 a proposedNovember 12, 2020, an additional revision to the CCR Rule "A Holistic Approach to Closure Part B: Alternate Demonstration for Unlined Surface Impoundments" was published in the Federal Register to address the D.C. Circuit’s 2018 decision regarding CCR impoundments that are not lined with an engineered liner system. The rule proposes that all CCR impoundments that do not meet the engineered liner requirements must close by specific dates, and it further confirms that all clay lined impoundments are viewed as unlined. The EPA is also preparingprovides a rulemaking, expected to be proposed early in 2020, that will provide mechanismsprocess to determine if certain unlined impoundments consist of an alternative liner systemssystem that may be as protective as the current liners specified in the CCR rule.rule, and therefore may continue to operate. DTE Electric is currently evaluating options based on the range of outcomes of the current proposed rule and the anticipated proposed ruleboth final rules 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 will submithas submitted to the EPA for approval to fully regulate the CCR program in Michigan in lieu of a Federal permit program. In November 2015,October 2020, the EPA finalizedpublished in the Federal Register the final version of the ELG Reconsideration Rule (Final Rule) which updates the 2015 ELG Rule (2015 Rule). The Final Rule establishes the technology-based effluent limitations guidelines and standards applicable to flue gas desulfurization (FGD) wastewater and bottom ash transport water. The EPA set the applicability dates for the steam electric power generating industry which requires additional controlsbottom ash transport water and FGD wastewater retrofits to be installed between 2018"as soon as possible" beginning October 13, 2021 and 2023.no later than December 31, 2025. Compliance schedules for individual facilities and individual waste streams are determined through issuance of new National Pollutant Discharge Elimination System (NPDES)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, 2021.2021 based on the 2015 Rule. Due to completion of the Final Rule in 2020, the compliance deadlines within the NPDES permit for Belle River Power Plant will be revised accordingly. 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)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 November 22, 2019,October 13, 2020, the EPA issued a proposed rule to revisefinalized the technology-based effluent limitations guidelines and standards applicable to flue gas desulfurizationELG 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 requirementsstrategies and final deadlinesmake 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 and FGD wastewater, and total ELG relatedsystem to achieve compliance costs will not be known untilwith the EPA completes its reconsiderationfinal rule. DTE Electric has estimated the impact of the CCR and ELG Rule expected by the endrules to be $721 million of 2020.capital expenditures, including $601 million through 2025.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) 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 0 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 8 of the MGP sites is complete and the sites are closed. DTE Gas has also completed partial closure of 4 additional sites. Cleanup activities associated with the remaining sites will continue over the next several years. The MPSC has established a cost deferral and rate recovery mechanism for investigation and remediation costs incurred at former MGP sites. In addition to the MGP sites, DTE Gas is also in the process of cleaning up other contaminated sites, including gate stations, gas pipeline releases, and underground storage tank locations. As of December 31, 20192020 and 2018,2019, 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.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
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 violationan FOV 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. In September 2020, the EPA issued another FOV alleging EES Coke's 2018 and 2019 SO2 emissions exceeded projections and hence violated non-attainment new source review requirements. EES Coke evaluated the EPA's alleged violations and believes that the permits approved by EGLE complied with the Clean Air Act. EES Coke also responded to the EPA's September 2020 allegations demonstrating its actual emissions are compliant with non-attainment new source review requirements. Discussions with the EPA are ongoing. At the present time, DTE Energy does not believecannot predict the outcome or financial impact of this will haveFOV. In January 2021, DTE Midstream announced a material financial impact.goal to achieve net 0 greenhouse gas emissions by 2050, including a 30% reduction in carbon emissions in the next decade. To achieve this goal, DTE Midstream plans comprehensive integration of carbon capture strategies to reduce carbon emissions in its operations. Other In 2010, the EPA finalized a new one-hour SO2 ambient air quality standard that requires states to submit plans and associated timelines for non-attainment areas that demonstrate attainment with the new SO2 standard in phases. Phase 1 addresses non-attainment areas designated based on ambient monitoring data. Phase 2 addresses non-attainment areas with large sources of SO2 and modeled concentrations exceeding the National Ambient Air Quality Standards for SO2. Phase 3 addresses smaller sources of SO2 with modeled or monitored exceedances of the new SO2 standard. Michigan's Phase 1 non-attainment area 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 SO2 emissions in these areas, including DTE Electric power plants and DTE Energy's Michigan coke battery facility. As part of the state implementation plan (SIP)SIP process, DTE Energy has worked with EGLE to develop air permits reflecting significant SO2 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. State implementation plan submittal and EPA approval describingEGLE has not made a final determination on SIP strategy for this area, pending the control strategy and timeline for demonstrating compliance with the new SO2 standard is the next step in the process and is expected to be completed by first quarter 2020. DTE Energy is currently working with EGLE to develop the required SIP.EPA's review of a clean data determination request. Until agency plans are final, DTE Energy is unable to determine the full impact of the SIP strategy.impacts.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) 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 December 31, 20192020 was approximately $400 million. Payment under these guarantees areis 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 December 31, 20192020 was $549$581 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$209 million and $360$335 million at December 31, 2019,2020, 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 October 2018, NEXUS Pipeline was placed in service. The amount of each guarantee decreases annually as payments are made by NEXUS to each of the aforementioned counterparties.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
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 December 31, 2019,2020, 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 $56$50 million at December 31, 2019.2020. Payments under these guarantees are considered remote. DTE Energy isThe Registrants are periodically required to obtain performance surety bonds in support of obligations to various governmental entities and other companies in connection with its operations. As of December 31, 2019,2020, DTE Energy had $109$125 million of performance bonds outstanding.outstanding, including $69 million for DTE Electric. In the event that such bonds are called for nonperformance, DTE Energythe Registrants would be obligated to reimburse the issuer of the performance bond. DTE Energy isThe 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 paymentspayment under the line of credit at December 31, 20192020 is $54$55 million. The funding of a loan under the terms of the credit facility is considered remote.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) Labor Contracts There are several bargaining units for DTE Energy subsidiaries' approximate 5,3005,200 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 As of December 31, 2019,2020, the Registrants were party to numerous long-term purchase commitments relating to a variety of goods and services required for their businesses. These agreements primarily consist of fuel supply commitments and renewable energy contracts for the Registrants, as well as energy trading contracts for DTE Energy. The Registrants estimate the following commitments from 20202021 through 2051 for DTE Energy, and 20202021 through 20392051 for DTE Electric, as detailed in the following table: | | | | | | | | | | | DTE Energy | | DTE Electric | | | (In millions) | | 2020 | $ | 3,152 |
| | $ | 1,556 |
| | 2021 | 1,055 |
| | 299 |
| | 2022 | 561 |
| | 95 |
| | 2023 | 418 |
| | 96 |
| | 2024 | 365 |
| | 96 |
| | 2025 and thereafter | 1,503 |
| | 688 |
| | | $ | 7,054 |
| | $ | 2,830 |
|
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
| | | | | | | | | | | | | DTE Energy | | DTE Electric | | (In millions) | | 2021 | $ | 2,998 | | | $ | 1,132 | | | 2022 | 1,142 | | | 246 | | | 2023 | 804 | | | 226 | | | 2024 | 520 | | | 159 | | | 2025 | 397 | | | 209 | | | 2026 and thereafter | 1,634 | | | 969 | | | $ | 7,495 | | | $ | 2,941 | |
Utility capital expenditures, expenditures for non-utility businesses, and contributions to equity method investees will be approximately $4.5$4.2 billion and $2.6$3.0 billion in 20202021 for DTE Energy and DTE Electric, respectively. The Registrants have made certain commitments in connection with the estimated 20202021 annual capital expenditures and contributions to equity method investees. Bankruptcies DTE Energy's Power and Industrial Projects segment holds ownership interests in, and operates, 5 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. AsPG&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 year ended December 31, 2019, PG&Es account is substantially current2020 include a reduction in DTE Electric sales volumes from commercial and outstanding accounts receivable from PG&E are not material. Therefore,industrial customers and an increase in residential customer sales volumes. This shift contributed to a net reduction in DTE Energy determined 0 reserve was necessary. As ofElectric sales volumes for the year ended December 31, 2019,2020, but the book valueimpact 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 long-lived assets used in producing electric output for salecertain employees critical to PG&E was approximately $101 million.continued operations. The Registrants implemented certain cost savings initiatives to offset some of these impacts, to the extent they did not affect safety or reliability of service. Impacts from the COVID-19 pandemic did not have a material effect on the Registrants' capital spending. For non-utility businesses, COVID-19 has primarily impacted the Power and Industrial Projects segment, alsocontributing 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 equity investments, including a note receivable, of approximately $74 millionnot been significantly impacted due to related decreases in entities that sell power to PG&E. In January 2019, following the bankruptcy filing, Operating expenses.
DTE Energy performed an impairment analysis on its long-lived assets. Based on its undiscountedCompany — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) 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 flow projections, DTE Energy determined it did 0tflows resulting from the COVID-19 pandemic, there have an impairment lossbeen no material adjustments or reserves deemed necessary to the Consolidated Financial Statements as of December 31, 2018. DTE Energy also determined there was 0t an other-than-temporary decline in its equity investments. DTE has not identified subsequent facts or circumstances that would cause a change to these conclusions through December 31, 2019. DTE Energy’s assumptions and conclusions may change, and it could have impairment losses if any2020. The Registrants cannot predict the future impacts of the terms ofCOVID-19 pandemic on the contracts are not honored by PG&E or the contracts are rejected through the bankruptcy process.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 10 and 14 to the Consolidated Financial Statements, "Regulatory Matters" and "Financial and Other Derivative Instruments," respectively.
NOTE 20 — NUCLEAR OPERATIONS Property Insurance DTE Electric maintains property insurance policies specifically for the Fermi 2 plant. These policies cover such items as replacement power and property damage. NEIL is the primary supplier of the insurance policies. DTE Electric maintains a policy for extra expenses, including replacement power costs necessitated by Fermi 2’s unavailability due to an insured event. This policy has a 12-week waiting period and provides an aggregate $490 million of coverage over a three-year period. DTE Electric has $1.5 billion in primary coverage and $1.25 billion of excess coverage for stabilization, decontamination, debris removal, repair and/or replacement of property, and decommissioning. The combined coverage limit for total property damage is $2.75 billion. The total limit for property damage for non-nuclear events is $2.0$1.8 billion and an aggregate of $328 million of coverage for extra expenses over a two-year period. On January 13, 2015,December 20, 2019, the Terrorism Risk Insurance Program Reauthorization Act of 20152019 was signed, extending TRIA through December 31, 2020.2027. For multiple terrorism losses caused by acts of terrorism not covered under the TRIA occurring within one year after the first loss from terrorism, the NEIL policies would make available to all insured entities up to $3.2 billion, plus any amounts recovered from reinsurance, government indemnity, or other sources to cover losses. Under NEIL policies, DTE Electric could be liable for maximum assessments of up to $42$43 million per event if the loss associated with any one event at any nuclear plant should exceed the accumulated funds available to NEIL.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
Public Liability Insurance As required by federal law, DTE Electric maintains $450 million of public liability insurance for a nuclear incident. For liabilities arising from a terrorist act outside the scope of TRIA, the policy is subject to one industry aggregate limit of $300 million. Further, under the Price-Anderson Amendments Act of 2005, deferred premium charges up to $138 million could be levied against each licensed nuclear facility, but not more than $20 million per year per facility. Thus, deferred premium charges could be levied against all owners of licensed nuclear facilities in the event of a nuclear incident at any of these facilities.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) Nuclear Fuel Disposal Costs In accordance with the Federal Nuclear Waste Policy Act of 1982, DTE Electric has a contract with the DOE for the future storage and disposal of spent nuclear fuel from Fermi 2 that required DTE Electric to pay the DOE a fee of 1 mill per kWh of Fermi 2 electricity generated and sold. The fee was a component of nuclear fuel expense. The 1 mill per kWh DOE fee was reduced to 0 effective May 16, 2014. The DOE's Yucca Mountain Nuclear Waste Repository program for the acceptance and disposal of spent nuclear fuel was terminated in 2011. DTE Electric is a party in the litigation against the DOE for both past and future costs associated with the DOE's failure to accept spent nuclear fuel under the timetable set forth in the Federal Nuclear Waste Policy Act of 1982. In July 2012, DTE Electric executed a settlement agreement with the federal government for costs associated with the DOE's delay in acceptance of spent nuclear fuel from Fermi 2 for permanent storage. The settlement agreement, including extensions, provides for a claims process and payment of delay-related costs experienced by DTE Electric through 2019. DTE Electric's claims are being settled and paid on a timely basis. The settlement proceeds reduce the cost of the dry cask storage facility assets and provide reimbursement for related operating expenses. DTE Electric currently employs a spent nuclear fuel storage strategy utilizing a fuel pool and a dry cask storage facility. The spent nuclear fuel storage strategy is expected to provide sufficient spent fuel storage capability for the life of the plant as defined by DTE Electric's operating license agreement. The federal government continues to maintain its legal obligation to accept spent nuclear fuel from Fermi 2 for permanent storage. Issues relating to long-term waste disposal policy and to the disposition of funds contributed by DTE Electric ratepayers to the federal waste fund await future governmental action.
NOTE 21 — RETIREMENT BENEFITS AND TRUSTEED ASSETS DTE Energy's subsidiary, DTE Energy Corporate Services, LLC, sponsors defined benefit pension plans and other postretirement plans covering certain employees of the Registrants. The table below represents the pension and other postretirement benefit plans of each Registrant at December 31, 2019:2020: | | | | | | | | | | | | | Registrants | | DTE Energy | | DTE Electric | | Qualified Pension Plans | | | | | DTE Energy Company Retirement Plan | X | | X | | DTE Gas Company Retirement Plan for Employees Covered by Collective Bargaining Agreements | X | | | Shenango Inc. Pension Plan(a) | X | | | NonqualifiedNon-qualified Pension Plans | | | | DTE Energy Company Supplemental Retirement Plan(b) | X | | X | DTE Energy Company Executive Supplemental Retirement Plan(a)(b) | X | | X | | DTE Energy Company Supplemental Severance Benefit Plan | X | | | | Other Postretirement Benefit Plans | | | | | The DTE Energy Company Comprehensive Non-Health Welfare Plan | X | | X | | The DTE Energy Company Comprehensive Retiree Group Health Care Plan | X | | X | | DTE Supplemental Retiree Benefit Plan | X | | X | | DTE Energy Company Retiree Reimbursement Arrangement Plan | X | | X |
_____________________________________(a)Sponsored by Shenango, LLC
| | (a) | Sponsored by the DTE Energy subsidiary, DTE Energy Holding Company. |
(b)Sponsored by DTE Energy Company
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
DTE Electric participates in various plans that provide pension and other postretirement benefits for DTE Energy and its affiliates. The plans are sponsored by the LLC. DTE Electric accounts for its participation in DTE Energy's qualified and nonqualifiednon-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. Pension Plan Benefits DTE Energy has qualified defined benefit retirement plans for eligible represented and non-represented employees. The plans are noncontributory and provide traditional retirement benefits based on the employee's years of benefit service, average final compensation, and age at retirement. In addition, certain represented and non-represented employees are covered under cash balance provisions that determine benefits on annual employer contributions and interest credits. DTE Energy also maintains supplemental nonqualified,non-qualified, noncontributory, retirement benefit plans for certain management employees. These plans provide for benefits that supplement those provided by DTE Energy’s other retirement plans. Net pension cost for DTE Energy includes the following components: | | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | (In millions) | | Service cost | $ | 99 | | | $ | 84 | | | $ | 99 | | | Interest cost | 186 | | | 219 | | | 202 | | | Expected return on plan assets | (334) | | | (325) | | | (329) | | | Amortization of: | | | | | | | Net actuarial loss | 171 | | | 131 | | | 176 | | | Prior service cost | 1 | | | 1 | | | 0 | | | Settlements | 25 | | | 2 | | | 0 | | | Net pension cost | $ | 148 | | | $ | 112 | | | $ | 148 | |
| | | | | | | | | | | | | | | 2019 | | 2018 | | 2017 | | | (In millions) | | Service cost | $ | 84 |
| | $ | 99 |
| | $ | 92 |
| | Interest cost | 219 |
| | 202 |
| | 214 |
| | Expected return on plan assets | (325 | ) | | (329 | ) | | (311 | ) | | Amortization of: | | | | | | | Net actuarial loss | 133 |
| | 176 |
| | 176 |
| | Prior service cost | 1 |
| | — |
| | 1 |
| | Net pension cost | $ | 112 |
| | $ | 148 |
| | $ | 172 |
|
| | | | | | | | | | | | | 2020 | | 2019 | | (In millions) | | Other changes in plan assets and benefit obligations recognized in Regulatory assets and Other comprehensive income (loss) | | | | | Net actuarial loss | $ | 137 | | | $ | 156 | | | Amortization of net actuarial loss | (193) | | | (133) | | | | | | | Amortization of prior service cost | (1) | | | (1) | | | Total recognized in Regulatory assets and Other comprehensive income (loss) | $ | (57) | | | $ | 22 | | | Total recognized in net periodic pension cost, Regulatory assets, and Other comprehensive income (loss) | $ | 91 | | | $ | 134 | |
| | | | | | | | | | | 2019 | | 2018 | | | (In millions) | | Other changes in plan assets and benefit obligations recognized in Regulatory assets and Other comprehensive income (loss) | | | | | Net actuarial loss | $ | 156 |
| | $ | 125 |
| | Amortization of net actuarial loss | (133 | ) | | (176 | ) | | Amortization of prior service cost | (1 | ) | | — |
| | Total recognized in Regulatory assets and Other comprehensive income (loss) | $ | 22 |
| | $ | (51 | ) | | Total recognized in net periodic pension cost, Regulatory assets, and Other comprehensive income (loss) | $ | 134 |
| | $ | 97 |
| | Estimated amounts to be amortized from Regulatory assets and Accumulated other comprehensive income (loss) into net periodic benefit cost during next fiscal year | | | | | Net actuarial loss | $ | 171 |
| | $ | 131 |
| | Prior service cost | $ | 1 |
| | $ | 1 |
|
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
The following table reconciles the obligations, assets, and funded status of the plans as well as the amounts recognized as prepaid pension cost or pension liability in DTE Energy's Consolidated Statements of Financial Position at December 31: | | | | | | | | | | | | | DTE Energy | | 2020 | | 2019 | | (In millions) | | Accumulated benefit obligation, end of year | $ | 5,843 | | | $ | 5,387 | | | Change in projected benefit obligation | | | | | Projected benefit obligation, beginning of year | $ | 5,810 | | | $ | 5,124 | | | Service cost | 99 | | | 84 | | | Interest cost | 186 | | | 219 | | | | | | | Actuarial loss | 619 | | | 719 | | | | | | | Special termination benefits | 3 | | | 0 | | | Benefits paid | (353) | | | (336) | | | Settlements | (60) | | | 0 | | | Projected benefit obligation, end of year | $ | 6,304 | | | $ | 5,810 | | | Change in plan assets | | | | | Plan assets at fair value, beginning of year | $ | 4,993 | | | $ | 4,273 | | | Actual return on plan assets | 815 | | | 888 | | | Company contributions | 102 | | | 168 | | | Benefits paid | (353) | | | (336) | | | Settlements | (60) | | | 0 | | | Plan assets at fair value, end of year | $ | 5,497 | | | $ | 4,993 | | | Funded status | $ | (807) | | | $ | (817) | | | Amount recorded as: | | | | | Current liabilities | $ | (10) | | | $ | (9) | | | Noncurrent liabilities | (797) | | | (808) | | | $ | (807) | | | $ | (817) | | | Amounts recognized in Accumulated other comprehensive income (loss), pre-tax | | | | | Net actuarial loss | $ | 142 | | | $ | 153 | | | Prior service cost | 3 | | | 4 | | | $ | 145 | | | $ | 157 | | Amounts recognized in Regulatory assets(a) | | | | | Net actuarial loss | $ | 1,949 | | | $ | 1,995 | | | Prior service credit | (11) | | | (12) | | | $ | 1,938�� | | | $ | 1,983 | |
| | | | | | | | | | | DTE Energy | | | 2019 | | 2018 | | | (In millions) | | Accumulated benefit obligation, end of year | $ | 5,387 |
| | $ | 4,779 |
| | Change in projected benefit obligation | | | | | Projected benefit obligation, beginning of year | $ | 5,124 |
| | $ | 5,576 |
| | Service cost | 84 |
| | 99 |
| | Interest cost | 219 |
| | 202 |
| | Actuarial (gain) loss | 719 |
| | (438 | ) | | Benefits paid | (336 | ) | | (315 | ) | | Projected benefit obligation, end of year | $ | 5,810 |
| | $ | 5,124 |
| | Change in plan assets | | | | | Plan assets at fair value, beginning of year | $ | 4,273 |
| | $ | 4,636 |
| | Actual return on plan assets | 888 |
| | (233 | ) | | Company contributions | 168 |
| | 185 |
| | Benefits paid | (336 | ) | | (315 | ) | | Plan assets at fair value, end of year | $ | 4,993 |
| | $ | 4,273 |
| | Funded status | $ | (817 | ) | | $ | (851 | ) | | Amount recorded as: | | | | | Current liabilities | $ | (9 | ) | | $ | (14 | ) | | Noncurrent liabilities | (808 | ) | | (837 | ) | | | $ | (817 | ) | | $ | (851 | ) | | Amounts recognized in Accumulated other comprehensive income (loss), pre-tax | | | | | Net actuarial loss | $ | 153 |
| | $ | 152 |
| | Prior service cost | 4 |
| | 5 |
| | | $ | 157 |
| | $ | 157 |
| Amounts recognized in Regulatory assets(a) | | | | | Net actuarial loss | $ | 1,995 |
| | $ | 1,973 |
| | Prior service credit | (12 | ) | | (12 | ) | | | $ | 1,983 |
| | $ | 1,961 |
|
______________________________________(a)See Note 10 to the Consolidated Financial Statements, "Regulatory Matters." | | (a) | See Note 10 to the Consolidated Financial Statements, "Regulatory Matters." |
The increases in DTE Energy's pension benefit obligation for the years ended December 31, 2020 and 2019 were primarily due to actuarial loss in both periods, which was primarily driven by decreases in discount rates. The increase in the pension benefit obligation in 2020 was partially offset by a one-time settlement described below. In December 2020, a DTE Energy non-regulated qualified pension plan used plan assets to purchase an annuity contract from a third-party insurance company. The annuity contract will be used to settle the benefit obligations for certain plan participants. The transaction resulted in a $60 million reduction to the plan's projected benefit obligation and plan assets, as well as a one-time settlement charge of $22 million. The settlement charge is a component of net pension cost and is included in Non-operating retirement benefits, net in DTE Energy's Consolidated Statements of Operations for the year ended December 31, 2020.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) The Registrants' policy is to fund pension costs by contributing amounts consistent with the provisions of the Pension Protection Act of 2006, and additional amounts when it deems appropriate. The following table provides contributions to the qualified pension plans in: | | | | | | | | | | | | | | | 2019 | | 2018 | | 2017 | | | (In millions) | | DTE Energy | $ | 150 |
| | $ | 175 |
| | $ | 223 |
| | DTE Electric | $ | 100 |
| | $ | 175 |
| | $ | 185 |
|
| | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | (In millions) | | DTE Energy | $ | 92 | | | $ | 150 | | | $ | 175 | | | DTE Electric | $ | 60 | | | $ | 100 | | | $ | 175 | |
During 2019, DTE Energy contributedEnergy's contributions of $92 million in 2020 included $82 million of common stock and $10 million of cash. Details of the following amountscontribution of DTE Energy common stock to the DTE Energy Company Affiliates Employee Benefit Plans Master Trust:Trust are as follows:
| | | | | | | | | | | Date | | Number of Shares | | Price per Share | | Amount | | | | | | | | (In millions) | | March 5, 2019 | | 814,597 | | $122.76 | | $ | 100 |
|
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
| | | | | | | | | | | | | | | | | | | | | | 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 $100$60 million and $22 million, respectively, in March 2019. DTE Energy made additional cash contributions of $50 million to the qualified pension plans in 2019. September 2020. At the discretion of management and depending upon financial market conditions, DTE Energy anticipates making up to $185$107 million in contributions, including $160 million of DTE Electric contributions to the qualified pension plans in 2020.2021, including up to $100 million of equity contributions to the qualified pension plans at DTE Electric. DTE Energy's subsidiaries are responsible for their share of qualified and nonqualifiednon-qualified pension benefit costs. DTE Electric's allocated portion of pension benefit costs included in capital expenditures and operating and maintenance expense were $106 million, $93 million, for the year ended December 31, 2019,and $120 million for the yearyears ended December 31, 2020, 2019, and 2018, and $136 million for the year ended December 31, 2017.respectively. These amounts include recognized contractual termination benefit charges, curtailment gains, and settlement charges. At December 31, 2019,2020, the benefits related to DTE Energy's qualified and nonqualifiednon-qualified pension plans expected to be paid in each of the next five years and in the aggregate for the five fiscal years thereafter are as follows: | | | | | | | (In millions) | | 2020 | $ | 311 |
| | 2021 | 319 |
| | 2022 | 324 |
| | 2023 | 330 |
| | 2024 | 334 |
| | 2025-2029 | 1,723 |
| | Total | $ | 3,341 |
|
| | | | | | | (In millions) | | 2021 | $ | 352 | | | 2022 | 363 | | | 2023 | 368 | | | 2024 | 352 | | | 2025 | 360 | | | 2026-2030 | 1,757 | | | Total | $ | 3,552 | |
Assumptions used in determining the projected benefit obligation and net pension costs of DTE Energy are: | | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | Projected benefit obligation | | | | | | | Discount rate | 2.57% | | 3.28% | | 4.40% | | Rate of compensation increase | 3.80% | | 3.85% | | 3.85% | | Cash balance interest crediting rate | 2.00% | | 3.30% | | 3.70% | | Net pension costs | | | | | | | Discount rate | 3.28% | | 4.40% | | 3.70% | | Rate of compensation increase | 3.85% | | 3.85% | | 3.85% | | Expected long-term rate of return on plan assets | 7.10% | | 7.30% | | 7.50% | | Cash balance interest crediting rate | 3.30% | | 3.70% | | 3.70% |
| | | | | | | | | 2019 | | 2018 | | 2017 | | Projected benefit obligation | | | | | | | Discount rate | 3.28% | | 4.40% | | 3.70% | | Rate of compensation increase | 4.98% | | 4.98% | | 4.98% | | Net pension costs | | | | | | | Discount rate | 4.40% | | 3.70% | | 4.25% | | Rate of compensation increase | 4.98% | | 4.98% | | 4.65% | | Expected long-term rate of return on plan assets | 7.30% | | 7.50% | | 7.50% |
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) DTE Energy employs a formal process in determining the long-term rate of return for various asset classes. Management reviews historic financial market risks and returns and long-term historic relationships between the asset classes of equities, fixed income, and other assets, consistent with the widely accepted capital market principle that asset classes with higher volatility generate a greater return over the long-term. Current market factors such as inflation, interest rates, asset class risks, and asset class returns are evaluated and considered before long-term capital market assumptions are determined. The long-term portfolio return is also established employing a consistent formal process, with due consideration of diversification, active investment management, and rebalancing. Peer data is reviewed to check for reasonableness. As a result of this process, the Registrants have long-term rate of return assumptions for the pension plans of 7.10%7.00% and other postretirement benefit plans of 7.20%6.70% for 2020.2021. The Registrants believe these rates are a reasonable assumption for the long-term rate of return on plan assets for 20202021 given the current investment strategy.
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
The DTE Energy Company Affiliates Employee Benefit Plans Master Trust employs a liability driven investment program whereby the characteristics of plan liabilities are considered when determining investment policy. Risk tolerance is established through consideration of future plan cash flows, plan funded status, and corporate financial considerations. The investment portfolio contains a diversified blend of equity, fixed income, and other investments. Furthermore, equity investments are diversified across U.S. and non-U.S. stocks and large and small market capitalizations. Fixed income investments generally include U.S. Treasuries, other governmental debt, diversified corporate bonds, bank loans, and mortgage-backed securities. Other investments are used to enhance long-term returns while improving portfolio diversification. Derivatives may be utilized in a risk controlled manner, to potentially increase the portfolio beyond the market value of invested assets and/or reduce portfolio investment risk. Investment risk is measured and monitored on an ongoing basis through annual liability measurements, periodic asset/liability studies, and quarterly investment portfolio reviews. Target allocations for DTE Energy's pension plan assets as of December 31, 20192020 are listed below: | | | | | | | U.S. Large Capitalization (Cap) Equity Securities | 1618 | % | | U.S. Small Cap and Mid Cap Equity Securities | 43 |
| | Non-U.S. Equity Securities | 1516 |
| | Fixed Income Securities | 4238 |
| | | | Hedge Funds and Similar Investments | 14 |
| | Private Equity and Other | 911 |
| | 100 | % |
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) The following tables provide the fair value measurement amounts for DTE Energy's pension plan assets at December 31, 20192020 and 20182019(a): | | | | December 31, 2019 | | December 31, 2018 | | December 31, 2020 | | December 31, 2019 | | | Level 1 | | Level 2 | | Other(b) | | Total | | Level 1 | | Level 2 | | Other(b) | | Total | | Level 1 | | Level 2 | | | Other(b) | | Total | | Level 1 | | Level 2 | | | Other(b) | | Total | | DTE Energy asset category: | (In millions) | DTE Energy asset category: | (In millions) | Short-term Investments(c) | $ | 99 |
| | $ | — |
| | $ | — |
| | $ | 99 |
| | $ | — |
| | $ | 27 |
| | $ | — |
| | $ | 27 |
| Short-term Investments(c) | $ | 92 | | | $ | 0 | | | | $ | 0 | | | $ | 92 | | | $ | 99 | | | $ | 0 | | | | $ | 0 | | | $ | 99 | | | Equity Securities | | | | | | | | | | | | | | | | Equity Securities | | | | | | Domestic(d) | 172 |
| | — |
| | 870 |
| | 1,042 |
| | 729 |
| | 4 |
| | — |
| | 733 |
| Domestic(d) | 167 | | | 0 | | | | 1,093 | | | 1,260 | | | 172 | | | 0 | | | | 870 | | | 1,042 | | International(e) | 387 |
| | — |
| | 322 |
| | 709 |
| | 337 |
| | 9 |
| | 240 |
| | 586 |
| International(e) | 100 | | | 0 | | | | 791 | | | 891 | | | 387 | | | 0 | | | | 322 | | | 709 | | | Fixed Income Securities | | | | | | | | | | | | | | | | Fixed Income Securities | | | | | | Governmental(f) | 569 |
| | — |
| | — |
| | 569 |
| | — |
| | 868 |
| | — |
| | 868 |
| Governmental(f) | 459 | | | 95 | | | | 0 | | | 554 | | | 569 | | | 0 | | | | 0 | | | 569 | | Corporate(g) | — |
| | 1,452 |
| | — |
| | 1,452 |
| | 6 |
| | 1,024 |
| | — |
| | 1,030 |
| Corporate(g) | 0 | | | 1,404 | | | | 0 | | | 1,404 | | | 0 | | | 1,452 | | | | 0 | | | 1,452 | | | Hedge Funds and Similar Investments(h) | 169 |
| | — |
| | 502 |
| | 671 |
| | 88 |
| | — |
| | 542 |
| | 630 |
| Hedge Funds and Similar Investments(h) | 238 | | | 61 | | | | 411 | | | 710 | | | 169 | | | 0 | | | | 502 | | | 671 | | Private Equity and Other(i) | — |
| | — |
| | 451 |
| | 451 |
| | — |
| | — |
| | 399 |
| | 399 |
| Private Equity and Other(i) | 0 | | | 0 | | | | 586 | | | 586 | | | 0 | | | 0 | | | | 451 | | | 451 | | | | DTE Energy Total | $ | 1,396 |
| | $ | 1,452 |
| | $ | 2,145 |
| | $ | 4,993 |
| | $ | 1,160 |
| | $ | 1,932 |
| | $ | 1,181 |
| | $ | 4,273 |
| DTE Energy Total | $ | 1,056 | | | $ | 1,560 | | | | $ | 2,881 | | | $ | 5,497 | | | $ | 1,396 | | | $ | 1,452 | | | | $ | 2,145 | | | $ | 4,993 | |
| | (a) | (a)For a description of levels within the fair value hierarchy, see Note 13 to the Consolidated Financial Statements, "Fair Value." |
| | (b) | Amounts represent assets valued at NAV as a practical expedient for fair value. |
| | (c) | This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category are obtained from quoted prices in actively traded markets or valuations from brokers or pricing services. |
| | (d) | This category represents portfolios of large, medium and small capitalization domestic equities. Investments in this category include exchange-traded securities for which unadjusted quoted prices can be obtained and exchange-traded securities held in a commingled fund classified as NAV assets. |
| | (e) | This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category are exchange-traded securities whereby unadjusted quoted prices can be obtained. Exchange-traded securities held in a commingled fund are classified as NAV assets. |
| | (f) | This category includes U.S. Treasuries, bonds, and other governmental debt. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. |
| | (g) | This category primarily consists of corporate bonds from diversified industries, bank loans, and mortgage backed securities. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. |
| | (h) | This category utilizes a diversified group of strategies that attempt to capture financial market inefficiencies and includes publicly traded mutual funds, commingled funds and limited partnership funds. Pricing for mutual funds in this category is obtained from quoted prices in actively traded markets. Commingled funds and limited partnership funds are classified as NAV assets. |
| | (i) | This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in real estate and private debt. All pricing for investments in this category are classified as NAV assets. |
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements, — (Continued)
"Fair Value."
(c)This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category are obtained from quoted prices in actively traded markets. (d)This category represents portfolios of large, medium and small capitalization domestic equities. Investments in this category include exchange-traded securities for which unadjusted quoted prices can be obtained and exchange-traded securities held in a commingled fund classified as NAV assets. (e)This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category include exchange-traded securities for which unadjusted quoted prices can be obtained and exchange-traded securities held in a commingled fund classified as NAV assets. (f)This category includes U.S. Treasuries, bonds, and other governmental debt. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. (g)This category primarily consists of corporate bonds from diversified industries, bank loans, and mortgage backed securities. Pricing for investments in this category is obtained from quotations from broker or pricing services. (h)This category utilizes a diversified group of strategies that attempt to capture financial market inefficiencies and includes publicly traded mutual funds, commingled funds and limited partnership funds. Pricing for mutual funds in this category is obtained from quoted prices in actively traded markets. Commingled funds and limited partnership funds are classified as NAV assets. (i)This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in real estate and private debt. All pricing for investments in this category are classified as NAV assets. The pension trust holds debt and equity securities directly and indirectly through commingled funds. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. The commingled funds hold exchange-traded equity or debt securities and are valued based on stated NAVs. Non-exchange traded fixed income securities are valued by the trustee based upon quotations available from brokers or pricing services. A primary price source is identified by asset type, class, or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustee challenges an assigned price and determines that another price source is considered preferable. DTE Energy has obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices. Other Postretirement Benefits The Registrants participate in defined benefit plans sponsored by the LLC that provide certain other postretirement health care and life insurance benefits for employees who are eligible for these benefits. The Registrants' policy is to fund certain trusts to meet its other postretirement benefit obligations. DTE Energy did not make any contributions to these trusts during 20192020 and does not anticipate making any contributions to the trusts in 2020.2021. DTE Energy and DTE Electric offer a defined contribution VEBA for eligible represented and non-represented employees, in lieu of defined benefit post-employment health care benefits. The Registrants allocate a fixed amount per year to an account in a defined contribution VEBA for each employee. These accounts are managed either by the Registrant (for non-represented and certain represented groups) or by the Utility Workers of America for Local 223 employees. DTE Energy contributions to the VEBA for these accounts were $15 million in 2020, $13 million in 2019, and $11 million in 2018, and $8 million in 2017, including DTE Electric contributions of $7 million in 2020, and $6 million in 2019, and $5 million in 2018 and 2017.2018.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) The Registrants also contribute a fixed amount to a Retiree Reimbursement Account, for certain non-represented and represented retirees, spouses, and surviving spouses when the youngest of the retiree's covered household becomes eligible for Medicare Part A based on age. The amount of the annual allocation to each participant is determined by the employee's retirement date and increases each year for each eligible participant at the lower of the rate of medical inflation or 2%. Net other postretirement credit for DTE Energy includes the following components: | | | | 2019 | | 2018 | | 2017 | | 2020 | | 2019 | | 2018 | | | (In millions) | | (In millions) | | Service cost | $ | 22 |
| | $ | 27 |
| | $ | 27 |
| Service cost | $ | 26 | | | $ | 22 | | | $ | 27 | | | Interest cost | 70 |
| | 69 |
| | 73 |
| Interest cost | 56 | | | 70 | | | 69 | | | Expected return on plan assets | (96 | ) | | (143 | ) | | (130 | ) | Expected return on plan assets | (128) | | | (96) | | | (143) | | | Amortization of: | | | | | | Amortization of: | | | Net actuarial loss | 12 |
| | 11 |
| | 13 |
| Net actuarial loss | 16 | | | 12 | | | 11 | | | Prior service credit | (9 | ) | | — |
| | (14 | ) | Prior service credit | (19) | | | (9) | | | 0 | | | | Net other postretirement credit | $ | (1 | ) | | $ | (36 | ) | | $ | (31 | ) | Net other postretirement credit | $ | (49) | | | $ | (1) | | | $ | (36) | |
| | | | 2019 | | 2018 | | 2020 | | 2019 | | | (In millions) | | (In millions) | | Other changes in plan assets and accumulated postretirement benefit obligation recognized in Regulatory assets and Other comprehensive income (loss) | | | | Other changes in plan assets and accumulated postretirement benefit obligation recognized in Regulatory assets and Other comprehensive income (loss) | | | Net actuarial (gain) loss | $ | 34 |
| | $ | (8 | ) | Net actuarial (gain) loss | $ | (38) | | | $ | 34 | | | Amortization of net actuarial loss | (12 | ) | | (11 | ) | Amortization of net actuarial loss | (16) | | | (12) | | | Prior service credit | (53 | ) | | (44 | ) | Prior service credit | 0 | | | (53) | | | Amortization of prior service credit | 9 |
| | — |
| Amortization of prior service credit | 19 | | | 9 | | | | Total recognized in Regulatory assets and Other comprehensive income (loss) | $ | (22 | ) | | $ | (63 | ) | Total recognized in Regulatory assets and Other comprehensive income (loss) | $ | (35) | | | $ | (22) | | | Total recognized in net periodic benefit cost, Regulatory assets, and Other comprehensive income (loss) | $ | (23 | ) | | $ | (99 | ) | Total recognized in net periodic benefit cost, Regulatory assets, and Other comprehensive income (loss) | $ | (84) | | | $ | (23) | | | Estimated amounts to be amortized from Regulatory assets and Accumulated other comprehensive income (loss) into net periodic benefit cost during next fiscal year | | | | | | Net actuarial loss | $ | 16 |
| | $ | 12 |
| | | Prior service credit | $ | (19 | ) | | $ | (9 | ) | |
Net other postretirement credit for DTE Electric includes the following components: | | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | (In millions) | | Service cost | $ | 20 | | | $ | 16 | | | $ | 20 | | | Interest cost | 43 | | | 53 | | | 53 | | | Expected return on plan assets | (87) | | | (65) | | | (98) | | | Amortization of: | | | | | | | Net actuarial loss | 11 | | | 5 | | | 8 | | | Prior service credit | (14) | | | (7) | | | 0 | | | | | | | | | Net other postretirement cost (credit) | $ | (27) | | | $ | 2 | | | $ | (17) | |
| | | | | | | | | | | | | 2020 | | 2019 | | (In millions) | | Other changes in plan assets and accumulated postretirement benefit obligation recognized in Regulatory assets | | | | | Net actuarial (gain) loss | $ | (26) | | | $ | 41 | | | Amortization of net actuarial loss | (11) | | | (5) | | | Prior service credit | 0 | | | (33) | | | Amortization of prior service credit | 14 | | | 7 | | | | | | | Total recognized in Regulatory assets | $ | (23) | | | $ | 10 | | | Total recognized in net periodic benefit cost and Regulatory assets | $ | (50) | | | $ | 12 | |
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
Net other postretirement credit for DTE Electric includes the following components:
| | | | | | | | | | | | | | | 2019 | | 2018 | | 2017 | | | (In millions) | | Service cost | $ | 16 |
| | $ | 20 |
| | $ | 20 |
| | Interest cost | 53 |
| | 53 |
| | 56 |
| | Expected return on plan assets | (65 | ) | | (98 | ) | | (90 | ) | | Amortization of: | | | | | | | Net actuarial loss | 5 |
| | 8 |
| | 8 |
| | Prior service credit | (7 | ) | | — |
| | (10 | ) | | Net other postretirement cost (credit) | $ | 2 |
| | $ | (17 | ) | | $ | (16 | ) |
| | | | | | | | | | | 2019 | | 2018 | | | (In millions) | | Other changes in plan assets and accumulated postretirement benefit obligation recognized in Regulatory assets | | | | | Net actuarial (gain) loss | $ | 41 |
| | $ | (46 | ) | | Amortization of net actuarial loss | (5 | ) | | (8 | ) | | Prior service cost | (33 | ) | | — |
| | Amortization of prior service (cost) credit | 7 |
| | (35 | ) | | Total recognized in Regulatory assets | $ | 10 |
| | $ | (89 | ) | | Total recognized in net periodic benefit cost and Regulatory assets | $ | 12 |
| | $ | (106 | ) | | Estimated amounts to be amortized from Regulatory assets into net periodic benefit cost during next fiscal year | | | | | Net actuarial loss | $ | 11 |
| | $ | 5 |
| | Prior service credit | $ | (14 | ) | | $ | (7 | ) |
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
The following table reconciles the obligations, assets, and funded status of the plans including amounts recorded as Accrued postretirement liability in the Registrants' Consolidated Statements of Financial Position at December 31: | | | | | | | | | | | | | | | | | | | | | | | | | DTE Energy | | DTE Electric | | 2020 | | 2019 | | 2020 | | 2019 | | (In millions) | | Change in accumulated postretirement benefit obligation | | | | | | | | | Accumulated postretirement benefit obligation, beginning of year | $ | 1,751 | | | $ | 1,645 | | | $ | 1,337 | | | $ | 1,247 | | | Service cost | 26 | | | 22 | | | 20 | | | 16 | | | Interest cost | 56 | | | 70 | | | 43 | | | 53 | | | Plan amendments | 0 | | | (53) | | | 0 | | | (33) | | | Actuarial loss | 54 | | | 153 | | | 31 | | | 118 | | | | | | | | | | | Benefits paid | (80) | | | (86) | | | (62) | | | (64) | | | Accumulated postretirement benefit obligation, end of year | $ | 1,807 | | | $ | 1,751 | | | $ | 1,369 | | | $ | 1,337 | | | Change in plan assets | | | | | | | | | Plan assets at fair value, beginning of year | $ | 1,819 | | | $ | 1,689 | | | $ | 1,236 | | | $ | 1,158 | | | Actual return on plan assets | 220 | | | 215 | | | 145 | | | 141 | | | | | | | | | | | Benefits paid | (79) | | | (85) | | | (61) | | | (63) | | | Plan assets at fair value, end of year | $ | 1,960 | | | $ | 1,819 | | | $ | 1,320 | | | $ | 1,236 | | | Funded status | $ | 153 | | | $ | 68 | | | $ | (49) | | | $ | (101) | | Amount recorded as:(a) | | | | | | | | | Noncurrent assets | $ | 561 | | | $ | 454 | | | $ | 335 | | | $ | 266 | | | Current liabilities | (1) | | | (1) | | | 0 | | | 0 | | | Noncurrent liabilities | (407) | | | (385) | | | (384) | | | (367) | | | $ | 153 | | | $ | 68 | | | $ | (49) | | | $ | (101) | | | Amounts recognized in Accumulated other comprehensive income (loss), pre-tax | | | | | | | | | Net actuarial gain | $ | (7) | | | $ | (8) | | | $ | 0 | | | $ | 0 | | | | | | | | | | | | | | | | | | | $ | (7) | | | $ | (8) | | | $ | 0 | | | $ | 0 | | Amounts recognized in Regulatory assets(b) | | | | | | | | | Net actuarial loss | $ | 234 | | | $ | 289 | | | $ | 156 | | | $ | 193 | | | Prior service credit | (69) | | | (88) | | | (48) | | | (62) | | | | | | | | | | | $ | 165 | | | $ | 201 | | | $ | 108 | | | $ | 131 | |
| | | | | | | | | | | | | | | | | | | DTE Energy | | DTE Electric | | | 2019 | | 2018 | | 2019 | | 2018 | | | (In millions) | | Change in accumulated postretirement benefit obligation | | | | | | | | | Accumulated postretirement benefit obligation, beginning of year | $ | 1,645 |
| | $ | 1,910 |
| | $ | 1,247 |
| | $ | 1,470 |
| | Service cost | 22 |
| | 27 |
| | 16 |
| | 20 |
| | Interest cost | 70 |
| | 69 |
| | 53 |
| | 53 |
| | Plan amendments | (53 | ) | | (44 | ) | | (33 | ) | | (35 | ) | | Actuarial (gain) loss | 153 |
| | (227 | ) | | 118 |
| | (196 | ) | | Benefits paid | (86 | ) | | (90 | ) | | (64 | ) | | (65 | ) | | Accumulated postretirement benefit obligation, end of year | $ | 1,751 |
| | $ | 1,645 |
| | $ | 1,337 |
| | $ | 1,247 |
| | Change in plan assets | | | | | | | | | Plan assets at fair value, beginning of year | $ | 1,689 |
| | $ | 1,848 |
| | $ | 1,158 |
| | $ | 1,272 |
| | Actual return on plan assets | 215 |
| | (75 | ) | | 141 |
| | (52 | ) | | Benefits paid | (85 | ) | | (84 | ) | | (63 | ) | | (62 | ) | | Plan assets at fair value, end of year | $ | 1,819 |
| | $ | 1,689 |
| | $ | 1,236 |
| | $ | 1,158 |
| | Funded status | $ | 68 |
| | $ | 44 |
| | $ | (101 | ) | | $ | (89 | ) | | Amount recorded as: | | | | | | | | | Noncurrent assets | $ | 69 |
| | $ | 45 |
| | $ | 266 |
| | $ | 189 |
| | Current liabilities | (1 | ) | | (1 | ) | | — |
| | — |
| | Noncurrent liabilities | — |
| | — |
| | (367 | ) | | (278 | ) | | | $ | 68 |
| | $ | 44 |
| | $ | (101 | ) | | $ | (89 | ) | | Amounts recognized in Accumulated other comprehensive income (loss), pre-tax | | | | | | | | | Net actuarial (gain) loss | $ | (8 | ) | | $ | 1 |
| | $ | — |
| | $ | — |
| | | $ | (8 | ) | | $ | 1 |
| | $ | — |
| | $ | — |
| Amounts recognized in Regulatory assets(a) | | | | | | | | | Net actuarial loss | $ | 289 |
| | $ | 257 |
| | $ | 193 |
| | $ | 156 |
| | Prior service credit | (88 | ) | | (44 | ) | | (62 | ) | | (35 | ) | | | $ | 201 |
| | $ | 213 |
| | $ | 131 |
| | $ | 121 |
|
______________________________________(a)Prior year balances for DTE Energy were recast to be consistent with the current year gross presentation of Noncurrent assets and Noncurrent liabilities. | | (a) | See Note 10 to the Consolidated Financial Statements, "Regulatory Matters." |
(b)See Note 10 to the Consolidated Financial Statements, "Regulatory Matters." The increases in the Registrants' other postretirement benefit obligation for the years ended December 31, 2020 and 2019 were primarily due to actuarial loss in both periods, which was primarily driven by decreases in discount rates and partially offset by favorable changes in healthcare cost assumptions. The increase in the other postretirement benefit obligation in 2019 was also partially offset by plan amendments. The following table reflects other postretirement benefit plans with accumulated postretirement benefit obligations in excess of plan assets as of December 31: | | | | | | | | | | | | | | | | | | | | | | | | | DTE Energy | | DTE Electric | | 2020 | | 2019 | | 2020 | | 2019 | | (In millions) | | Accumulated postretirement benefit obligation | $ | 878 | | | $ | 840 | | | $ | 826 | | | $ | 795 | | | Fair value of plan assets | 470 | | | 454 | | | 442 | | | 428 | | | Accumulated postretirement benefit obligation in excess of plan assets | $ | 408 | | | $ | 386 | | | $ | 384 | | | $ | 367 | |
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) At December 31, 2019,2020, the benefits expected to be paid, including prescription drug benefits, in each of the next five years and in the aggregate for the five fiscal years thereafter for the Registrants are as follows: | | | | | | | | | | | DTE Energy | | DTE Electric | | | (In millions) | | 2020 | $ | 84 |
| | $ | 64 |
| | 2021 | 88 |
| | 67 |
| | 2022 | 92 |
| | 70 |
| | 2023 | 94 |
| | 72 |
| | 2024 | 96 |
| | 73 |
| | 2025-2029 | 496 |
| | 378 |
| | Total | $ | 950 |
| | $ | 724 |
|
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
| | | | | | | | | | | | | DTE Energy | | DTE Electric | | (In millions) | | 2021 | $ | 82 | | | $ | 62 | | | 2022 | 87 | | | 66 | | | 2023 | 91 | | | 69 | | | 2024 | 92 | | | 70 | | | 2025 | 95 | | | 72 | | | 2026-2030 | 497 | | | 376 | | | Total | $ | 944 | | | $ | 715 | |
Assumptions used in determining the accumulated postretirement benefit obligation and net other postretirement benefit costs of the Registrants are: | | | | | | | | | 2019 | | 2018 | | 2017 | | Accumulated postretirement benefit obligation | | | | | | | Discount rate | 3.29% | | 4.40% | | 3.70% | | Health care trend rate pre- and post- 65 | 6.75 / 7.25% | | 6.75 / 7.25% | | 6.75 / 7.25% | | Ultimate health care trend rate | 4.50% | | 4.50% | | 4.50% | | Year in which ultimate reached pre- and post- 65 | 2032 | | 2031 | | 2030 | | Other postretirement benefit costs | | | | | | | Discount rate | 4.40% | | 3.70% | | 4.25% | | Expected long-term rate of return on plan assets | 7.30% | | 7.75% | | 7.75% | | Health care trend rate pre- and post- 65 | 6.75 / 7.25% | | 6.75 / 7.25% | | 6.50 / 6.75% | | Ultimate health care trend rate | 4.50% | | 4.50% | | 4.50% | | Year in which ultimate reached pre- and post- 65 | 2031 | | 2030 | | 2028 |
A one percentage point increase in health care cost trend rates would have increased the total service cost and interest cost components of benefit costs for DTE Energy by $3 million, including $2 million for DTE Electric, in 2019 and would have increased the accumulated benefit obligation for DTE Energy by $62 million, including $44 million for DTE Electric, at December 31, 2019. A one percentage point decrease in the health care cost trend rates would have decreased the total service and interest cost components of benefit costs for DTE Energy by $3 million, including $2 million for DTE Electric, in 2019 and would have decreased the accumulated benefit obligation for DTE Energy by $54 million, including $39 million for DTE Electric, at December 31, 2019. | | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | Accumulated postretirement benefit obligation | | | | | | | Discount rate | 2.58% | | 3.29% | | 4.40% | | Health care trend rate pre- and post- 65 | 6.75 / 7.25% | | 6.75 / 7.25% | | 6.75 / 7.25% | | Ultimate health care trend rate | 4.50% | | 4.50% | | 4.50% | | Year in which ultimate reached pre- and post- 65 | 2033 | | 2032 | | 2031 | | Other postretirement benefit costs | | | | | | | Discount rate | 3.29% | | 4.40% | | 3.70% | | | | | | | | Expected long-term rate of return on plan assets | 7.20% | | 7.30% | | 7.75% | | Health care trend rate pre- and post- 65 | 6.75 / 7.25% | | 6.75 / 7.25% | | 6.75 / 7.25% | | Ultimate health care trend rate | 4.50% | | 4.50% | | 4.50% | | Year in which ultimate reached pre- and post- 65 | 2032 | | 2031 | | 2030 |
The process used in determining the long-term rate of return on assets for the other postretirement benefit plans is similar to that previously described for the pension plans. The DTE Energy Company Master VEBA Trust employs a liability driven investment program whereby the characteristics of plan liabilities are considered when determining investment policy. Risk tolerance is established through consideration of future plan cash flows, plan funded status, and corporate financial considerations. The investment portfolio contains a diversified blend of equity, fixed income, and other investments. Furthermore, equity investments are diversified across U.S. and non-U.S. stocks and large and small market capitalizations. Fixed income investments generally include U.S. Treasuries, other governmental debt, diversified corporate bonds, bank loans, and mortgage-backed securities. Other investments are used to enhance long-term returns while improving portfolio diversification. Derivatives may be utilized in a risk controlled manner to potentially increase the portfolio beyond the market value of invested assets and/or reduce portfolio investment risk. Investment risk is measured and monitored on an ongoing basis through annual liability measurements, periodic asset/liability studies, and quarterly investment portfolio reviews. Target allocations for the Registrants' other postretirement benefit plan assets as of December 31, 20192020 are listed below: | | | | | | | U.S. Large Cap Equity Securities | 1611 | % | | U.S. Small Cap and Mid Cap Equity Securities | 32 |
| | Non-U.S. Equity Securities | 1610 |
| | Fixed Income Securities | 3752 |
| | Hedge Funds and Similar Investments | 1411 |
| | Private Equity and Other | 14 |
| | 100 | % |
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
The following tables provide the fair value measurement amounts for the Registrants' other postretirement benefit plan assets at December 31, 20192020 and 20182019(a): | | | | | | | | | | | | | | | | | | | | December 31, 2020 | | December 31, 2019 | | | December 31, 2019 | | December 31, 2018 | | Level 1 | | Level 2 | | | Other(b) | | Total | | Level 1 | | Level 2 | | | Other(b) | | Total | | | Level 1 | | Level 2 | | Other(b) | | Total | | Level 1 | | Level 2 | | Other(b) | | Total | | (In millions) | | DTE Energy asset category: | (In millions) | DTE Energy asset category: | | | | | | Short-term Investments(c) | $ | 80 |
| | $ | — |
| | $ | — |
| | $ | 80 |
| | $ | 14 |
| | $ | 2 |
| | $ | — |
| | $ | 16 |
| Short-term Investments(c) | $ | 21 | | | $ | 0 | | | | $ | 0 | | | $ | 21 | | | $ | 80 | | | $ | 0 | | | | $ | 0 | | | $ | 80 | | | Equity Securities | | | | | | | | | | | | | | | | Equity Securities | | | | | | Domestic(d) | 51 |
| | — |
| | 273 |
| | 324 |
| | 300 |
| | — |
| | — |
| | 300 |
| Domestic(d) | 51 | | | 0 | | | | 200 | | | 251 | | | 51 | | | 0 | | | | 273 | | | 324 | | International(e) | 182 |
| | — |
| | 89 |
| | 271 |
| | 234 |
| | — |
| | 67 |
| | 301 |
| International(e) | 23 | | | 0 | | | | 178 | | | 201 | | | 182 | | | 0 | | | | 89 | | | 271 | | | Fixed Income Securities | | | | | | | | | | | | | | | | Fixed Income Securities | | | | | | Governmental(f) | 74 |
| | — |
| | — |
| | 74 |
| | — |
| | 85 |
| | — |
| | 85 |
| Governmental(f) | 40 | | | 45 | | | | 0 | | | 85 | | | 74 | | | 0 | | | | 0 | | | 74 | | Corporate(g) | — |
| | 256 |
| | 251 |
| | 507 |
| | 11 |
| | 265 |
| | 130 |
| | 406 |
| Corporate(g) | 0 | | | 477 | | | | 379 | | | 856 | | | 0 | | | 256 | | | | 251 | | | 507 | | Hedge Funds and Similar Investments(h) | 71 |
| | — |
| | 182 |
| | 253 |
| | 97 |
| | — |
| | 203 |
| | 300 |
| Hedge Funds and Similar Investments(h) | 61 | | | 17 | | | | 124 | | | 202 | | | 71 | | | 0 | | | | 182 | | | 253 | | Private Equity and Other(i) | — |
| | — |
| | 310 |
| | 310 |
| | — |
| | — |
| | 281 |
| | 281 |
| Private Equity and Other(i) | 0 | | | 0 | | | | 344 | | | 344 | | | 0 | | | 0 | | | | 310 | | | 310 | | | | DTE Energy Total | $ | 458 |
| | $ | 256 |
| | $ | 1,105 |
| | $ | 1,819 |
| | $ | 656 |
| | $ | 352 |
| | $ | 681 |
| | $ | 1,689 |
| DTE Energy Total | $ | 196 | | | $ | 539 | | | | $ | 1,225 | | | $ | 1,960 | | | $ | 458 | | | $ | 256 | | | | $ | 1,105 | | | $ | 1,819 | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | DTE Electric asset category: | | | | | | | | | | | | | | | | DTE Electric asset category: | | | | | | Short-term Investments(c) | $ | 55 |
| | $ | — |
| | $ | — |
| | $ | 55 |
| | $ | 10 |
| | $ | 1 |
| | $ | — |
| | $ | 11 |
| Short-term Investments(c) | $ | 14 | | | $ | 0 | | | | $ | 0 | | | $ | 14 | | | $ | 55 | | | $ | 0 | | | | $ | 0 | | | $ | 55 | | | Equity Securities | | | | | | | | | | | | | | | | Equity Securities | | | | | | Domestic(d) | 34 |
| | — |
| | 185 |
| | 219 |
| | 206 |
| | — |
| | — |
| | 206 |
| Domestic(d) | 33 | | | 0 | | | | 131 | | | 164 | | | 34 | | | 0 | | | | 185 | | | 219 | | International(e) | 124 |
| | — |
| | 60 |
| | 184 |
| | 163 |
| | — |
| | 45 |
| | 208 |
| International(e) | 16 | | | 0 | | | | 117 | | | 133 | | | 124 | | | 0 | | | | 60 | | | 184 | | | Fixed Income Securities | | | | | | | | | | | | | | | | Fixed Income Securities | | | | | | Governmental(f) | 48 |
| | — |
| | — |
| | 48 |
| | — |
| | 53 |
| | — |
| | 53 |
| Governmental(f) | 24 | | | 31 | | | | 0 | | | 55 | | | 48 | | | 0 | | | | 0 | | | 48 | | Corporate(g) | — |
| | 168 |
| | 176 |
| | 344 |
| | 7 |
| | 179 |
| | 92 |
| | 278 |
| Corporate(g) | 0 | | | 321 | | | | 263 | | | 584 | | | 0 | | | 168 | | | | 176 | | | 344 | | Hedge Funds and Similar Investments(h) | 49 |
| | — |
| | 123 |
| | 172 |
| | 68 |
| | — |
| | 139 |
| | 207 |
| Hedge Funds and Similar Investments(h) | 41 | | | 11 | | | | 83 | | | 135 | | | 49 | | | 0 | | | | 123 | | | 172 | | Private Equity and Other(i) | — |
| | — |
| | 214 |
| | 214 |
| | — |
| | — |
| | 195 |
| | 195 |
| Private Equity and Other(i) | 0 | | | 0 | | | | 235 | | | 235 | | | 0 | | | 0 | | | | 214 | | | 214 | | | | DTE Electric Total | $ | 310 |
| | $ | 168 |
| | $ | 758 |
| | $ | 1,236 |
| | $ | 454 |
| | $ | 233 |
| | $ | 471 |
| | $ | 1,158 |
| DTE Electric Total | $ | 128 | | | $ | 363 | | | | $ | 829 | | | $ | 1,320 | | | $ | 310 | | | $ | 168 | | | | $ | 758 | | | $ | 1,236 | |
| | (a) | For a description of levels within the fair value hierarchy see Note 13 to the Consolidated Financial Statements, "Fair Value." |
| | (b) | Amounts represent assets valued at NAV as a practical expedient for fair value. |
| | (c) | This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category are obtained from quoted prices in actively traded markets or valuations from brokers or pricing services. |
| | (d) | This category represents portfolios of large, medium and small capitalization domestic equities. Investments in this category include exchange-traded securities for which unadjusted quoted prices can be obtained and exchange-traded securities held in a commingled fund classified as NAV assets. |
| | (e) | This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category are exchange-traded securities whereby unadjusted quoted prices can be obtained. Exchange-traded securities held in a commingled fund are classified as NAV assets. |
| | (f) | This category includes U.S. Treasuries, bonds and other governmental debt. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. |
| | (g) | This category primarily consists of corporate bonds from diversified industries, bank loans, and mortgage backed securities. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. Non-exchange traded securities and exchange-traded securities held in commingled funds are classified as NAV assets. |
| | (h) | This category utilizes a diversified group of strategies that attempt to capture financial market inefficiencies and includes publicly traded mutual funds, commingled funds and limited partnership funds. Pricing for mutual funds in this category is obtained from quoted prices in actively traded markets. Commingled funds and limited partnership funds are classified as NAV assets. |
| | (i) | This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in real estate and private debt. All investments in this category are classified as NAV assets. |
(a)For a description of levels within the fair value hierarchy see Note 13 to the Consolidated Financial Statements, "Fair Value." (b)Amounts represent assets valued at NAV as a practical expedient for fair value. (c)This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category are obtained from quoted prices in actively traded markets. (d)This category represents portfolios of large, medium and small capitalization domestic equities. Investments in this category include exchange-traded securities for which unadjusted quoted prices can be obtained and exchange-traded securities held in a commingled fund classified as NAV assets. (e)This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category include exchange-traded securities for which unadjusted quoted prices can be obtained and exchange-traded securities held in a commingled fund classified as NAV assets. (f)This category includes U.S. Treasuries, bonds and other governmental debt. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. (g)This category primarily consists of corporate bonds from diversified industries, bank loans, and mortgage backed securities. Pricing for investments in this category is obtained from quotations from broker or pricing services. Non-exchange traded securities and exchange-traded securities held in commingled funds are classified as NAV assets. (h)This category utilizes a diversified group of strategies that attempt to capture financial market inefficiencies and includes publicly traded mutual funds, commingled funds and limited partnership funds. Pricing for mutual funds in this category is obtained from quoted prices in actively traded markets. Commingled funds and limited partnership funds are classified as NAV assets. (i)This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in real estate and private debt. All investments in this category are classified as NAV assets.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
The DTE Energy Company Master VEBA Trust holds debt and equity securities directly and indirectly through commingled funds. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. The commingled funds hold exchange-traded equity or debt securities and are valued based on NAVs. Non-exchange traded fixed income securities are valued by the trustee based upon quotations available from brokers or pricing services. A primary price source is identified by asset type, class, or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustee challenges an assigned price and determines that another price source is considered preferable. The Registrants have obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices. Defined Contribution Plans The Registrants also sponsor defined contribution retirement savings plans. Participation in one of these plans is available to substantially all represented and non-represented employees. For substantially all employees, the Registrants match employee contributions up to certain predefined limits based upon eligible compensation and the employee’s contribution rate. Additionally, for eligible represented and non-represented employees who do not participate in the Pension Plans, the Registrants annually contribute an amount equivalent to 4% (8% for certain DTE Gas represented employees) of an employee's eligible pay to the employee's defined contribution retirement savings plan. For DTE Energy, the cost of these plans was $73 million, $65 million, $61 million, and $57$61 million for the years ended December 31, 2020, 2019, 2018, and 2017,2018, respectively. For DTE Electric, the cost of these plans was $34 million, $31 million, $29 million, and $27$29 million for the years ended December 31, 2020, 2019, 2018, and 2017,2018, respectively.
NOTE 22 — STOCK-BASED COMPENSATION DTE Energy’s stock incentive program permits the grant of incentive stock options, non-qualifying stock options, stock awards, performance shares, and performance units to employees and members of its Board of Directors. As a result of a stock award, a settlement of an award of performance shares, or by exercise of a participant’s stock option, DTE Energy may deliver common stock from its authorized but unissued common stock and/or from outstanding common stock acquired by or on behalf of DTE Energy in the name of the participant. Key provisions of the stock incentive program are: •Authorized limit is 16,500,000 shares of common stock; •Prohibits the grant of a stock option with an exercise price that is less than the fair market value of DTE Energy’s stock on the date of the grant; and •Imposes the following award limits to a single participant in a single calendar year, (1) options for more than 500,000 shares of common stock; (2) stock awards for more than 150,000 shares of common stock; (3) performance share awards for more than 300,000 shares of common stock (based on the maximum payout under the award); or (4) more than 1,000,000 performance units, which have a face amount of $1.00 each. DTE Energy records compensation expense at fair value over the vesting period for all awards it grants. The following table summarizes the components of stock-based compensation for DTE Energy: | | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | (In millions) | | Stock-based compensation expense | $ | 63 | | | $ | 71 | | | $ | 64 | | | Tax benefit | $ | 12 | | | $ | 13 | | | $ | 13 | | Stock-based compensation cost capitalized in Property, plant, and equipment(a) | $ | 0 | | | $ | 16 | | | $ | 11 | |
| | | | | | | | | | | | | | | 2019 | | 2018 | | 2017 | | | (In millions) | | Stock-based compensation expense | $ | 71 |
| | $ | 64 |
| | $ | 58 |
| | Tax benefit | $ | 13 |
| | $ | 13 |
| | $ | 23 |
| | Stock-based compensation cost capitalized in Property, plant, and equipment | $ | 16 |
| | $ | 11 |
| | $ | 9 |
|
Stock Options
Options are exercisable accordingIn DTE Electric's May 2020 rate order, the MPSC disallowed certain capital expenditures related to incentive compensation. Therefore, beginning in 2020, no stock-based compensation cost will be capitalized in Property, plant, and equipment. Refer to Note 10 to the terms of the individual stock option award agreements and expire ten years after the date of the grant. The option exercise price equals the fair value of the stock on the date that the option was granted. Stock options vest ratably over a three-year period.Consolidated Financial Statements, "Regulatory Matters," for further information.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
There were 0 options granted and 0 options expensed during 2019, 2018, or 2017. The intrinsic value of options outstanding and options exercised for the years ended December 31, 2019, 2018, and 2017 were not material.
Restricted Stock Awards Stock awards granted under the plan are restricted for varying periods, generally for three years. Participants have all rights of a shareholder with respect to a stock award, including the right to receive dividends and vote the shares. Prior to vesting in stock awards, the participant: (i) may not sell, transfer, pledge, exchange, or otherwise dispose of shares; (ii) shall not retain custody of the share certificates; and (iii) will deliver to DTE Energy a stock power with respect to each stock award upon request. The stock awards are recorded at cost that approximates fair value on the date of grant. The cost is amortized to compensation expense over the vesting period. The fair value of awards vested were not material for the years ended December 31, 2020, 2019, 2018, and 2017.2018. Compensation cost charged against income was $13 million for the year ended December 31, 2020, and $11 million for the years ended December 31, 2019 and 2018, and 2017.respectively. Performance Share Awards Performance shares awarded under the plan are for a specified number of shares of DTE Energy common stock that entitle the holder to receive a cash payment, shares of DTE Energy common stock, or a combination thereof. The final value of the award is determined by the achievement of certain performance objectives and market conditions. The awards vest at the end of a specified period, usually three years. Awards granted in 2020, 2019, 2018, and 20172018 were primarily deemed to be equity awards. The DTE Energy stock price and number of probable shares attributable to market conditions for such equity awards are fair valued only at the grant date. DTE Energy accounts for performance share awards by accruing compensation expense over the vesting period based on: (i) the number of shares expected to be paid which is based on the probable achievement of performance objectives; and (ii) the closing stock price market value. The settlement of the award is based on the closing price at the settlement date. DTE Energy recorded compensation expense foractivity relating to performance share awards as follows: | | | | | | | | | | | | | | | 2019 | | 2018 | | 2017 | | | (In millions) | | Compensation expense | $ | 60 |
| | $ | 53 |
| | $ | 47 |
| Cash settlements(a) | $ | 19 |
| | $ | 13 |
| | $ | 15 |
| Stock settlements(a) | $ | 79 |
| | $ | 39 |
| | $ | 66 |
|
| | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | (In millions, except per share amounts) | | Weighted average grant date fair value of awards granted (per share) | $ | 129.68 | | | $ | 115.85 | | | $ | 105.64 | | Awards settled in cash(a) | $ | 21 | | | $ | 19 | | | $ | 13 | | Awards settled in stock(a) | $ | 53 | | | $ | 79 | | | $ | 39 | | | Compensation expense | $ | 50 | | | $ | 60 | | | $ | 53 | |
| | (a) | Sum of cash and stock settlements approximates the intrinsic value of the awards. |
(a)Sum of awards settled in cash and stock approximates the intrinsic value of the awards. During the vesting period, the recipient of a performance share award has no shareholder rights. During the period beginning on the date the performance shares are awarded and ending on the certification date of the performance objectives, the number of performance shares awarded will be increased, assuming full dividend reinvestment at the fair market value on the dividend payment date. The cumulative number of performance shares will be adjusted to determine the final payment based on the performance objectives achieved. Performance share awards are nontransferable and are subject to risk of forfeiture. The following table summarizes DTE Energy’s performance share activity for the period ended December 31, 2019:2020: | | | | | | | | | | | | | Performance Shares | | Weighted Average
Grant Date
Fair Value | | Balance at December 31, 2019 | 1,226,031 | | | $ | 107.35 | | | Grants | 383,813 | | | $ | 129.68 | | | Forfeitures | (43,768) | | | $ | 116.94 | | | Payouts | (438,639) | | | $ | 99.22 | | | Balance at December 31, 2020 | 1,127,437 | | | $ | 117.06 | |
| | | | | | | | | | Performance Shares | | Weighted Average
Grant Date
Fair Value | | Balance at December 31, 2018 | 1,286,686 |
| | $ | 97.17 |
| | Grants | 446,579 |
| | $ | 115.85 |
| | Forfeitures | (44,044 | ) | | $ | 102.42 |
| | Payouts | (463,190 | ) | | $ | 88.53 |
| | Balance at December 31, 2019 | 1,226,031 |
| | $ | 107.35 |
|
150
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
Unrecognized Compensation Costs As of December 31, 2019,2020, DTE Energy's total unrecognized compensation cost related to non-vested stock incentive plan arrangements and the weighted average recognition period was as follows: | | | | | | | | | Unrecognized
Compensation
Cost | | Weighted Average
to be Recognized | | | (In millions) | | (In years) | | Stock awards | $ | 19 |
| | 1.57 | | Performance shares | 62 |
| | 1.05 | | | $ | 81 |
| | 1.17 |
| | | | | | | | | | | | | Unrecognized
Compensation
Cost | | Weighted Average
to be Recognized | | (In millions) | | (In years) | | | | | | Stock awards | $ | 19 | | | 1.60 | | Performance shares | 49 | | | 1.04 | | $ | 68 | | | 1.19 |
Allocated Stock-Based Compensation DTE Electric received an allocation of costs from DTE Energy associated with stock-based compensation. DTE Electric's allocation for 2020, 2019, 2018, and 20172018 for stock-based compensation expense was $37 million, $43 million, $38 million, and $34$38 million, respectively.
NOTE 23 — 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.certain investments, including funds supporting regional development and economic growth. The federal income tax provisions or benefits of DTE Energy’s subsidiaries are determined on an individual company basis and recognize the tax benefit of tax credits and net operating losses, if applicable. The state and local income tax provisions of the utility subsidiaries are also determined on an individual company basis and recognize the tax benefit of various tax credits and net operating losses, if applicable. The subsidiaries record federal, state, and local income taxes payable to or receivable from DTE Energy based on the federal, state, and local tax provisions of each company.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
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: | | | | | | | | | | | | | | | | | | | Year Ended December 31, | | 2020 | | 2019 | | 2018 | | (In millions) | Electric(a) | $ | 61 | | | $ | 56 | | | $ | 52 | | | Gas | 16 | | | 12 | | | 12 | | | Gas Storage and Pipelines | 26 | | | 27 | | | 36 | | | Power and Industrial Projects | 464 | | | 596 | | | 642 | | | Energy Trading | 31 | | | 22 | | | 27 | | | Corporate and Other | 2 | | | 2 | | | 2 | | | | | | | | | $ | 600 | | | $ | 715 | | | $ | 771 | |
| | | | | | | | | | | | | | | Year Ended December 31, | | | 2019 | | 2018 | | 2017 | | | (In millions) | | Electric | $ | 56 |
| | $ | 52 |
| | $ | 48 |
| | Gas | 12 |
| | 12 |
| | 8 |
| | Gas Storage and Pipelines | 27 |
| | 36 |
| | 42 |
| | Power and Industrial Projects | 596 |
| | 642 |
| | 569 |
| | Energy Trading | 22 |
| | 27 |
| | 35 |
| | Corporate and Other | 2 |
| | 2 |
| | 2 |
| | | $ | 715 |
| | $ | 771 |
| | $ | 704 |
|
Financial data of DTE Energy's business segments follows: | | | | | | | | | | | | | | | | | | | | | | | | | | | | | Electric | | Gas | | Gas Storage and Pipelines | | Power and Industrial Projects | | Energy Trading | | Corporate and Other | | Reclassifications
and
Eliminations | | Total | | | (In millions) | | 2019 | | | | | | | | | | | | | | | | | Operating Revenues — Utility operations | $ | 5,224 |
| | 1,482 |
| | — |
| | — |
| | — |
| | — |
| | (68 | ) | | $ | 6,638 |
| | Operating Revenues — Non-utility operations | $ | 5 |
| | — |
| | 501 |
| | 1,560 |
| | 4,610 |
| | 2 |
| | (647 | ) | | $ | 6,031 |
| | Depreciation and amortization | $ | 949 |
| | 144 |
| | 94 |
| | 69 |
| | 6 |
| | 1 |
| | — |
| | $ | 1,263 |
| | Interest expense | $ | 315 |
| | 78 |
| | 73 |
| | 33 |
| | 8 |
| | 266 |
| | (132 | ) | | $ | 641 |
| | Interest income | $ | (2 | ) | | (6 | ) | | (8 | ) | | (9 | ) | | (4 | ) | | (120 | ) | | 132 |
| | $ | (17 | ) | | Equity in earnings of equity method investees | $ | 1 |
| | 2 |
| | 97 |
| | 14 |
| | — |
| | (3 | ) | | — |
| | $ | 111 |
| | Income Tax Expense (Benefit) | $ | 137 |
| | 62 |
| | 74 |
| | (63 | ) | | 17 |
| | (75 | ) | | — |
| | $ | 152 |
| | Net Income (Loss) Attributable to DTE Energy Company | $ | 714 |
| | 185 |
| | 204 |
| | 133 |
| | 49 |
| | (116 | ) | | — |
| | $ | 1,169 |
| | Investment in equity method investees | $ | 5 |
| | 11 |
| | 1,685 |
| | 130 |
| | — |
| | 31 |
| | — |
| | $ | 1,862 |
| | Capital expenditures and acquisitions | $ | 2,368 |
| | 530 |
| | 2,510 |
| | 54 |
| | 5 |
| | — |
| | — |
| | $ | 5,467 |
| | Goodwill | $ | 1,208 |
| | 743 |
| | 470 |
| | 26 |
| | 17 |
| | — |
| | — |
| | $ | 2,464 |
| | Total Assets | $ | 24,617 |
| | 5,717 |
| | 4,832 |
| | 537 |
| | 798 |
| | 7,679 |
| | (2,298 | ) | | $ | 41,882 |
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | Electric | | Gas | | Gas Storage and Pipelines | | Power and Industrial Projects | | Energy Trading | | Corporate and Other | | Reclassifications
and
Eliminations | | Total | | (In millions) | | 2020 | | | | | | | | | | | | | | | | | Operating Revenues — Utility operations | $ | 5,506 | | | 1,414 | | | 0 | | | 0 | | | 0 | | | 0 | | | (75) | | | $ | 6,845 | | | Operating Revenues — Non-utility operations | $ | 14 | | | 0 | | | 754 | | | 1,224 | | | 3,863 | | | 2 | | | (525) | | | $ | 5,332 | | | Depreciation and amortization | $ | 1,057 | | | 157 | | | 151 | | | 72 | | | 5 | | | 1 | | | 0 | | | $ | 1,443 | | | Interest expense | $ | 337 | | | 80 | | | 113 | | | 37 | | | 6 | | | 331 | | | (184) | | | $ | 720 | | | Interest income | $ | (4) | | | (5) | | | (9) | | | (22) | | | (2) | | | (180) | | | 184 | | | $ | (38) | | | Equity in earnings of equity method investees | $ | 0 | | | 1 | | | 106 | | | 17 | | | 0 | | | 8 | | | 0 | | | $ | 132 | | | Income Tax Expense (Benefit) | $ | 108 | | | 48 | | | 116 | | | (40) | | | 12 | | | (77) | | | 0 | | | $ | 167 | | | Net Income (Loss) Attributable to DTE Energy Company | $ | 777 | | | 186 | | | 315 | | | 134 | | | 36 | | | (80) | | | 0 | | | $ | 1,368 | | | Investment in equity method investees | $ | 6 | | | 12 | | | 1,691 | | | 125 | | | 0 | | | 34 | | | 0 | | | $ | 1,868 | | | Capital expenditures and acquisitions | $ | 2,701 | | | 574 | | | 517 | | | 186 | | | 5 | | | 0 | | | 0 | | | $ | 3,983 | | | Goodwill | $ | 1,208 | | | 743 | | | 472 | | | 26 | | | 17 | | | 0 | | | 0 | | | $ | 2,466 | | | Total Assets | $ | 26,588 | | | 6,339 | | | 5,068 | | | 696 | | | 807 | | | 8,071 | | | (2,073) | | | $ | 45,496 | |
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | Electric | | Gas | | Gas Storage and Pipelines | | Power and Industrial Projects | | Energy Trading | | Corporate and Other | | Reclassifications
and
Eliminations | | Total | | (In millions) | | 2019 | | | | | | | | | | | | | | | | | Operating Revenues — Utility operations | $ | 5,224 | | | 1,482 | | | 0 | | | 0 | | | 0 | | | 0 | | | (68) | | | $ | 6,638 | | | Operating Revenues — Non-utility operations | $ | 5 | | | 0 | | | 501 | | | 1,560 | | | 4,610 | | | 2 | | | (647) | | | $ | 6,031 | | | Depreciation and amortization | $ | 949 | | | 144 | | | 94 | | | 69 | | | 6 | | | 1 | | | 0 | | | $ | 1,263 | | | Interest expense | $ | 315 | | | 78 | | | 73 | | | 33 | | | 8 | | | 266 | | | (132) | | | $ | 641 | | | Interest income | $ | (2) | | | (6) | | | (8) | | | (9) | | | (4) | | | (120) | | | 132 | | | $ | (17) | | | Equity in earnings of equity method investees | $ | 1 | | | 2 | | | 97 | | | 14 | | | 0 | | | (3) | | | 0 | | | $ | 111 | | | Income Tax Expense (Benefit) | $ | 137 | | | 62 | | | 74 | | | (63) | | | 17 | | | (75) | | | 0 | | | $ | 152 | | | Net Income (Loss) Attributable to DTE Energy Company | $ | 714 | | | 185 | | | 204 | | | 133 | | | 49 | | | (116) | | | 0 | | | $ | 1,169 | | | Investment in equity method investees | $ | 5 | | | 11 | | | 1,685 | | | 130 | | | 0 | | | 31 | | | 0 | | | $ | 1,862 | | | Capital expenditures and acquisitions | $ | 2,368 | | | 530 | | | 2,510 | | | 54 | | | 5 | | | 0 | | | 0 | | | $ | 5,467 | | | Goodwill | $ | 1,208 | | | 743 | | | 470 | | | 26 | | | 17 | | | 0 | | | 0 | | | $ | 2,464 | | | Total Assets | $ | 24,617 | | | 5,717 | | | 4,832 | | | 537 | | | 798 | | | 7,610 | | | (1,843) | | | $ | 42,268 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | Electric | | Gas | | Gas Storage and Pipelines | | Power and Industrial Projects | | Energy Trading | | Corporate and Other | | Reclassifications
and
Eliminations | | Total | | (In millions) | | 2018 | | | | | | | | | | | | | | | | | Operating Revenues — Utility operations | $ | 5,298 | | | 1,436 | | | 0 | | | 0 | | | 0 | | | 0 | | | (64) | | | $ | 6,670 | | | Operating Revenues — Non-utility operations | $ | 0 | | | 0 | | | 485 | | | 2,204 | | | 5,557 | | | 3 | | | (707) | | | $ | 7,542 | | | Depreciation and amortization | $ | 836 | | | 133 | | | 82 | | | 67 | | | 5 | | | 1 | | | 0 | | | $ | 1,124 | | | Interest expense | $ | 283 | | | 70 | | | 68 | | | 31 | | | 6 | | | 220 | | | (119) | | | $ | 559 | | | Interest income | $ | 0 | | | (6) | | | (9) | | | (9) | | | (3) | | | (104) | | | 119 | | | $ | (12) | | | Equity in earnings of equity method investees | $ | 0 | | | 2 | | | 123 | | | 3 | | | 0 | | | 4 | | | 0 | | | $ | 132 | | | Income Tax Expense (Benefit) | $ | 193 | | | 67 | | | 68 | | | (195) | | | 13 | | | (48) | | | 0 | | | $ | 98 | | | Net Income (Loss) Attributable to DTE Energy Company | $ | 664 | | | 150 | | | 235 | | | 161 | | | 39 | | | (129) | | | 0 | | | $ | 1,120 | | | Investment in equity method investees | $ | 7 | | | 12 | | | 1,585 | | | 134 | | | 0 | | | 33 | | | 0 | | | $ | 1,771 | | | Capital expenditures and acquisitions | $ | 1,979 | | | 460 | | | 176 | | | 91 | | | 5 | | | 2 | | | 0 | | | $ | 2,713 | | | Goodwill | $ | 1,208 | | | 743 | | | 299 | | | 26 | | | 17 | | | 0 | | | 0 | | | $ | 2,293 | | | Total Assets | $ | 22,501 | | | 5,378 | | | 3,161 | | | 495 | | | 909 | | | 6,153 | | | (2,309) | | | $ | 36,288 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | Electric | | Gas | | Gas Storage and Pipelines | | Power and Industrial Projects | | Energy Trading | | Corporate and Other | | Reclassifications
and
Eliminations | | Total | | | (In millions) | | 2018 | | | | | | | | | | | | | | | | | Operating Revenues — Utility operations | $ | 5,298 |
| | 1,436 |
| | — |
| | — |
| | — |
| | — |
| | (64 | ) | | $ | 6,670 |
| | Operating Revenues — Non-utility operations | $ | — |
| |
|
| | 485 |
| | 2,204 |
| | 5,557 |
| | 3 |
| | (707 | ) | | $ | 7,542 |
| | Depreciation and amortization | $ | 836 |
| | 133 |
| | 82 |
| | 67 |
| | 5 |
| | 1 |
| | — |
| | $ | 1,124 |
| | Interest expense | $ | 283 |
| | 70 |
| | 68 |
| | 31 |
| | 6 |
| | 220 |
| | (119 | ) | | $ | 559 |
| | Interest income | $ | — |
| | (6 | ) | | (9 | ) | | (9 | ) | | (3 | ) | | (104 | ) | | 119 |
| | $ | (12 | ) | | Equity in earnings of equity method investees | $ | — |
| | 2 |
| | 123 |
| | 3 |
| | — |
| | 4 |
| | — |
| | $ | 132 |
| | Income Tax Expense (Benefit) | $ | 193 |
| | 67 |
| | 68 |
| | (195 | ) | | 13 |
| | (48 | ) | | — |
| | $ | 98 |
| | Net Income (Loss) Attributable to DTE Energy Company | $ | 664 |
| | 150 |
| | 235 |
| | 161 |
| | 39 |
| | (129 | ) | | — |
| | $ | 1,120 |
| | Investment in equity method investees | $ | 7 |
| | 12 |
| | 1,585 |
| | 134 |
| | — |
| | 33 |
| | — |
| | $ | 1,771 |
| | Capital expenditures and acquisitions | $ | 1,979 |
| | 460 |
| | 176 |
| | 91 |
| | 5 |
| | 2 |
| | — |
| | $ | 2,713 |
| | Goodwill | $ | 1,208 |
| | 743 |
| | 299 |
| | 26 |
| | 17 |
| | — |
| | — |
| | $ | 2,293 |
| | Total Assets | $ | 22,501 |
| | 5,378 |
| | 3,161 |
| | 495 |
| | 909 |
| | 6,153 |
| | (2,309 | ) | | $ | 36,288 |
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | Electric | | Gas | | Gas Storage and Pipelines | | Power and Industrial Projects | | Energy Trading | | Corporate and Other | | Reclassifications
and
Eliminations | | Total | | | (In millions) | | 2017 | | | | | | | | | | | | | | | | | Operating Revenues — Utility operations | $ | 5,102 |
| | 1,388 |
| | — |
| | — |
| | — |
| | — |
| | (56 | ) | | $ | 6,434 |
| | Operating Revenues — Non-utility operations | $ | — |
| | — |
| | 453 |
| | 2,089 |
| | 4,277 |
| | 2 |
| | (648 | ) | | $ | 6,173 |
| | Depreciation and amortization | $ | 753 |
| | 123 |
| | 76 |
| | 72 |
| | 5 |
| | 1 |
| | — |
| | $ | 1,030 |
| | Interest expense | $ | 274 |
| | 65 |
| | 77 |
| | 29 |
| | 5 |
| | 192 |
| | (106 | ) | | $ | 536 |
| | Interest income | $ | — |
| | (7 | ) | | (14 | ) | | (7 | ) | | (2 | ) | | (88 | ) | | 106 |
| | $ | (12 | ) | | Equity in earnings of equity method investees | $ | 1 |
| | 2 |
| | 90 |
| | 9 |
| | — |
| | — |
| | — |
| | $ | 102 |
| Income Tax Expense (Benefit)(a) | $ | 321 |
| | 78 |
| | (30 | ) | | (195 | ) | | 49 |
| | (48 | ) | | — |
| | $ | 175 |
| | Net Income (Loss) Attributable to DTE Energy Company | $ | 606 |
| | 146 |
| | 275 |
| | 138 |
| | 72 |
| | (103 | ) | | — |
| | $ | 1,134 |
| | Investment in equity method investees | $ | 7 |
| | 11 |
| | 879 |
| | 150 |
| | — |
| | 26 |
| | — |
| | $ | 1,073 |
| | Capital expenditures and acquisitions | $ | 1,574 |
| | 463 |
| | 137 |
| | 56 |
| | 7 |
| | 13 |
| | — |
| | $ | 2,250 |
| | Goodwill | $ | 1,208 |
| | 743 |
| | 299 |
| | 26 |
| | 17 |
| | — |
| | — |
| | $ | 2,293 |
| | Total Assets | $ | 21,163 |
| | 5,072 |
| | 2,594 |
| | 593 |
| | 725 |
| | 5,324 |
| | (1,704 | ) | | $ | 33,767 |
|
| | (a) | Includes Income Tax Expense (Benefit) of $(5) million, $(115) million, $(21) million, $2 million, and $34 million for Electric — non-utility, Gas Storage and Pipelines, Power and Industrial Projects, Energy Trading, and Corporate and Other, respectively, related to the enactment of the TCJA. |
DTE Energy Company — DTE Electric Company
Combined Notes to Consolidated Financial Statements — (Continued)
NOTE 24 — RELATED PARTY TRANSACTIONS DTE Energy enters into related party transactions with certain equity method investees, primarily between DTE Gas and 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 is charged a fixed daily pipeline reservation charge.charge for this capacity. DTE Electric and DTE Gas operating revenues from this agreement was $32 million and $6 million in 2019 and 2018, respectively. DTE Gas isare also party to arespective 20-year and 15-year service agreementagreements with NEXUS for the transportation of natural gas. Under the service agreement,agreements, NEXUS provides firm pipeline capacity to transport natural gas to DTE Electric and to service DTE Gas customers. DTE Electric and DTE Gas incursincur a firm daily pipeline reservation charge, which totaled $21 millionis recovered through the respective PSCR and $2 million in 2019 and 2018, respectively. These expenses areGCR mechanisms. DTE Energy Trading also enters into related party transactions with NEXUS for the transportation of natural gas.
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued) The following table summarizes the amounts resulting from these transactions included in Fuel, purchased power, and gas - utility on the Consolidated Statements of Operations and are recovered throughfor the GCR mechanism. years ended December 31: | | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | (In millions) | | Operating Revenues — Utility operations | | | | | | | DTE Gas | $ | 32 | | | $ | 32 | | | $ | 6 | | | Fuel, purchased power, and gas — utility | | | | | | | DTE Electric | $ | 8 | | | $ | 8 | | | $ | 1 | | | DTE Gas | $ | 21 | | | $ | 22 | | | $ | 1 | | | Fuel, purchased power, gas, and other — non-utility | | | | | | | DTE Energy Trading | $ | 27 | | | $ | 13 | | | $ | 1 | |
Other related party transactions with equity method investees include transactions with Vector Pipeline and Millennium Pipeline. TheseRefer to Note 18 to the Consolidated Financial Statements, "Leases," for lease activity related to Vector Pipeline. Other transactions relating to Vector Pipeline and Millennium Pipeline were not material for the years ended December 31, 2020, 2019, 2018, and 2017.2018. DTE Electric has agreements with affiliated companies to sell energy for resale, purchase fuel and power, provide fuel supply services, and provide power plant operation and maintenance services. DTE Electric has agreements with certain DTE Energy affiliates where DTE Electricit charges the affiliates for their use of the shared capital assets of DTE Electric. A shared services company accumulates various corporate support services expenses and charges various subsidiaries of DTE Energy, including DTE Electric. DTE Electric records federal, state, and local income taxes payable to or receivable from DTE Energy based on its federal, state, and local tax provisions. The following is a summary of DTE Electric's transactions with affiliated companies: | | | | | | | | | | | | | | | 2019 | | 2018 | | 2017 | | | (In millions) | | Revenues | | | | | | | Energy sales | $ | 10 |
| | $ | 9 |
| | $ | 9 |
| | Other services | $ | 5 |
| | $ | 4 |
| | $ | 4 |
| | Shared capital assets | $ | 47 |
| | $ | 43 |
| | $ | 39 |
| | Costs | | | | | | | Fuel and purchased power | $ | 9 |
| | $ | 7 |
| | $ | 6 |
| | Other services and interest | $ | 23 |
| | $ | 33 |
| | $ | (2 | ) | | Corporate expenses, net | $ | 372 |
| | $ | 377 |
| | $ | 370 |
| | Other | | | | | | | Dividends declared | $ | 494 |
| | $ | 461 |
| | $ | 432 |
| | Dividends paid | $ | 494 |
| | $ | 461 |
| | $ | 432 |
| | Capital contribution from DTE Energy | $ | 180 |
| | $ | 325 |
| | $ | 100 |
|
| | | | | | | | | | | | | | | | | | | 2020 | | 2019 | | 2018 | | (In millions) | | Revenues and Other Income | | | | | | | Energy sales | $ | 8 | | | $ | 10 | | | $ | 9 | | | Other services | $ | 2 | | | $ | 5 | | | $ | 4 | | | Shared capital assets | $ | 51 | | | $ | 47 | | | $ | 43 | | | Costs | | | | | | | Fuel and purchased power | $ | 16 | | | $ | 9 | | | $ | 7 | | | Other services and interest | $ | 1 | | | $ | 23 | | | $ | 33 | | | Corporate expenses | $ | 367 | | | $ | 372 | | | $ | 377 | | | Other | | | | | | | Dividends declared | $ | 539 | | | $ | 494 | | | $ | 461 | | | Dividends paid | $ | 539 | | | $ | 494 | | | $ | 461 | | | Capital contribution from DTE Energy | $ | 636 | | | $ | 180 | | | $ | 325 | |
DTE Electric's Accounts receivable and Accounts payable related to Affiliates are payable upon demand and are generally settled in cash within a monthly business cycle. Notes receivable and Short-term borrowings related to Affiliates are subject to a credit agreement with DTE Energy whereby short-term excess cash or cash shortfalls are remitted to or funded by DTE Energy. This credit arrangement involves the charge and payment of interest at market-based rates. Refer to DTE Electric's Consolidated Statements of Financial Position for affiliate balances at December 31, 20192020 and 2018.2019. There were 0 contributions made by DTE Electric to the DTE Energy Foundation for the years ended December 31, 2019 and 2018. There were $7$20 million in charitable contributions made by DTE Electric to the DTE Energy Foundation for the year ended December 31, 2017.2020 and 0 contributions for the years ended December 31, 2019, and 2018. The DTE Energy Foundation is a non-consolidated not-for-profit private foundation, the purpose of which is to contribute and assist charitable organizations. See the following notes for other related party transactions impacting DTE Electric’s Consolidated Financial Statements:
| | | | Note | | Title | 1 | | Organization and Basis of Presentation | 21 | | Retirement Benefits and Trusteed Assets | 22 | | Stock-Based Compensation |
154
DTE Energy Company — DTE Electric Company Combined Notes to Consolidated Financial Statements — (Continued)
| | | | | | | | | | Note | | Title | | | | | 1 | | Organization and Basis of Presentation | | 21 | | Retirement Benefits and Trusteed Assets | | 22 | | Stock-Based Compensation |
NOTE 25 — SUPPLEMENTARY QUARTERLY FINANCIAL INFORMATION (UNAUDITED) DTE Energy QuarterlyThe sum of quarterly earnings per share may not equal full year totals,year-end amounts, since quarterly computations are based on weighted average common shares outstanding during each quarter.
| | | | | | | | | | | | | | | | | | | | | | | First
Quarter | | Second
Quarter | | Third
Quarter | | Fourth
Quarter | | Year | | | (In millions, except per share amounts) | | 2019 | | | | | | | | | | | Operating Revenues | $ | 3,514 |
| | $ | 2,888 |
| | $ | 3,119 |
| | $ | 3,148 |
| | $ | 12,669 |
| | Operating Income | $ | 542 |
| | $ | 300 |
| | $ | 450 |
| | $ | 415 |
| | $ | 1,707 |
| | Net Income Attributable to DTE Energy Company | $ | 401 |
| | $ | 182 |
| | $ | 319 |
| | $ | 267 |
| | $ | 1,169 |
| | Basic Earnings per Share | $ | 2.20 |
| | $ | 0.99 |
| | $ | 1.74 |
| | $ | 1.40 |
| | $ | 6.32 |
| | Diluted Earnings per Share | $ | 2.19 |
| | $ | 0.99 |
| | $ | 1.73 |
| | $ | 1.40 |
| | $ | 6.31 |
| | 2018 | | | | | | | | | | | Operating Revenues | $ | 3,753 |
| | $ | 3,159 |
| | $ | 3,550 |
| | $ | 3,750 |
| | $ | 14,212 |
| | Operating Income | $ | 504 |
| | $ | 329 |
| | $ | 429 |
| | $ | 332 |
| | $ | 1,594 |
| | Net Income Attributable to DTE Energy Company | $ | 361 |
| | $ | 234 |
| | $ | 334 |
| | $ | 191 |
| | $ | 1,120 |
| | Basic Earnings per Share | $ | 2.01 |
| | $ | 1.29 |
| | $ | 1.84 |
| | $ | 1.05 |
| | $ | 6.18 |
| | Diluted Earnings per Share | $ | 2.00 |
| | $ | 1.29 |
| | $ | 1.84 |
| | $ | 1.05 |
| | $ | 6.17 |
|
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | First
Quarter | | Second
Quarter | | Third
Quarter | | Fourth
Quarter | | Year | | (In millions, except per share amounts) | | 2020 | | | | | | | | | | | Operating Revenues | $ | 3,022 | | | $ | 2,583 | | | $ | 3,284 | | | $ | 3,288 | | | $ | 12,177 | | | Operating Income | $ | 546 | | | $ | 367 | | | $ | 608 | | | $ | 465 | | | $ | 1,986 | | | Net Income Attributable to DTE Energy Company | $ | 340 | | | $ | 277 | | | $ | 476 | | | $ | 275 | | | $ | 1,368 | | | Basic Earnings per Share | $ | 1.77 | | | $ | 1.44 | | | $ | 2.47 | | | $ | 1.42 | | | $ | 7.09 | | | Diluted Earnings per Share | $ | 1.76 | | | $ | 1.44 | | | $ | 2.46 | | | $ | 1.42 | | | $ | 7.08 | | | 2019 | | | | | | | | | | | Operating Revenues | $ | 3,514 | | | $ | 2,888 | | | $ | 3,119 | | | $ | 3,148 | | | $ | 12,669 | | | Operating Income | $ | 542 | | | $ | 300 | | | $ | 450 | | | $ | 415 | | | $ | 1,707 | | | Net Income Attributable to DTE Energy Company | $ | 401 | | | $ | 182 | | | $ | 319 | | | $ | 267 | | | $ | 1,169 | | | Basic Earnings per Share | $ | 2.20 | | | $ | 0.99 | | | $ | 1.74 | | | $ | 1.40 | | | $ | 6.32 | | | Diluted Earnings per Share | $ | 2.19 | | | $ | 0.99 | | | $ | 1.73 | | | $ | 1.40 | | | $ | 6.31 | |
DTE Electric | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | First
Quarter | | Second
Quarter | | Third
Quarter | | Fourth
Quarter | | Year | | (In millions) | | 2020 | | | | | | | | | | | Operating Revenues | $ | 1,212 | | | $ | 1,309 | | | $ | 1,690 | | | $ | 1,295 | | | $ | 5,506 | | | Operating Income | $ | 214 | | | $ | 263 | | | $ | 541 | | | $ | 206 | | | $ | 1,224 | | | Net Income | $ | 94 | | | $ | 183 | | | $ | 400 | | | $ | 101 | | | $ | 778 | | | 2019 | | | | | | | | | | | Operating Revenues | $ | 1,235 | | | $ | 1,190 | | | $ | 1,519 | | | $ | 1,280 | | | $ | 5,224 | | | Operating Income | $ | 226 | | | $ | 223 | | | $ | 440 | | | $ | 224 | | | $ | 1,113 | | | Net Income | $ | 147 | | | $ | 133 | | | $ | 307 | | | $ | 129 | | | $ | 716 | |
| | | | | | | | | | | | | | | | | | | | | | | First
Quarter | | Second
Quarter | | Third
Quarter | | Fourth
Quarter | | Year | | | (In millions) | | 2019 | | | | | | | | | | | Operating Revenues | $ | 1,235 |
| | $ | 1,190 |
| | $ | 1,519 |
| | $ | 1,280 |
| | $ | 5,224 |
| | Operating Income | $ | 226 |
| | $ | 223 |
| | $ | 440 |
| | $ | 224 |
| | $ | 1,113 |
| | Net Income | $ | 147 |
| | $ | 133 |
| | $ | 307 |
| | $ | 129 |
| | $ | 716 |
| | 2018 | | | | | | | | | | | Operating Revenues | $ | 1,205 |
| | $ | 1,276 |
| | $ | 1,521 |
| | $ | 1,296 |
| | $ | 5,298 |
| | Operating Income | $ | 253 |
| | $ | 269 |
| | $ | 444 |
| | $ | 168 |
| | $ | 1,134 |
| | Net Income | $ | 140 |
| | $ | 163 |
| | $ | 305 |
| | $ | 56 |
| | $ | 664 |
|
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure None.
Item 9A. Controls and Procedures See Item 8. Financial Statements and Supplementary Data for management’s evaluation of the Registrants' disclosure controls and procedures, their report on internal control over financial reporting, and their conclusion on changes in internal control over financial reporting.
Item 9B. Other Information None.
Part III Item 10. Directors, Executive Officers, and Corporate Governance
Item 11. Executive Compensation
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
Item 13. Certain Relationships and Related Transactions, and Director Independence
DTE Electric
Information required of DTE Electric by Part III (Items 10, 11, 12, and 13) of this Form 10-K is omitted per General Instruction I (2) (c) of Form 10-K for wholly-owned subsidiaries (reduced disclosure format).
Item 14. Principal Accountant Fees and Services
DTE Energy
Information required of DTE Energy by Part III (Items 10, 11, 12, 13, and 14) of this Form 10-K is incorporated by reference from DTE Energy’s definitive Proxy Statement for its 20202021 Annual Meeting of Shareholders to be held May 7, 2020.20, 2021. The Proxy Statement will be filed with the SEC, pursuant to Regulation 14A, not later than 120 days after the end of DTE Energy's fiscal year covered by this report on Form 10-K, all of which information is hereby incorporated by reference in, and made part of, this Form 10-K.
Information required of DTE Electric by Part III (Items 10, 11, 12, and 13) of this Form 10-K is omitted per General Instruction I (2) (c) of Form 10-K for wholly-owned subsidiaries (reduced disclosure format).
Item 10. Directors, Executive Officers, and Corporate Governance
Item 11. Executive Compensation
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
Item 13. Certain Relationships and Related Transactions, and Director Independence
Item 14. Principal Accountant Fees and Services DTE Electric For the years ended December 31, 2019 and 2018, professional services were performed by PricewaterhouseCoopers LLP (PwC). The following table presents fees for professional services rendered by PwCPricewaterhouseCoopers LLP (PwC) for the audit of DTE Electric’s consolidated annual financial statements for the years ended December 31, 20192020 and 2018, respectively,2019 and fees billed for other services rendered by PwC during those periods.
| | | | 2019 | | 2018 | | 2020 | | 2019 | Audit fees(a) | $ | 1,408,900 |
| | $ | 1,393,500 |
| Audit fees(a) | $ | 1,492,572 | | | $ | 1,408,900 | | Audit-related fees(b) | 52,000 |
| | 52,000 |
| Audit-related fees(b) | 12,000 | | | 52,000 | | | Total | $ | 1,460,900 |
| | $ | 1,445,500 |
| Total | $ | 1,504,572 | | | $ | 1,460,900 | |
| | (a) | Represents the aggregate fees for the audits of DTE Electric’s annual financial statements included in the Annual Reports on Form 10-K and for the reviews of the financial statements included in the Quarterly Reports on Form 10-Q. |
| | (b) | Represents the aggregate fees billed for audit-related services for various attest services. |
(a)Represents the aggregate fees for the audits of DTE Electric’s consolidated financial statements included in the Annual Reports on Form 10-K, reviews of the consolidated financial statements included in the Quarterly Reports on Form 10-Q, and audit services provided in connection with certain regulatory filings and debt issuances. Audit fees are presented on an Audit Year basis in accordance with SEC guidelines and include an estimate of fees incurred for the most recent Audit Year. (b)Represents the aggregate fees billed for audit-related services and various attest services. The above listed fees were pre-approved by the DTE Energy Audit Committee. Prior to engagement, the DTE Energy Audit Committee pre-approves these services by category of service. The DTE Energy Audit Committee may delegate to the chair of the Audit Committee, or to one or more other designated members of the Audit Committee, the authority to grant pre-approvals of all permitted services or classes of these permitted services to be provided by the independent auditor up to, but not exceeding, a pre-defined limit.auditor. The decision of the designated member to pre-approve a permitted service will be reported to the DTE Energy Audit Committee at the next scheduled meeting.
Part IV Item 15. Exhibits and Financial Statement Schedules A.The following documents are filed as part of this Annual Report on Form 10-K. (a)Consolidated Financial Statements. See "Item 8 — Financial Statements and Supplementary Data." (b)Financial statement schedule. See "Item 8 — Financial Statements and Supplementary Data." (c)Exhibits. | | | | | | | | | | | | | | | | | | | | | A.Exhibit Number | The following documents are filed as part of this Annual Report on Form 10-K. | Description | | DTE
Energy | | DTE
Electric |
| | | | | | | (1) | Consolidated Financial Statements. See "Item 8 — Financial Statements and Supplementary Data." |
| (i) Exhibits filed herewith: | | | (2) | Financial statement schedule. See "Item 8 — Financial Statements and Supplementary Data." |
| | | | | | | | Exhibit Number | | Description | | DTE
| | DTE
Electric
| | | | | | | | | | (i) Exhibits filed herewith: | | | | | | | | | | | | | | Supplemental Indenture dated as of November 1, 2019, to the Amended and Restated Indenture, dated as of April 9, 2001, between DTE Energy Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee. (2019 Series G and H) | | X | | | | | | | | | | | | Description of the Company’s Common stock | | X | | | | | | | | | | | | Description of the Company’s: 2012 Series C 5.25% Junior Subordinated Debentures due 2062; 2016 Series B 5.375% Junior Subordinated Debentures due 2076; 2016 Series F 6.00% Junior Subordinated Debentures due 2076; and 2017 Series E 5.25% Junior Subordinated Debentures due 2077 | | X | | | | | | | | | | | | Description of the Company's 2019 6.25% Corporate UnitsCompany’s 2020 Series G 4.375% Junior Subordinated Debentures due 2080 | | X | | | | | | | | | | | | Certain arrangements pertaining to the employment of Gerardo Norcia, dated July 1, 2019 | | X | | | | | | | | | | | | Subsidiaries of DTE Energy | | X | | | | | | | | | | | | Consent of PricewaterhouseCoopers LLP | | X | | | | | | | | | | | | Consent of PricewaterhouseCoopers LLP | | | | X | | | | | | | | | | Chief Executive Officer Section 302 Form 10-K Certification of Periodic Report | | X | | | | | | | | | | | | Chief Financial Officer Section 302 Form 10-K Certification of Periodic Report | | X | | | | | | | | | | | | Chief Executive Officer Section 302 Form 10-K Certification of Periodic Report | | | | X | | | | | | | | | | Chief Financial Officer Section 302 Form 10-K Certification of Periodic Report | | | | X | | | | | | | | | 101.INS | | XBRL Instance Document | | X | | X | | | | | | | | | 101.SCH | | XBRL Taxonomy Extension Schema | | X | | X | | | | | | | | | 101.CAL | | XBRL Taxonomy Extension Calculation Linkbase | | X | | X | | | | | | | | | 101.DEF | | XBRL Taxonomy Extension Definition Database | | X | | X | | | | | | | | | 101.LAB | | XBRL Taxonomy Extension Label Linkbase | | X | | X | | | | | | | | | 101.PRE | | XBRL Taxonomy Extension Presentation Linkbase | | X | | X | | | | | | | | | 104 | | Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101) | | X | | X | | | | | | | | | | (ii) Exhibits furnished herewith: | | | | | | | | | | | | | | Chief Executive Officer Section 906 Form 10-K Certification of Periodic Report | | X | | | | | | | | | | | | Chief Financial Officer Section 906 Form 10-K Certification of Periodic Report | | X | | | | | | | | | | | | Chief Executive Officer Section 906 Form 10-K Certification of Periodic Report | | | | X | | | | | | | | | | Chief Financial Officer Section 906 Form 10-K Certification of Periodic Report | | | | X |
| | | | | | | | | (iii) Exhibits incorporated by reference: | | | | | | | | | | | | Exhibit Number | | Description | | DTE
Energy
| | DTE
Electric
| | | | | | | | | | | | | | | | | (iii) Exhibits incorporated by reference: | | | | | | | | | | | | | Certain exhibits listed below refer to "The Detroit Edison Company" and "Michigan Consolidated Gas Company" and were effective prior to the change to DTE Electric Company and DTE Gas Company, respectively, effective January 1, 2013. | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | 3(a)Exhibit Number | | Description | | DTE
Energy | | DTE
Electric | | | | | | | | | 3(a) | | | | X | | | | | | | | | | | 3(b) | | | | X | | | | | | | | | | | 3(c) | | | | | | X | | | | | | | | | 3(d) | | | | | | X | | | | | | | | | 4(a) | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X
| | | | | | | | | | | | | | X
| | | | | | | | | | | | | | X | | | | | | | | | | | | | | X
| | | | | | | | | | | | | | X | | | | | | | | | |
| | | | | | | | Exhibit Number | | Description | | DTE
Energy
| | DTE
Electric
| | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | Exhibit Number | | Description | | DTE
Energy | | DTE
Electric | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | 4(b) | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | 4(b) | | Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit B-1 to Detroit Edison's Registration Statement on Form A-2 (File No. 2-1630)) and indentures supplemental thereto, dated as of dates indicated below, and filed as exhibits to the filings set forth below: | | X | | X | | | | | | | | | | Supplemental Indenture, dated as of December 1, 1940, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit B-14 to Detroit Edison's Registration Statement on Form A-2 (File No. 2-4609)). (amendment) | | X | | X | | | | | | | | | | Supplemental Indenture, dated as of September 1, 1947, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit B-20 to Detroit Edison's Registration Statement on Form S-1 (File No. 2-7136)). (amendment) | | X | | X | | | | | | | | | | Supplemental Indenture, dated as of March 1, 1950, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit B-22 to Detroit Edison's Registration Statement on Form S-1 (File No. 2-8290)). (amendment) | | X | | X | | | | | | | | | | Supplemental Indenture, dated as of November 15, 1951, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit B-23 to Detroit Edison's Registration Statement on Form S-1 (File No. 2-9226)). (amendment) | | X | | X | | | | | | | | | | Supplemental Indenture, dated as of August 15, 1957, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 3-B-30 to Detroit Edison's Form 8-K dated September 11, 1957). (amendment) | | X | | X | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | Exhibit Number | | Description | | DTE
Energy | | DTE
Electric | | | | | | | | | | Supplemental Indenture, dated as of December 1, 1966, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 2-B-32 to Detroit Edison's Registration Statement on Form S-9 (File No. 2-25664)). (amendment) | | X | | X | | | | | | | | | | | | X | | X | | | | | | | |
| | | | | | | | Exhibit Number | | Description | | DTE
Energy
| | DTE
Electric
| | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | Exhibit Number | | Description | | DTE
Energy | | DTE
Electric | | | | | | | | Exhibit Number | | Description | | DTE
Energy
| | DTE
Electric
| | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | Supplemental Indenture, dated as of August 15, 2011, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A. as successor trustee (Exhibit 4-277 to Detroit Edison's Form 10-Q for the quarter ended September 30, 2011). (2011 Series D, 2011 Series E, 2011 Series F) | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | |
| | | | | | | | Exhibit Number | | Description | | DTE
Energy
| | DTE
Electric
| | | | | | | | | | | | X | | X | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | Exhibit Number | | Description | | DTE
Energy | | DTE
Electric | | | | | | | | | | | | X | | X | | | | | | | | 4(c) | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | 4(c) | | Collateral Trust Indenture, dated as of June 30, 1993, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4-152 to Detroit Edison's Registration Statement (File No. 33-50325)) and indentures supplemental thereto, dated as of dates indicated below, and filed as exhibits to the filings set forth below: | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | Eighteenth Supplemental Indenture, dated as of September 15, 2005, to the Collateral Trust Indenture, dated as of June 30, 1993, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4.1 to Detroit Edison's Form 8-K dated September 29, 2005). (2005 Series C 5.19% Senior Notes due October 1, 2023) | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | Exhibit Number | | Description | | DTE
Energy | | DTE
Electric | | | | | | | | Exhibit Number4(d) | | Description | | DTE
Energy
| | DTE
Electric
| | | | | | | | | | | | X | | X | | | | | | | | | | | | X | | X | | | | | | | | 4(d) | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | 4(e) | | Indenture of Mortgage and Deed of Trust dated as of March 1, 1944 (Exhibit 7-D to Michigan Consolidated Gas Company Registration Statement No. 2-5252) and indentures supplemental thereto, dated as of dates indicated below, and filed as exhibits to the filings set forth below: | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | |
| | | | | | | | Exhibit Number | | Description | | DTE
Energy
| | DTE
Electric
| | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | Exhibit Number | | Description | | DTE
Energy | | DTE
Electric | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | 10(a) | | | | X | | | | | | | | | | | 10(b) | | Certain arrangements pertaining to the employment of Gerard M. Anderson with The Detroit Edison Company, dated October 6, 1993 (Exhibit 10-48 to The Detroit Edison Company's Form 10-K for the year ended December 31, 1993) | | X | | X | | | | | | | | | 10(c) | | | | X | | X | | | | | | | | | 10(d) | | | | X | | | | | | | | | | | 10(e) | | | | X | | | | | | | | | | | 10(f) | | | | X | | |
| | | | | | | | Exhibit Number10(g) | | Description | | DTE
Energy
| | DTE
Electric
| | | | | | | | | | | | | | | 10(g) | | | | X | | X | | | | | | | | | 10(h) | | | | X | | | | | | | | | | | 10(i) | | | | X | | | | | | | | | | | 10(j) | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | 10(k) | | | | X | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | 10(l)Exhibit Number | | Description | | DTE
Energy | | DTE
Electric | | | | | | | | | 10(l) | | | | X | | | | | | | | | | | 10(m) | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | 10(n) | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | 10(o) | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | 10(p) | | | | X | | | | | | | | | | | | | | X | | | | | | | | | |
| | | | | | | | Exhibit Number10(q) | | Description | | DTE
Energy
| | DTE
Electric
| | | | | | | | 10(q) | | | | X | | | | | | | | | | | | | | X | | | | | | | | | | | 10(r) | | Form of Third Amended and Restated DTE Energy Company Five-Year Credit Agreement, dated as of October 21, 2011 and amended and restated as of April 16, 2015, by and among DTE Energy Company, the lenders party thereto, Citibank, N.A., as Administrative Agent, and Barclays Bank PLC, The Bank of Nova Scotia and JPMorgan Chase Bank, N.A. as Co-Syndication Agents (Exhibit 10.01 to DTE Energy Company's Form 8-K filed on April 21, 2015) | | X | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | 10(s)Exhibit Number | | Description | | DTE
Energy | | DTE
Electric | | | | | | | | | 10(s) | | Request for Extension of Termination Date, dated as of April 16, 2017, to the Third Amended and Restated Five-Year Credit Agreement, dated as of October 21, 2011, amended and restated as of April 5, 2013, and amended and restated as of April 16, 2015, by and among DTE Energy, the lenders party thereto, Citibank, N.A., as Administrative Agent, and Barclays Bank PLC, The Bank of Nova Scotia and JPMorgan Chase Bank, N.A, as Co-Syndication Agents (Exhibit 10.104 to DTE Energy’s Form 10-Q for the quarter ended June 30, 2017) | | X | | | | | | | | | | | | Form of Third Amended and Restated DTE Gas Company Five-Year Credit Agreement, dated as of October 21, 2011 and amended and restated as of April 16, 2015, by and among DTE Gas Company, the lenders party thereto, JPMorgan Chase Bank, N.A., as Administrative Agent, and Barclays Bank PLC, Citibank, N.A., and Bank of America, N.A., as Co-Syndication Agents (Exhibit 10.02 to DTE Energy Company's Form 8-K filed on April 21, 2015) | | X | | | | | | | | | | | 10(t) | | Request for Extension of Termination Date, dated as of April 16, 2017, to the Third Amended and Restated Five-Year Credit Agreement, dated as of October 21, 2011, amended and restated as of April 5, 2013, and amended and restated as of April 16, 2015, by and among DTE Gas the lenders party thereto, JPMorgan Chase Bank, N.A., as Administrative Agent, and Barclays Bank PLC, Citibank, N.A. and Bank of America, N.A., as Co-Syndication Agents (Exhibit 10.105 to DTE Energy’s Form 10-Q for the quarter ended June 30, 2017) | | X
| | | | | | | | | | | | Form of Third Amended and Restated DTE Electric Company Five-Year Credit Agreement, dated as of October 21, 2011 and amended and restated as of April 16, 2015, by and among DTE Electric Company, the lenders party thereto, Barclays Bank PLC, as Administrative Agent, and Citibank N.A., JPMorgan Chase Bank, N.A., and Wells Fargo Bank, National Association as Co-Syndication Agents (Exhibit 10.01 to DTE Energy Company's and DTE Electric Company's Form 8-K filed on April 21, 2015) | | X | | X | | | | | | | | | 10(u) | | Request for Extension of Termination Date, dated as of April 16, 2017, to the Third Amended and Restated Five-Year Credit Agreement, dated as of October 21, 2011, amended and restated as of April 5, 2013, and further amended and restated as of April 16, 2015, by and among DTE Electric Company, the lenders party thereto, Barclays Bank PLC., as Administrative Agent, and Citibank, N.A., JPMorgan Chase Bank, N.A. and Wells Fargo Bank, National Association as Co-Syndication Agents (Exhibit 10.106 to DTE Energy’s and DTE Electric Company's Form 10-Q for the quarter ended June 30, 2017) | | X | | X | | | | | | | | | | | | X | | | | | | | | | | | 10(v) | | | | X | | | | | | | | | |
| | | | | | | | Exhibit Number10(w) | | Description | | DTE
Energy
| | DTE
Electric
| | | | | | | | 10(w) | |
| | X | | | | | | | | | | | 10(x) | | Certain arrangements pertaining to the employment of Gerardo Norcia, dated July 1, 2019 (Exhibit 10.107 to DTE Energy's Form 10-K for the year ended December 31, 2019) | | X | | | | | | | | | | | 10(y) | | | | X | | | | | | | | | | | 10(z) | | | | X | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | Exhibit Number | | Description | | DTE
Energy | | DTE
Electric | | | | | | | | | 10(aa) | | | | X | | | | | | | | | | | 10(bb) | | | | X | | | | | | | | | | | 10(cc) | | | | X | | X | | | | | | | | | 10(dd) | | | | X | | X | | | | | | | | | 10(ee) | | | | X | | |
Item 16. Form 10-K Summary None.
DTE Energy Company Schedule II — Valuation and Qualifying Accounts | | | | | | | | | | | | | | | | | | | Year Ending December 31, | | 2020 | | 2019 | | 2018 | | (In millions) | | Allowance for Doubtful Accounts (shown as deduction from Accounts receivable in DTE Energy's Consolidated Statements of Financial Position) | | | | | | | Balance at Beginning of Period | $ | 91 | | | $ | 91 | | | $ | 49 | | | Additions: | | | | | | | Charged to costs and expenses | 103 | | | 111 | | | 140 | | Charged to other accounts(a) | 50 | | | 56 | | | 55 | | Deductions(b) | (140) | | | (167) | | | (153) | | | Balance at End of Period | $ | 104 | | | $ | 91 | | | $ | 91 | |
| | | | | | | | | | | | | | | Year Ending December 31, | | | 2019 | | 2018 | | 2017 | | | (In millions) | | Allowance for Doubtful Accounts (shown as deduction from Accounts receivable in DTE Energy's Consolidated Statements of Financial Position) | | | | | | | Balance at Beginning of Period | $ | 91 |
| | $ | 49 |
| | $ | 41 |
| | Additions: | | | | | | | Charged to costs and expenses | 111 |
| | 140 |
| | 80 |
| Charged to other accounts(a) | 56 |
| | 55 |
| | 26 |
| Deductions(b) | (167 | ) | | (153 | ) | | (98 | ) | | Balance at End of Period | $ | 91 |
| | $ | 91 |
| | $ | 49 |
|
_______________________________________(a)Collection of accounts previously written off. | | (a) | Collection of accounts previously written off. |
| | (b) | Uncollectible accounts written off. |
(b)Uncollectible accounts written off.
DTE Electric Company Schedule II — Valuation and Qualifying Accounts | | | | | | | | | | | | | | | | | | | Year Ending December 31, | | 2020 | | 2019 | | 2018 | | (In millions) | | Allowance for Doubtful Accounts (shown as deduction from Accounts receivable in DTE Electric's Consolidated Statements of Financial Position) | | | | | | | Balance at Beginning of Period | $ | 46 | | | $ | 53 | | | $ | 31 | | | Additions: | | | | | | | Charged to costs and expenses | 61 | | | 65 | | | 85 | | Charged to other accounts(a) | 30 | | | 36 | | | 36 | | Deductions(b) | (80) | | | (108) | | | (99) | | | Balance at End of Period | $ | 57 | | | $ | 46 | | | $ | 53 | |
| | | | | | | | | | | | | | | Year Ending December 31, | | | 2019 | | 2018 | | 2017 | | | (In millions) | | Allowance for Doubtful Accounts (shown as deduction from Accounts receivable in DTE Electric's Consolidated Statements of Financial Position) | | | | | | | Balance at Beginning of Period | $ | 53 |
| | $ | 31 |
| | $ | 25 |
| | Additions: | | | | | | | Charged to costs and expenses | 65 |
| | 85 |
| | 55 |
| Charged to other accounts(a) | 36 |
| | 36 |
| | 14 |
| Deductions(b) | (108 | ) | | (99 | ) | | (63 | ) | | Balance at End of Period | $ | 46 |
| | $ | 53 |
| | $ | 31 |
|
_______________________________________(a)Collection of accounts previously written off. | | (a) | Collection of accounts previously written off. |
| | (b) | Uncollectible accounts written off. |
(b)Uncollectible accounts written off.
Signatures Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, DTE Energy Company has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized. | | | | | | | | | | | DTE ENERGY COMPANY | | | (Registrant) | | | | | | | | By: | DTE ENERGY COMPANY | | | (Registrant) | | | | | | | | By: | /S/ GERARDO NORCIA | | | Gerardo Norcia
President and
Chief Executive Officer |
Date: February 5, 202019, 2021
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of DTE Energy Company and in the capacities and on the date indicated.
| | | | | | | | | | | | | | | | By: | /S/ GERARDO NORCIA | | By: | /S/ PETER B. OLEKSIAKDAVID RUUD | | Gerardo Norcia
President,
Chief Executive Officer, and Director
(Principal Executive Officer) | | | Peter B. OleksiakDavid Ruud
Senior Vice President and
Chief Financial Officer
(Principal Financial Officer) | | | | | | | By: | /S/ MARK C. ROLLING | | By: | /S/ RUTH G. SHAW | | Mark C. Rolling
Vice President, Controller, and Chief Accounting Officer
(Principal Accounting Officer)
| | | Ruth G. Shaw, Director | | | | | | | By: | /S/ GERARD M. ANDERSON | | By: | /S/ ROBERT C. SKAGGS, JR. | | Gerard M. Anderson | | | Robert C. Skaggs, Jr., Director | | Executive Chairman, and Director | | | | | | | | | | By: | /S/ DAVID A. BRANDON | | By: | /S/ DAVID A. THOMAS | | David A. Brandon, Director | | | David A. Thomas, Director | | | | | | | By: | /S/ W. FRANK FOUNTAIN, JR. | | By: | /S/ GARY TORGOW | | W. Frank Fountain, Jr., Director | | | Gary Torgow, Director | | | | | | By: | /S/ CHARLES G. MCCLURE JR. | | By: | /S/ JAMES H. VANDENBERGHEGARY TORGOW | | Charles G. McClure Jr., Director | | | James H. Vandenberghe,Gary Torgow, Director | | | | | | | By: | /S/ GAIL J. MCGOVERN | | By: | /S/ JAMES H. VANDENBERGHE | | Gail J. McGovern, Director | | | James H. Vandenberghe, Director | | | | | | | By: | /S/ MARK A. MURRAY | | By: | /S/ VALERIE M. WILLIAMS | | Gail J. McGovern,Mark A. Murray, Director | | | Valerie M. Williams, Director | | | | | | By: | /S/ MARK A. MURRAY | | | | | Mark A. Murray, Director | | | | | | | | | | | | | | | | | | |
Date: February 5, 2020
Signatures Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, DTE Electric Company has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized. | | | | | | | | | | | DTE ELECTRIC COMPANY | | | (Registrant) | | | | | | | | By: | DTE ELECTRIC COMPANY | | | (Registrant) | | | | | | | | By: | /S/ GERARDO NORCIA | | | Gerardo Norcia
President and
Chief Executive Officer
|
Date: February 5, 202019, 2021 Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of DTE Electric Company and in the capacities and on the date indicated. | | | | | | | | | | | | | | | | By: | /S/ GERARDO NORCIA | | By: | /S/ PETER B. OLEKSIAKDAVID RUUD | | Gerardo Norcia
President,
Chief Executive Officer, and Director
(Principal Executive Officer) | | | Peter B. Oleksiak
Senior Vice President,David Ruud
Chief Financial Officer, and Director
(Principal Financial Officer) | | | | | | | By: | /S/ MARK C. ROLLING | | By: | /S/ JOANN CHAVEZ | | Mark C. Rolling
Vice President, Controller, and Chief Accounting Officer
(Principal Accounting Officer)
| | | JoAnn Chavez, Director | | | | | | | By: | /S/ LISA A. MUSCHONG | | | | | Lisa A. Muschong, Director | | | |
Date: February 5, 202019, 2021 Supplemental Information to be Furnished with Reports Filed Pursuant to Section 15(d) of the Securities Exchange Act of 1934 by Registrants Which Have Not Registered Securities Pursuant to Section 12 of the Securities Exchange Act of 1934. No annual report, proxy statement, form of proxy, or other proxy soliciting material has been sent to security holders of DTE Electric Company during the period covered by this Annual Report on Form 10-K for the fiscal year ended December 31, 2019.2020.
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