10-Q

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

__________________________________________

FORM 10-Q

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the Quarterly Period ended June 30, 2019

Or

☐ TRANSITION REPORT PURSUANT TO SECTION 12 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Commission File Number: 1-11607

DTE Energy Company

Michigan	38-3217752
(State or other jurisdiction of incorporation or organization)	(I.R.S Employer Identification No.)

Commission File Number: 1-2198

DTE Electric Company

Michigan	38-0478650
(State or other jurisdiction of incorporation or organization)	(I.R.S Employer Identification No.)

Registrants address of principal executive offices: One Energy Plaza, Detroit, Michigan 48226-1279

Registrants telephone number, including area code: (313) 235-4000

Securities registered pursuant to Section 12(b) of the Act:

Title of Each Class	Trading Symbol(s)	Name of Exchange on which Registered
Common stock, without par value	DTE	New York Stock Exchange
2012 Series C 5.25% Junior Subordinated Debentures due 2062	DTQ	New York Stock Exchange
2016 Series B 5.375% Junior Subordinated Debentures due 2076	DTJ	New York Stock Exchange
2016 Series F 6.00% Junior Subordinated Debentures due 2076	DTY	New York Stock Exchange
2017 Series E 5.25% Junior Subordinated Debentures due 2077	DTW	New York Stock Exchange
6.50% Corporate Units	DTV	New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

DTE Energy Company (DTE Energy) Yes ☒ No ☐ DTE Electric Company (DTE Electric) Yes ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

DTE Energy Yes ☒ No ☐ DTE Electric Yes ☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.

DTE Energy	Large accelerated filer	Accelerated filer	Non-accelerated filer	Smaller reporting company	Emerging growth company
	☒	☐	☐	☐	☐
DTE Electric	Large accelerated filer	Accelerated filer	Non-accelerated filer	Smaller reporting company	Emerging growth company
	☐	☐	☒	☐	☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

DTE Energy Yes ☐ No ☒ DTE Electric Yes ☐ No ☒

Number of shares of Common Stock outstanding at June 30, 2019:

Registrant	Description	Shares
DTE Energy	Common Stock, without par value	183,301,732
DTE Electric	Common Stock, $10 par value, directly owned by DTE Energy	138,632,324

This combined Form 10-Q is filed separately by two registrants: DTE Energy and DTE Electric. Information contained herein relating to any individual registrant is filed by such registrant solely on its own behalf. DTE Electric makes no representation as to information relating exclusively to DTE Energy.

DTE Electric, a wholly-owned subsidiary of DTE Energy, meets the conditions set forth in General Instructions H(1)(a) and (b) of Form 10-Q and is therefore filing this form with the reduced disclosure format specified in General Instructions H(2) of Form 10-Q.

TABLE OF CONTENTS

		Page
	Definitions	1
	Filing Format	3
	Forward-Looking Statements	3
PART I - FINANCIAL INFORMATION
Item 1.	Financial Statements
	DTE Energy Consolidated Financial Statements (Unaudited)	5
	DTE Electric Consolidated Financial Statements (Unaudited)	13
	Combined Notes to Consolidated Financial Statements (Unaudited)	19
	Note 1 — Organization and Basis of Presentation	19
	Note 2 — Significant Accounting Policies	22
	Note 3 — New Accounting Pronouncements	24
	Note 4 — Revenue	26
	Note 5 — Regulatory Matters	28
	Note 6 — Earnings Per Share	29
	Note 7 — Fair Value	30
	Note 8 — Financial and Other Derivative Instruments	37
	Note 9 — Long-Term Debt	42
	Note 10 — Short-Term Credit Arrangements and Borrowings	42
	Note 11 — Leases	43
	Note 12 — Commitments and Contingencies	49
	Note 13 — Retirement Benefits and Trusteed Assets	54
	Note 14 — Segment and Related Information	56
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	58
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	73
Item 4.	Controls and Procedures	76
PART II - OTHER INFORMATION
Item 1.	Legal Proceedings	77
Item 1A.	Risk Factors	77
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	77
Item 6.	Exhibits	78
	Signatures	79

DEFINITIONS

AFUDC	Allowance for Funds Used During Construction
AGS	Appalachia Gathering System is a midstream natural gas asset located in Pennsylvania and West Virginia. DTE Energy purchased 100% of AGS in October 2016, and this asset is part of DTE Energy's Gas Storage and Pipelines segment.
ASU	Accounting Standards Update issued by the FASB
CAD	Canadian Dollar (C$)
CCR	Coal Combustion Residuals
CFTC	U.S. Commodity Futures Trading Commission
DTE Electric	DTE Electric Company (a direct wholly-owned subsidiary of DTE Energy) and subsidiary companies
DTE Energy	DTE Energy Company, directly or indirectly the parent of DTE Electric, DTE Gas, and numerous non-utility subsidiaries
DTE Gas	DTE Gas Company (an indirect wholly-owned subsidiary of DTE Energy) and subsidiary companies
EGU	Electric Generating Unit
ELG	Effluent Limitations Guidelines
EPA	U.S. Environmental Protection Agency
Equity units	DTE Energy's 2016 equity units issued in October 2016, which were used to finance the October 1, 2016 Gas Storage and Pipelines acquisition
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
FOV	Finding of Violation
FTRs	Financial Transmission Rights are financial instruments that entitle the holder to receive payments related to costs incurred for congestion on the transmission grid.
GCR	A Gas Cost Recovery mechanism authorized by the MPSC that allows DTE Gas to recover through rates its natural gas costs.
GHGs	Greenhouse gases
Green Bonds	A financing option to fund projects that have a positive environmental impact based upon a specified set of criteria. The proceeds are required to be used for eligible green expenditures.
MDEQ	Michigan Department of Environmental Quality
MGP	Manufactured Gas Plant
MPSC	Michigan Public Service Commission
MTM	Mark-to-market
NAV	Net Asset Value
NEXUS	NEXUS Gas Transmission, LLC, a joint venture in which DTE Energy own a 50% partnership interest.
Non-utility	An entity that is not a public utility. Its conditions of service, prices of goods and services, and other operating related matters are not directly regulated by the MPSC.
NOV	Notice of Violation
NOX	Nitrogen Oxides
NRC	U.S. Nuclear Regulatory Commission
PG&E	Pacific Gas and Electric Corporation

1

DEFINITIONS

Production tax credits	Tax credits as authorized under Sections 45K and 45 of the Internal Revenue Code that are designed to stimulate investment in and development of alternate fuel sources. The amount of a production tax credit can vary each year as determined by the Internal Revenue Service.
PSCR	A Power Supply Cost Recovery mechanism authorized by the MPSC that allows DTE Electric to recover through rates its fuel, fuel-related, and purchased power costs.
RDM	A Revenue Decoupling Mechanism authorized by the MPSC that is designed to minimize the impact on revenues of changes in average customer usage.
REC	Renewable Energy Credit
REF	Reduced Emissions Fuel
Registrants	DTE Energy and DTE Electric
Retail access	Michigan legislation provided customers the option of access to alternative suppliers for electricity and natural gas.
RNG	Renewable Natural Gas
SEC	Securities and Exchange Commission
SGG	Stonewall Gas Gathering is a midstream natural gas asset located in West Virginia. DTE Energy purchased 55% of SGG in October 2016, and an additional 30% in May 2019, bringing its ownership to 85%. SGG is part of DTE Energy's Gas Storage and Pipelines segment.
SO2	Sulfur Dioxide
TCJA	Tax Cuts and Jobs Act of 2017
TCJA rate reduction liability	Due to the change in the corporate tax rate, from January 1, 2018 to June 30, 2018 for DTE Gas and from January 1, 2018 to July 31, 2018 for DTE Electric, the utilities reduced revenue and recorded an offsetting regulatory liability.
Topic 606	FASB issued ASU No. 2014-09, Revenue from Contracts with Customers, as amended
Topic 840	FASB issued ASC 840, Leases
Topic 842	FASB issued ASU No. 2016-02, Leases, as amended, which replaced Topic 840
TRM	A Transitional Reconciliation Mechanism authorized by the MPSC that allows DTE Electric to recover through rates the deferred net incremental revenue requirement associated with the transition of City of Detroit's Public Lighting Department customers to DTE Electric's distribution system.
USD	United States Dollar ($)
VIE	Variable Interest Entity

Units of Measurement
Bcf	Billion cubic feet of natural gas
BTU	British thermal unit, heat value (energy content) of fuel
MMBtu	One million BTU
MWh	Megawatt-hour of electricity

2

FILING FORMAT

This combined Form 10-Q is separately filed by DTE Energy and DTE Electric. Information in this combined Form 10-Q relating to each individual Registrant is filed by such Registrant on its own behalf. DTE Electric makes no representation regarding information relating to any other companies affiliated with DTE Energy other than its own subsidiaries. Neither DTE Energy, nor any of DTE Energy’s other subsidiaries (other than DTE Electric), has any obligation in respect of DTE Electric's debt securities, and holders of such debt securities should not consider the financial resources or results of operations of DTE Energy nor any of DTE Energy’s other subsidiaries (other than DTE Electric and its own subsidiaries (in relevant circumstances)) in making a decision with respect to DTE Electric's debt securities. Similarly, none of DTE Electric nor any other subsidiary of DTE Energy has any obligation in respect to debt securities of DTE Energy. This combined Form 10-Q should be read in its entirety. No one section of this combined Form 10-Q deals with all aspects of the subject matter of this combined Form 10-Q. This combined Form 10-Q should be read in conjunction with the Consolidated Financial Statements and Combined Notes to Consolidated Financial Statements and with Management's Discussion and Analysis included in the combined DTE Energy and DTE Electric 2018 Annual Report on Form 10-K.

FORWARD-LOOKING STATEMENTS

Certain information presented herein includes "forward-looking statements" within the meaning of the Private Securities Litigation Reform Act of 1995 with respect to the financial condition, results of operations, and businesses of the Registrants. Words such as "anticipate," "believe," "expect," "may," "could," "projected," "aspiration," "plans," and "goals" signify forward-looking statements. Forward-looking statements are not guarantees of future results and conditions, but rather are subject to numerous assumptions, risks, and uncertainties that may cause actual future results to be materially different from those contemplated, projected, estimated, or budgeted. Many factors may impact forward-looking statements of the Registrants including, but not limited to, the following:

• impact of regulation by the EPA, the FERC, the MPSC, the NRC, and for DTE Energy, the CFTC, as well as other applicable governmental proceedings and regulations, including any associated impact on rate structures;

• the amount and timing of cost recovery allowed as a result of regulatory proceedings, related appeals, or new legislation, including legislative amendments and retail access programs;

• economic conditions and population changes in the Registrants' geographic area resulting in changes in demand, customer conservation, and thefts of electricity and, for DTE Energy, natural gas;

• the operational failure of electric or gas distribution systems or infrastructure;

• impact of volatility of prices in the oil and gas markets on DTE Energy's gas storage and pipelines operations;

• impact of volatility in prices in the international steel markets on DTE Energy's power and industrial projects operations;

• the risk of a major safety incident;

• environmental issues, laws, regulations, and the increasing costs of remediation and compliance, including actual and potential new federal and state requirements;

• the cost of protecting assets against, or damage due to, cyber incidents and terrorism;

• health, safety, financial, environmental, and regulatory risks associated with ownership and operation of nuclear facilities;

• volatility in the short-term natural gas storage markets impacting third-party storage revenues related to DTE Energy;

• volatility in commodity markets, deviations in weather, and related risks impacting the results of DTE Energy's energy trading operations;

• changes in the cost and availability of coal and other raw materials, purchased power, and natural gas;

• advances in technology that produce power, store power, or reduce power consumption;

3

• changes in the financial condition of significant customers and strategic partners;

• the potential for losses on investments, including nuclear decommissioning and benefit plan assets and the related increases in future expense and contributions;

• access to capital markets and the results of other financing efforts which can be affected by credit agency ratings;

• instability in capital markets which could impact availability of short and long-term financing;

• the timing and extent of changes in interest rates;

• the level of borrowings;

• the potential for increased costs or delays in completion of significant capital projects;

• changes in, and application of, federal, state, and local tax laws and their interpretations, including the Internal Revenue Code, regulations, rulings, court proceedings, and audits;

• the effects of weather and other natural phenomena on operations and sales to customers, and purchases from suppliers;

• unplanned outages;

• employee relations and the impact of collective bargaining agreements;

• the availability, cost, coverage, and terms of insurance and stability of insurance providers;

• cost reduction efforts and the maximization of plant and distribution system performance;

• the effects of competition;

• changes in and application of accounting standards and financial reporting regulations;

• changes in federal or state laws and their interpretation with respect to regulation, energy policy, and other business issues;

• contract disputes, binding arbitration, litigation, and related appeals; and

• the risks discussed in the Registrants' public filings with the Securities and Exchange Commission.

New factors emerge from time to time. The Registrants cannot predict what factors may arise or how such factors may cause results to differ materially from those contained in any forward-looking statement. Any forward-looking statements speak only as of the date on which such statements are made. The Registrants undertake no obligation to update any forward-looking statement to reflect events or circumstances after the date on which such statement is made or to reflect the occurrence of unanticipated events.

4

Part I — Financial Information

Item 1. Financial Statements

DTE Energy Company

Consolidated Statements of Operations (Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions, except per share amounts)
Operating Revenues
Utility operations	$	1,417		$	1,514		$	3,281		$	3,254
Non-utility operations	1,471			1,645			3,121			3,658
	2,888			3,159			6,402			6,912
Operating Expenses
Fuel, purchased power, and gas — utility	360			434			942			987
Fuel, purchased power, and gas — non-utility	1,258			1,443			2,643			3,216
Operation and maintenance	560			583			1,151			1,117
Depreciation and amortization	305			272			601			553
Taxes other than income	92			97			210			208
Asset (gains) losses and impairments, net	13			1			13			(2		)
	2,588			2,830			5,560			6,079
Operating Income	300			329			842			833
Other (Income) and Deductions
Interest expense	154			135			306			270
Interest income	(3		)	(3		)	(7		)	(6		)
Non-operating retirement benefits, net	10			9			19			18
Other income	(73		)	(82		)	(161		)	(163		)
Other expenses	12			15			23			40
	100			74			180			159
Income Before Income Taxes	200			255			662			674
Income Tax Expense	21			19			75			87
Net Income	179			236			587			587
Less: Net Income (Loss) Attributable to Noncontrolling Interests	(3		)	2			4			(8		)
Net Income Attributable to DTE Energy Company	$	182		$	234		$	583		$	595
Basic Earnings per Common Share
Net Income Attributable to DTE Energy Company	$	0.99		$	1.29		$	3.19		$	3.29
Diluted Earnings per Common Share
Net Income Attributable to DTE Energy Company	$	0.99		$	1.29		$	3.18		$	3.29
Weighted Average Common Shares Outstanding
Basic	183			181			183			180
Diluted	184			181			183			180

See Combined Notes to Consolidated Financial Statements (Unaudited)

5

DTE Energy Company

Consolidated Statements of Comprehensive Income (Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Net Income	$	179		$	236		$	587		$	587
Other comprehensive income (loss), net of tax:
Benefit obligations, net of taxes of $1, $1, $2 and $2, respectively	3			3			7			5
Net unrealized losses on derivatives during the period, net of taxes of $(2), $—, $(3), and $—, respectively	(6		)	—			(9		)	—
Foreign currency translation	—			(1		)	1			(1		)
Other comprehensive income (loss)	(3		)	2			(1		)	4
Comprehensive income	176			238			586			591
Less: Comprehensive income (loss) attributable to noncontrolling interests	(3		)	2			4			(8		)
Comprehensive Income Attributable to DTE Energy Company	$	179		$	236		$	582		$	599

See Combined Notes to Consolidated Financial Statements (Unaudited)

6

DTE Energy Company

Consolidated Statements of Financial Position (Unaudited)

	June 30,			December 31,
	2019			2018
	(In millions)
ASSETS
Current Assets
Cash and cash equivalents	$	62		$	71
Restricted cash	—			5
Accounts receivable (less allowance for doubtful accounts of $91 for both periods)
Customer	1,436			1,789
Other	93			108
Inventories
Fuel and gas	334			406
Materials and supplies	431			405
Derivative assets	113			102
Regulatory assets	79			153
Other	178			221
	2,726			3,260
Investments
Nuclear decommissioning trust funds	1,561			1,378
Investments in equity method investees	1,758			1,771
Other	247			219
	3,566			3,368
Property
Property, plant, and equipment	32,834			31,810
Accumulated depreciation and amortization	(10,537		)	(10,160		)
	22,297			21,650
Other Assets
Goodwill	2,293			2,293
Regulatory assets	4,508			4,568
Intangible assets	837			849
Notes receivable	168			64
Derivative assets	46			31
Prepaid postretirement costs	83			45
Operating lease right-of-use assets	142			—
Other	185			160
	8,262			8,010
Total Assets	$	36,851		$	36,288

See Combined Notes to Consolidated Financial Statements (Unaudited)

7

DTE Energy Company

Consolidated Statements of Financial Position (Unaudited) — (Continued)

	June 30,			December 31,
	2019			2018
	(In millions, except shares)
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	1,051		$	1,329
Accrued interest	141			127
Dividends payable	346			172
Short-term borrowings	3			609
Current portion long-term debt, including finance leases	1,498			1,499
Derivative liabilities	94			67
Gas inventory equalization	45			—
Regulatory liabilities	37			126
Operating lease liabilities	34			—
Other	405			509
	3,654			4,438
Long-Term Debt (net of current portion)
Mortgage bonds, notes, and other	12,418			10,982
Junior subordinated debentures	1,146			1,145
Finance lease liabilities	5			7
	13,569			12,134
Other Liabilities
Deferred income taxes	2,063			1,975
Regulatory liabilities	2,880			2,922
Asset retirement obligations	2,531			2,469
Unamortized investment tax credit	136			138
Derivative liabilities	68			89
Accrued pension liability	715			837
Nuclear decommissioning	231			205
Operating lease liabilities	102			—
Other	333			364
	9,059			8,999
Commitments and Contingencies (Notes 5 and 12)
Equity
Common stock (No par value, 400,000,000 shares authorized, and 183,301,732 and 181,925,281 shares issued and outstanding at June 30, 2019 and December 31, 2018, respectively)	4,344			4,245
Retained earnings	6,198			6,112
Accumulated other comprehensive loss	(146		)	(120		)
Total DTE Energy Company Equity	10,396			10,237
Noncontrolling interests	173			480
Total Equity	10,569			10,717
Total Liabilities and Equity	$	36,851		$	36,288

See Combined Notes to Consolidated Financial Statements (Unaudited)

8

DTE Energy Company

Consolidated Statements of Cash Flows (Unaudited)

	Six Months Ended June 30,
	2019			2018
	(In millions)
Operating Activities
Net Income	$	587		$	587
Adjustments to reconcile Net Income to Net cash from operating activities:
Depreciation and amortization	601			553
Nuclear fuel amortization	30			25
Allowance for equity funds used during construction	(13		)	(13		)
Deferred income taxes	80			80
Equity earnings of equity method investees	(43		)	(53		)
Dividends from equity method investees	89			34
Asset (gains) losses and impairments, net	13			—
Changes in assets and liabilities:
Accounts receivable, net	369			20
Inventories	46			104
Prepaid postretirement benefit costs	(38		)	(9		)
Accounts payable	(247		)	(34		)
Gas inventory equalization	45			37
Accrued pension liability	(122		)	(197		)
Accrued postretirement liability	—			(61		)
Derivative assets and liabilities	(20		)	(8		)
Regulatory assets and liabilities	142			230
Other current and noncurrent assets and liabilities	(152		)	138
Net cash from operating activities	1,367			1,433
Investing Activities
Plant and equipment expenditures — utility	(1,294		)	(1,027		)
Plant and equipment expenditures — non-utility	(102		)	(130		)
Proceeds from sale of nuclear decommissioning trust fund assets	396			616
Investment in nuclear decommissioning trust funds	(399		)	(613		)
Distributions from equity method investees	5			5
Contributions to equity method investees	(38		)	(233		)
Notes receivable	(62		)	5
Other	(20		)	(3		)
Net cash used for investing activities	(1,514		)	(1,380		)
Financing Activities
Issuance of long-term debt, net of issuance costs	1,438			520
Redemption of long-term debt	—			(102		)
Short-term borrowings, net	(606		)	(147		)
Issuance of common stock	—			6
Dividends paid on common stock	(345		)	(309		)
Contributions from noncontrolling interests, principally REF entities	17			22
Distributions to noncontrolling interests	(31		)	(17		)
Purchases of noncontrolling interest, principally SGG	(300		)	—
Other	(40		)	(29		)
Net cash from (used for) financing activities	133			(56		)
Net Decrease in Cash, Cash Equivalents, and Restricted Cash	(14		)	(3		)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	76			89
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	62		$	86
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	$	270		$	216

See Combined Notes to Consolidated Financial Statements (Unaudited)

9

DTE Energy Company

Consolidated Statements of Changes in Equity (Unaudited)

					Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Noncontrolling Interests
	Common Stock
	Shares	Amount												Total
	(Dollars in millions, shares in thousands)
Balance, December 31, 2018	181,925	$	4,245		$	6,112		$	(120	)	$	480		$	10,717
Implementation of ASU 2018-02	—	—			25			(25		)	—			—
Net Income	—	—			401			—			7			408
Dividends declared on common stock ($0.945 per Common Share)	—	—			(173		)	—			—			(173		)
Contribution of common stock to pension plan	815	100			—			—			—			100
Other comprehensive income, net of tax	—	—			—			2			—			2
Stock-based compensation, net distributions to noncontrolling interests, and other	472	(21		)	(1		)	—			(12		)	(34		)
Balance, March 31, 2019	183,212	$	4,324		$	6,364		$	(143	)	$	475		$	11,020
Net Income (Loss)	—	—			182			—			(3		)	179
Dividends declared on common stock ($1.89 per Common Share)	—	—			(347		)	—			—			(347		)
Other comprehensive loss, net of tax	—	—			—			(3		)	—			(3		)
Purchase of noncontrolling interests, principally SGG	—	(3		)	—			—			(297		)	(300		)
Stock-based compensation, net distributions to noncontrolling interests, and other	90	23			(1		)	—			(2		)	20
Balance, June 30, 2019	183,302	$	4,344		$	6,198		$	(146	)	$	173		$	10,569

See Combined Notes to Consolidated Financial Statements (Unaudited)

10

DTE Energy Company

Consolidated Statements of Changes in Equity (Unaudited) — (Continued)

					Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Noncontrolling Interests
	Common Stock
	Shares	Amount												Total
	(Dollars in millions, shares in thousands)
Balance, December 31, 2017	179,387	$	3,989		$	5,643		$	(120	)	$	478		$	9,990
Implementation of ASU 2016-01	—	—			5			(5		)	—			—
Net Income (Loss)	—	—			361			—			(10		)	351
Dividends declared on common stock ($0.88 per Common Share)	—	—			(160		)	—			—			(160		)
Contribution of common stock to pension plan	1,751	175			—			—			—			175
Other comprehensive income, net of tax	—	—			—			2			—			2
Stock-based compensation, net contributions from noncontrolling interests, and other	345	(1		)	(1		)	—			7			5
Balance, March 31, 2018	181,483	$	4,163		$	5,848		$	(123	)	$	475		$	10,363
Net Income (Loss)	—	—			234			—			2			236
Dividends declared on common stock ($1.77 per Common Share)	—	—			(321		)	—			—			(321		)
Issuance of common stock	160	16			—			—			—			16
Other comprehensive income, net of tax	—	—			—			2			—			2
Stock-based compensation, net distributions to noncontrolling interests, and other	130	26			(1		)	—			(3		)	22
Balance, June 30, 2018	181,773	$	4,205		$	5,760		$	(121	)	$	474		$	10,318

See Combined Notes to Consolidated Financial Statements (Unaudited)

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12

DTE Electric Company

Consolidated Statements of Operations (Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Operating Revenues — Utility operations	$	1,190		$	1,276		$	2,425		$	2,481
Operating Expenses
Fuel and purchased power — utility	322			386			668			725
Operation and maintenance	334			345			692			665
Depreciation and amortization	229			202			450			414
Taxes other than income	69			74			153			155
Asset (gains) losses and impairments, net	13			—			13			—
	967			1,007			1,976			1,959
Operating Income	223			269			449			522
Other (Income) and Deductions
Interest expense	78			69			154			137
Interest income	—			—			(1		)	—
Other income	(25		)	(22		)	(58		)	(49		)
Other expenses	12			15			20			40
	65			62			115			128
Income Before Income Taxes	158			207			334			394
Income Tax Expense	25			44			54			91
Net Income	$	133		$	163		$	280		$	303

See Combined Notes to Consolidated Financial Statements (Unaudited)

13

DTE Electric Company

Consolidated Statements of Comprehensive Income (Unaudited)

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions)
Net Income	$	133	$	163	$	280	$	303
Other comprehensive income	—		—		—		—
Comprehensive Income	$	133	$	163	$	280	$	303

See Combined Notes to Consolidated Financial Statements (Unaudited)

14

DTE Electric Company

Consolidated Statements of Financial Position (Unaudited)

	June 30,			December 31,
	2019			2018
	(In millions)
ASSETS
Current Assets
Cash and cash equivalents	$	9		$	18
Accounts receivable (less allowance for doubtful accounts of $47 and $53, respectively)
Customer	715			750
Affiliates	5			11
Other	42			54
Inventories
Fuel	179			171
Materials and supplies	283			279
Regulatory assets	78			148
Other	89			89
	1,400			1,520
Investments
Nuclear decommissioning trust funds	1,561			1,378
Other	36			34
	1,597			1,412
Property
Property, plant, and equipment	23,537			22,747
Accumulated depreciation and amortization	(7,574		)	(7,310		)
	15,963			15,437
Other Assets
Regulatory assets	3,787			3,829
Intangible assets	22			21
Prepaid postretirement costs — affiliates	189			189
Operating lease right-of-use assets	67			—
Other	152			121
	4,217			4,160
Total Assets	$	23,177		$	22,529

See Combined Notes to Consolidated Financial Statements (Unaudited)

15

DTE Electric Company

Consolidated Statements of Financial Position (Unaudited) — (Continued)

	June 30,		December 31,
	2019		2018
	(In millions, except shares)
LIABILITIES AND SHAREHOLDER’S EQUITY
Current Liabilities
Accounts payable
Affiliates	$	56	$	71
Other	421		441
Accrued interest	84		74
Current portion long-term debt, including finance leases	3		4
Regulatory liabilities	28		98
Short-term borrowings
Affiliates	295		101
Other	—		149
Operating lease liabilities	13		—
Other	138		139
	1,038		1,077
Long-Term Debt (net of current portion)
Mortgage bonds, notes, and other	7,178		6,538
Finance lease liabilities	5		7
	7,183		6,545
Other Liabilities
Deferred income taxes	2,294		2,246
Regulatory liabilities	2,140		2,171
Asset retirement obligations	2,329		2,271
Unamortized investment tax credit	135		137
Nuclear decommissioning	231		205
Accrued pension liability — affiliates	613		718
Accrued postretirement liability — affiliates	254		278
Operating lease liabilities	48		—
Other	86		88
	8,130		8,114
Commitments and Contingencies (Notes 5 and 12)
Shareholder’s Equity
Common stock ($10 par value, 400,000,000 shares authorized, and 138,632,324 shares issued and outstanding for both periods)	4,631		4,631
Retained earnings	2,195		2,162
Total Shareholder’s Equity	6,826		6,793
Total Liabilities and Shareholder’s Equity	$	23,177	$	22,529

See Combined Notes to Consolidated Financial Statements (Unaudited)

16

DTE Electric Company

Consolidated Statements of Cash Flows (Unaudited)

	Six Months Ended June 30,
	2019			2018
	(In millions)
Operating Activities
Net Income	$	280		$	303
Adjustments to reconcile Net Income to Net cash from operating activities:
Depreciation and amortization	450			414
Nuclear fuel amortization	30			25
Allowance for equity funds used during construction	(12		)	(9		)
Deferred income taxes	38			91
Asset (gains) losses and impairments, net	13			—
Changes in assets and liabilities:
Accounts receivable, net	53			(86		)
Inventories	(12		)	24
Accounts payable	(13		)	(2		)
Accrued pension liability — affiliates	(105		)	(182		)
Accrued postretirement liability — affiliates	(24		)	(47		)
Regulatory assets and liabilities	137			158
Other current and noncurrent assets and liabilities	(169		)	(4		)
Net cash from operating activities	666			685
Investing Activities
Plant and equipment expenditures	(1,073		)	(825		)
Notes receivable, including affiliates	(5		)	—
Proceeds from sale of nuclear decommissioning trust fund assets	396			616
Investment in nuclear decommissioning trust funds	(399		)	(613		)
Other	(19		)	(4		)
Net cash used for investing activities	(1,100		)	(826		)
Financing Activities
Issuance of long-term debt, net of issuance costs	643			520
Short-term borrowings, net — affiliate	194			(41		)
Short-term borrowings, net — other	(149		)	(108		)
Dividends paid on common stock	(247		)	(230		)
Other	(16		)	(7		)
Net cash from financing activities	425			134
Net Decrease in Cash and Cash Equivalents	(9		)	(7		)
Cash and Cash Equivalents at Beginning of Period	18			15
Cash and Cash Equivalents at End of Period	$	9		$	8
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	$	159		$	117

See Combined Notes to Consolidated Financial Statements (Unaudited)

17

DTE Electric Company

Consolidated Statements of Changes in Shareholder's Equity (Unaudited)

				Additional Paid-in Capital		Retained Earnings
	Common Stock
	Shares	Amount							Total
	(Dollars in millions, shares in thousands)
Balance, December 31, 2018	138,632	$	1,386	$	3,245	$	2,162		$	6,793
Net Income	—	—		—		147			147
Dividends declared on common stock	—	—		—		(124		)	(124		)
Balance, March 31, 2019	138,632	1,386		3,245		2,185			6,816
Net Income	—	—		—		133			133
Dividends declared on common stock	—	—		—		(123		)	(123		)
Balance, June 30, 2019	138,632	$	1,386	$	3,245	$	2,195		$	6,826

				Additional Paid-in Capital		Retained Earnings			Accumulated Other Comprehensive Income
	Common Stock
	Shares	Amount										Total
	(Dollars in millions, shares in thousands)
Balance, December 31, 2017	138,632	$	1,386	$	2,920	$	1,956		$	3		$	6,265
Implementation of ASU 2016-01	—	—		—		3			(3		)	—
Net Income	—	—		—		140			—			140
Dividends declared on common stock	—	—		—		(115		)	—			(115		)
Balance, March 31, 2018	138,632	1,386		2,920		1,984			—			6,290
Net Income	—	—		—		163			—			163
Dividends declared on common stock	—	—		—		(115		)	—			(115		)
Balance, June 30, 2018	138,632	$	1,386	$	2,920	$	2,032		$	—		$	6,338

See Combined Notes to Consolidated Financial Statements (Unaudited)

18

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited)

Index of Combined Notes to Consolidated Financial Statements (Unaudited)

The Combined Notes to Consolidated Financial Statements (Unaudited) 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	Revenue	DTE Energy and DTE Electric
Note 5	Regulatory Matters	DTE Energy and DTE Electric
Note 6	Earnings per Share	DTE Energy
Note 7	Fair Value	DTE Energy and DTE Electric
Note 8	Financial and Other Derivative Instruments	DTE Energy and DTE Electric
Note 9	Long-Term Debt	DTE Energy and DTE Electric
Note 10	Short-Term Credit Arrangements and Borrowings	DTE Energy and DTE Electric
Note 11	Leases	DTE Energy and DTE Electric
Note 12	Commitments and Contingencies	DTE Energy and DTE Electric
Note 13	Retirement Benefits and Trusteed Assets	DTE Energy and DTE Electric
Note 14	Segment and Related Information	DTE Energy

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 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 MDEQ, and for DTE Energy, the CFTC.

Basis of Presentation

The Consolidated Financial Statements should be read in conjunction with the Combined Notes to Consolidated Financial Statements included in the combined DTE Energy and DTE Electric 2018 Annual Report on Form 10-K.

The accompanying Consolidated Financial Statements of the Registrants are prepared using accounting principles generally accepted in the United States of America. These accounting principles require management to use estimates and assumptions that impact reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results may differ from the Registrants' estimates.

The Consolidated Financial Statements are unaudited but, in the Registrants' opinions, include all adjustments necessary to present a fair statement of the results for the interim periods. All adjustments are of a normal recurring nature, except as otherwise disclosed in these Consolidated Financial Statements and Combined Notes to Consolidated Financial Statements. Financial results for this interim period are not necessarily indicative of results that may be expected for any other interim period or for the fiscal year ending December 31, 2019.

19

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

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 cost method is used. These Consolidated Financial Statements also reflect the Registrants' proportionate interests in certain jointly-owned utility plants. The Registrants eliminate all intercompany balances and transactions.

The Registrants evaluate whether an entity is a VIE whenever reconsideration events occur. The Registrants consolidate VIEs for which they are the primary beneficiary. If a Registrant is not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, a Registrant considers all relevant facts and circumstances, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. The Registrants perform ongoing reassessments of all VIEs to determine if the primary beneficiary status has changed.

Legal entities within DTE Energy's Power and Industrial Projects segment enter into long-term contractual arrangements with customers to supply energy-related products or services. The entities are generally designed to pass-through the commodity risk associated with these contracts to the customers, with DTE Energy retaining operational and customer default risk. These entities generally are VIEs and consolidated when DTE Energy is the primary beneficiary. In addition, DTE Energy has interests in certain VIEs through which control of all significant activities is shared with partners, and therefore are generally accounted for under the equity method.

DTE Energy currently owns an 85% interest in SGG, which owns and operates midstream natural gas assets. SGG has contracts through which certain construction risk is designed to pass-through to the customers, with DTE Energy retaining operational and customer default risk. SGG is a VIE with DTE Energy as the primary beneficiary.

The Registrants have variable interests in NEXUS, which include DTE Energy's 50% ownership interest and DTE Electric's transportation services contract. NEXUS is a joint venture which owns a 256-mile pipeline to transport Utica and Marcellus shale gas to Ohio, Michigan, and Ontario market centers. NEXUS 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 as, an operational business providing energy-related products. These entities are generally VIEs as a result of certain characteristics of the limited partnership voting rights. The ownership interests are accounted for under the equity method as the Registrants are not the primary beneficiaries.

DTE Energy has variable interests in VIEs through certain of its long-term purchase and sale contracts. DTE Electric has variable interests in VIEs through certain of its long-term purchase contracts. As of June 30, 2019, 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 June 30, 2019, the carrying amount of assets and liabilities in DTE Electric's Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase contracts are predominantly related to working capital accounts and generally represent the amounts owed by DTE Electric for the deliveries associated with the current billing cycle under the contracts. The Registrants have not provided any significant form of financial support associated with these long-term contracts. There is no significant potential exposure to loss as a result of DTE Energy's variable interests through these long-term purchase and sale contracts. In addition, there is no significant potential exposure to loss as a result of DTE Electric's variable interests through these long-term purchase contracts.

20

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

The maximum risk exposure for consolidated VIEs is reflected on the Registrants' Consolidated Statements of Financial Position and, for DTE Energy, in Note 12 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 12 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 June 30, 2019 and December 31, 2018. 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:

	June 30, 2019						December 31, 2018
	SGG(a)		Other		Total		SGG(a)		Other		Total
	(In millions)
ASSETS
Cash and cash equivalents	$	18	$	14	$	32	$	25	$	14	$	39
Restricted cash	—		—		—		—		5		5
Accounts receivable	10		38		48		9		37		46
Inventories	—		84		84		1		92		93
Property, plant, and equipment, net	400		40		440		395		46		441
Goodwill	25		—		25		25		—		25
Intangible assets	550		—		550		557		—		557
Other current and long-term assets	2		1		3		3		—		3
	$	1,005	$	177	$	1,182	$	1,015	$	194	$	1,209
LIABILITIES
Accounts payable and accrued current liabilities	$	5	$	25	$	30	$	3	$	31	$	34
Other current and long-term liabilities	9		9		18		9		10		19
	$	14	$	34	$	48	$	12	$	41	$	53

_____________________________________

(a)Amounts shown are 100% of SGG's assets and liabilities, of which DTE Energy owns 85% at June 30, 2019 and 55% at December 31, 2018.

Amounts for DTE Energy's non-consolidated VIEs are as follows:

	June 30, 2019		December 31, 2018
	(In millions)
Investments in equity method investees	$	1,402	$	1,425
Notes receivable	$	26	$	15
Future funding commitments	$	51	$	55

21

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

NOTE 2 — SIGNIFICANT ACCOUNTING POLICIES

Other Income

The following is a summary of DTE Energy's Other income:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions)
Income from REF entities	$	29	$	25	$	56	$	48
Equity earnings of equity method investees	20		32		43		53
Gains from equity securities	7		1		24		1
Contract services	6		12		14		32
Allowance for equity funds used during construction	6		6		13		13
Other	5		6		11		16
	$	73	$	82	$	161	$	163

The following is a summary of DTE Electric's Other income:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions)
Gains from equity securities allocated from DTE Energy	$	7	$	1	$	24	$	1
Contract services	8		13		16		33
Allowance for equity funds used during construction	6		4		12		9
Other	4		4		6		6
	$	25	$	22	$	58	$	49

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 three and six months ended June 30, 2019 and 2018, reclassifications out of Accumulated other comprehensive income (loss) not relating to the adoption of new accounting pronouncements for DTE Energy were not material.

22

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

Income Taxes

The 2019 estimated annual effective tax rates for DTE Energy and DTE Electric are 12% and 16%, respectively. These tax rates are affected by estimated annual permanent items, including AFUDC equity, production tax credits, and other flow-through items, as well as discrete items that may occur in any given period, but are not consistent from period to period.

The interim effective tax rate of the Registrants are as follows:

	Effective Tax Rate
	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
DTE Energy	11	%	7	%	11	%	13	%
DTE Electric	16	%	21	%	16	%	23	%

The 4% increase in DTE Energy's effective tax rate for the three months ended June 30, 2019 was primarily due to lower production tax credits of 7% in 2019, partially offset by the amortization of the TCJA regulatory liability of 3% in 2019. The 2% decrease in DTE Energy's effective tax rate for the six months ended June 30, 2019 was primarily due to the amortization of the TCJA regulatory liability of 3% in 2019 and the remeasurement of deferred taxes in 2018 of $21 million that impacted the effective tax rate by 3%. The decrease in the effective tax rate was partially offset by lower production tax credits of 4% in 2019.

The 5% and 7% decrease in DTE Electric's effective tax rate for the three and six months ended June 30, 2019, respectively, was primarily due to the amortization of the TCJA regulatory liability of 4% and higher production tax credits of 1% in 2019. The remeasurement of deferred taxes in 2018 of $8 million impacted the effective tax rate by 2% for the six months ended June 30, 2019.

DTE Energy's total amount of unrecognized tax benefits as of June 30, 2019 was $8 million, which if recognized, would favorably impact its effective tax rate. DTE Electric's total amount of unrecognized tax benefits as of June 30, 2019 was $10 million, which if recognized, would favorably impact its effective tax rate. The Registrants do not anticipate any material changes to the unrecognized tax benefits in the next twelve months.

DTE Electric had income tax receivables of $9 million with DTE Energy at June 30, 2019 and income tax receivables with DTE Energy of $8 million at December 31, 2018.

Unrecognized Compensation Costs

As of June 30, 2019, DTE Energy had $104 million of total unrecognized compensation cost related to non-vested stock incentive plan arrangements. That cost is expected to be recognized over a weighted-average period of 1.54 years.

Allocated Stock-Based Compensation

DTE Electric received an allocation of costs from DTE Energy associated with stock-based compensation of $11 million and $8 million for the three months ended June 30, 2019 and 2018, respectively, while such allocation was $24 million and $17 million for the six months ended June 30, 2019 and 2018, respectively.

Cash, Cash Equivalents, and Restricted Cash

Cash and cash equivalents include cash on hand, cash in banks, and temporary investments purchased with remaining maturities of three months or less. Restricted cash consists of funds held to satisfy requirements of certain debt and DTE Energy partnership operating agreements. Restricted cash designated for interest and principal payments within one year is classified as a Current Asset.

23

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

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-of-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 11 to the Consolidated Financial Statements, "Leases."

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 from 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 replace the 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 current generally accepted accounting principles. Entities will 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 ASU is effective for the Registrants beginning after December 15, 2019, and interim periods therein. 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.

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 ASU is effective for the Registrants for fiscal years beginning after December 15, 2019, and interim periods therein. Early adoption is permitted. 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 — Changes to the Disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. The amendments in this update modify the disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. The ASU is effective for the Registrants for fiscal years ending after December 15, 2020. Early adoption is permitted. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements.

24

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

In August 2018, the FASB issued ASU No. 2018-15, Intangibles — Goodwill and Other — Internal-Use Software (Subtopic 350-40): Customer's Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That is a Service Contract. The amendments in this update align the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software (and hosting arrangements that include an internal use software license). The ASU is effective for the Registrants for fiscal years beginning after December 15, 2019, and interim periods therein. Early adoption is permitted. The Registrants anticipate adopting the ASU on its effective date. The ASU may be applied using either a retrospective or prospective approach. The Registrants are currently evaluating the transition methods and assessing the impact of this standard on their Consolidated Financial Statements.

In October 2018, the FASB issued ASU No. 2018-17, Consolidation (Topic 810): Targeted Improvements to Related Party Guidance for Variable Interest Entities. The amendments in this update modify the requirements for determining whether a decision-making fee is a variable interest 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. Early adoption is permitted. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements.

25

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

NOTE 4 — REVENUE

Disaggregation of Revenue

The following is a summary of revenues disaggregated by segment for DTE Energy:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions)
Electric(a)
Residential	$	494	$	584	$	1,047	$	1,170
Commercial	423		446		843		875
Industrial	158		178		322		354
Other(b)	115		68		213		82
Total Electric operating revenues(c)	$	1,190	$	1,276	$	2,425	$	2,481
Gas
Gas sales	$	163	$	180	$	640	$	637
End User Transportation	42		49		122		134
Intermediate Transportation	15		11		41		29
Other(b)	23		15		85		5
Total Gas operating revenues(d)	$	243	$	255	$	888	$	805
Other segment operating revenues
Gas Storage and Pipelines(e)	$	121	$	122	$	237	$	241
Power and Industrial Projects(f)	$	402	$	538	$	790	$	1,105
Energy Trading(g)	$	1,113	$	1,164	$	2,414	$	2,662

_______________________________________

(a) Revenues under the Electric segment generally represent those of DTE Electric.

(b) Includes revenue adjustments related to various regulatory mechanisms.

(c) Includes $5 million and $4 million of other revenues outside the scope of Topic 606 for the three months ended June 30, 2019 and 2018, respectively, and $8 million and $9 million for the six months ended June 30, 2019 and 2018, respectively.

(d) Includes $1 million and $4 million under Alternative Revenue Programs for the three and six months ended June 30, 2018, respectively, and $2 million of other revenues for the three months ended June 30, 2019 and 2018 and $4 million for the six months ended June 30, 2019 and 2018, which are both outside the scope of Topic 606.

(e) Includes revenues outside the scope of Topic 606 primarily related to $2 million and $4 million of contracts accounted for as leases for the three and six months ended June 30, 2019, respectively.

(f) Includes revenues outside the scope of Topic 606 primarily related to $30 million and $28 million of contracts accounted for as leases for the three months ended June 30, 2019 and 2018, respectively, and $61 million and $56 million for the six months ended June 30, 2019 and 2018, respectively.

(g) Includes revenues outside the scope of Topic 606 primarily related to $879 million and $937 million of derivatives for the three months ended June 30, 2019 and 2018, respectively, and $1.8 billion and $2.1 billion of derivatives for the six months ended June 30, 2019 and 2018, respectively.

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	35
Revenue recognized that was included in the deferred revenue balance at the beginning of the period	(26		)
Ending Balance, June 30, 2019	$	83

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.

26

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

Deferred revenues include amounts associated with REC performance obligations under certain wholesale full requirements power contracts. Deferred revenues associated with RECs are recognized as revenue when control of the RECs has transferred.

Other performance obligations associated with deferred revenues include providing products and services related to customer prepayments. Deferred revenues associated with these products and services are recognized when control has transferred to the customer.

The following table represents deferred revenue amounts for DTE Energy that are expected to be recognized as revenue in future periods:

	DTE Energy
	(In millions)
2019	$	48
2020	5
2021	5
2022	7
2023	3
2024 and thereafter	15
	$	83

Transaction Price Allocated to the Remaining Performance Obligations

In accordance with optional exemptions available under Topic 606, the Registrants did not disclose the value of unsatisfied performance obligations for (1) contracts with an original expected length of one year or less, (2) with the exception of fixed consideration, contracts for which revenue is recognized at the amount to which the Registrants have the right to invoice for goods provided and services performed, and (3) contracts for which variable consideration relates entirely to an unsatisfied performance obligation.

Such contracts consist of varying types of performance obligations across the segments, including the supply and delivery of energy related products and services. Contracts with variable volumes and/or variable pricing, including those with pricing provisions tied to a consumer price or other index, have also been excluded as the related consideration under the contract is variable at inception of the contract. Contract lengths vary from cancelable 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)
2019	$	111	$	5
2020	305		—
2021	249		—
2022	191		—
2023	133		—
2024 and thereafter	645		—
	$	1,634	$	5

27

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

Other Matters

The following table represents expenses recognized for estimated uncollectible accounts receivable:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions)
DTE Energy	$	24	$	31	$	53	$	56
DTE Electric	$	14	$	17	$	30	$	31

NOTE 5 — REGULATORY MATTERS

2018 Electric Rate Case Filing

DTE Electric filed a rate case with the MPSC on July 6, 2018 requesting an increase in base rates of $328 million based on a projected twelve-month period ending April 30, 2020. The requested increase in base rates was primarily due to an increase in net plant resulting from infrastructure investments, depreciation expense, as requested in the 2016 DTE Electric Depreciation Case Filing, and reliability improvement projects. The rate filing also requested an increase in return on equity from 10.0% 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, the MPSC issued an order approving an annual revenue increase of $125 million for services rendered on or after May 9, 2019. The 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.

2019 Electric Rate Case Filing

DTE Electric filed a rate case with the MPSC on July 8, 2019 requesting an increase in base rates of $351 million based on a projected twelve-month period ending April 30, 2021. The requested increase in base rates is primarily due to an increase in net plant resulting from infrastructure and generation investments. The rate filing also requests an increase in return on equity from 10.0% to 10.5% and includes projected changes in sales and operating and maintenance expenses. A final MPSC order in this case is expected by May 2020.

2016 DTE Electric Depreciation Case Filing

DTE Electric filed a depreciation case with 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 to increase its composite depreciation rate from 3.06% to 3.72%. The new rates are effective for service rendered on or after May 9, 2019, per the final order in DTE Electric's 2018 rate case issued on May 2, 2019.

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, DTE Electric and DTE Gas filed information 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.

28

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

On February 22, 2018, the MPSC issued an order in this case requiring utilities, including DTE Electric and DTE Gas, to follow 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 and a final MPSC order in this case is expected by August 2019. DTE Electric proposed an amortization schedule for Calculation C in its general rate case filed July 6, 2018, which was approved by the MPSC in the May 2, 2019 rate order.

NOTE 6 — 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.

The following is a reconciliation of DTE Energy's basic and diluted income per share calculation:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions, except per share amounts)
Basic Earnings per Share
Net Income Attributable to DTE Energy Company	$	182	$	234	$	583	$	595
Less: Allocation of earnings to net restricted stock awards	—		—		1		1
Net income available to common shareholders — basic	$	182	$	234	$	582	$	594
Average number of common shares outstanding — basic	183		181		183		180
Basic Earnings per Common Share	$	0.99	$	1.29	$	3.19	$	3.29
Diluted Earnings per Share
Net Income Attributable to DTE Energy Company	$	182	$	234	$	583	$	595
Less: Allocation of earnings to net restricted stock awards	—		—		1		1
Net income available to common shareholders — diluted	$	182	$	234	$	582	$	594
Average number of common shares outstanding — basic	183		181		183		180
Incremental shares attributable to:
Average dilutive equity units, performance share awards, and stock options	1		—		—		—
Average number of common shares outstanding — diluted	184		181		183		180
Diluted Earnings per Common Share(a)	$	0.99	$	1.29	$	3.18	$	3.29

_______________________________________

(a) The 2016 Equity Units excluded from the calculation of diluted EPS were approximately 6.6 million for the three and six months ended June 30, 2018 as the dilutive stock price threshold was not met.

29

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

NOTE 7 — 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 June 30, 2019 and December 31, 2018. The Registrants believe they use valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.

A fair value hierarchy has been established that prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. All assets and liabilities are required to be classified in their entirety based on the lowest level of input that is significant to the fair value measurement in its entirety. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. The Registrants classify fair value balances based on the fair value hierarchy defined as follows:

• Level 1 — Consists of unadjusted quoted prices in active markets for identical assets or liabilities that the Registrants have the ability to access as of the reporting date.

• Level 2 — Consists of inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.

• Level 3 — Consists of unobservable inputs for assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost-benefit constraints.

30

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

The following table presents assets and liabilities for DTE Energy measured and recorded at fair value on a recurring basis^(a):

	June 30, 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)	$	26		$	—		$	—		$	—	$	—		$	26		$	16		$	2		$	—		$	—	$	—		$	18
Nuclear decommissioning trusts
Equity securities	988			—			—			—		—			988			851			—			—			—		—			851
Fixed income securities	9			523			—			—		—			532			12			490			—			—		—			502
Private equity and other	—			—			—			32		—			32			—			—			—			20		—			20
Cash equivalents	9			—			—			—		—			9			5			—			—			—		—			5
Other investments(e)
Equity securities	128			—			—			—		—			128			110			—			—			—		—			110
Fixed income securities	75			—			—			—		—			75			69			—			—			—		—			69
Cash equivalents	4			—			—			—		—			4			4			—			—			—		—			4
Derivative assets
Commodity contracts
Natural gas	97			78			60			—		(170		)	65			199			87			63			—		(277		)	72
Electricity	—			239			81			—		(236		)	84			—			247			56			—		(252		)	51
Other	—			—			9			—		—			9			—			—			7			—		(1		)	6
Foreign currency exchange contracts	—			1			—			—		—			1			—			4			—			—		—			4
Total derivative assets	97			318			150			—		(406		)	159			199			338			126			—		(530		)	133
Total	$	1,336		$	841		$	150		$	32	$	(406	)	$	1,953		$	1,266		$	830		$	126		$	20	$	(530	)	$	1,712
Liabilities
Derivative liabilities
Commodity contracts
Natural gas	$	(119	)	$	(47	)	$	(70	)	$	—	$	170		$	(66	)	$	(197	)	$	(71	)	$	(112	)	$	—	$	272		$	(108	)
Electricity	—			(250		)	(71		)	—		240			(81		)	—			(227		)	(58		)	—		240			(45		)
Other	—			—			—			—		—			—			—			(1		)	—			—		1			—
Interest rate contracts	—			(15		)	—			—		—			(15		)	—			(3		)	—			—		—			(3		)
Total derivative liabilities	(119		)	(312		)	(141		)	—		410			(162		)	(197		)	(302		)	(170		)	—		513			(156		)
Total	$	(119	)	$	(312	)	$	(141	)	$	—	$	410		$	(162	)	$	(197	)	$	(302	)	$	(170	)	$	—	$	513		$	(156	)
Net Assets (Liabilities) at end of period	$	1,217		$	529		$	9		$	32	$	4		$	1,791		$	1,069		$	528		$	(44	)	$	20	$	(17	)	$	1,556
Assets
Current	$	122		$	249		$	104		$	—	$	(336	)	$	139		$	212		$	273		$	96		$	—	$	(461	)	$	120
Noncurrent	1,214			592			46			32		(70		)	1,814			1,054			557			30			20		(69		)	1,592
Total Assets	$	1,336		$	841		$	150		$	32	$	(406	)	$	1,953		$	1,266		$	830		$	126		$	20	$	(530	)	$	1,712
Liabilities
Current	$	(111	)	$	(251	)	$	(72	)	$	—	$	340		$	(94	)	$	(191	)	$	(251	)	$	(76	)	$	—	$	451		$	(67	)
Noncurrent	(8		)	(61		)	(69		)	—		70			(68		)	(6		)	(51		)	(94		)	—		62			(89		)
Total Liabilities	$	(119	)	$	(312	)	$	(141	)	$	—	$	410		$	(162	)	$	(197	)	$	(302	)	$	(170	)	$	—	$	513		$	(156	)
Net Assets (Liabilities) at end of period	$	1,217		$	529		$	9		$	32	$	4		$	1,791		$	1,069		$	528		$	(44	)	$	20	$	(17	)	$	1,556

_______________________________________

(a) See footnotes on following page.

31

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (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 June 30, 2019, the $26 million consisted of $15 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.

The following table presents assets for DTE Electric measured and recorded at fair value on a recurring basis as of:

	June 30, 2019										December 31, 2018
	Level 1		Level 2		Level 3		Other(a)		Net Balance		Level 1		Level 2		Level 3		Other(a)		Net Balance
	(In millions)
Assets
Cash equivalents(b)	$	11	$	—	$	—	$	—	$	11	$	8	$	2	$	—	$	—	$	10
Nuclear decommissioning trusts
Equity securities	988		—		—		—		988		851		—		—		—		851
Fixed income securities	9		523		—		—		532		12		490		—		—		502
Private equity and other	—		—		—		32		32		—		—		—		20		20
Cash equivalents	9		—		—		—		9		5		—		—		—		5
Other investments
Equity securities	11		—		—		—		11		10		—		—		—		10
Derivative assets — FTRs	—		—		9		—		9		—		—		6		—		6
Total	$	1,028	$	523	$	9	$	32	$	1,592	$	886	$	492	$	6	$	20	$	1,404
Assets
Current	$	11	$	—	$	9	$	—	$	20	$	8	$	2	$	6	$	—	$	16
Noncurrent	1,017		523		—		32		1,572		878		490		—		20		1,388
Total Assets	$	1,028	$	523	$	9	$	32	$	1,592	$	886	$	492	$	6	$	20	$	1,404

_______________________________________

(a) Amounts represent assets valued at NAV as a practical expedient for fair value.

(b) At June 30, 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.

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 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 assets such as private equity investments are classified as NAV assets. 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.

32

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (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.

The following table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for DTE Energy:

	Three Months Ended June 30, 2019												Three Months Ended June 30, 2018
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of March 31	$	(10	)	$	(25	)	$	2		$	(33	)	$	(10	)	$	(13	)	$	4		$	(19	)
Transfers into Level 3 from Level 2	1			—			—			1			—			—			—			—
Transfers from Level 3 into Level 2	—			—			—			—			—			—			—			—
Total gains (losses)
Included in earnings	(1		)	41			—			40			(28		)	18			1			(9		)
Recorded in Regulatory liabilities	—			—			9			9			—			—			15			15
Purchases, issuances, and settlements
Settlements	—			(6		)	(2		)	(8		)	13			(18		)	(5		)	(10		)
Net Assets (Liabilities) as of June 30	$	(10	)	$	10		$	9		$	9		$	(25	)	$	(13	)	$	15		$	(23	)
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 June 30, 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	)	$	38		$	(4	)	$	33		$	(20	)	$	4		$	(2	)	$	(18	)

33

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

	Six Months Ended June 30, 2019												Six Months Ended June 30, 2018
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of December 31	$	(49	)	$	(2	)	$	7		$	(44	)	$	(29	)	$	12		$	8		$	(9	)
Transfers into Level 3 from Level 2	—			—			—			—			—			—			—			—
Transfers from Level 3 into Level 2	—			—			—			—			(3		)	—			—			(3		)
Total gains (losses)
Included in earnings	31			10			(1		)	40			(98		)	4			1			(93		)
Recorded in Regulatory liabilities	—			—			7			7			—			—			15			15
Purchases, issuances, and settlements
Settlements	8			2			(4		)	6			105			(29		)	(9		)	67
Net Assets (Liabilities) as of June 30	$	(10	)	$	10		$	9		$	9		$	(25	)	$	(13	)	$	15		$	(23	)
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 June 30, 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	$	16		$	17		$	(5	)	$	28		$	(78	)	$	(6	)	$	(2	)	$	(86	)

The following table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for DTE Electric:

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Net Assets as of beginning of period	$	2		$	5		$	6		$	9
Change in fair value recorded in Regulatory liabilities	9			15			7			15
Purchases, issuances, and settlements
Settlements	(2		)	(5		)	(4		)	(9		)
Net Assets as of June 30	$	9		$	15		$	9		$	15
The amount of total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets held at June 30, 2019 and 2018 and reflected in DTE Electric's Consolidated Statements of Financial Position	$	9		$	15		$	9		$	15

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 three and six months ended June 30, 2019 and 2018, and there were no transfers from or into Level 3 for DTE Electric during the same periods.

The following tables present the unobservable inputs related to DTE Energy's Level 3 assets and liabilities:

	June 30, 2019
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	60	$	(70	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.33	)	—	$	5.95	/MMBtu	$	(0.08	)/MMBtu
Electricity	$	81	$	(71	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(13	)	—	$	7	/MWh	$	—

34

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

	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

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 inputs listed above would have 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 result 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:

	June 30, 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(a), excluding lessor finance leases	$	153	$	—	$	—	$	153	$	40	$	—	$	—	$	40
Dividends payable	$	346	$	346	$	—	$	—	$	172	$	172	$	—	$	—
Short-term borrowings	$	3	$	—	$	3	$	—	$	609	$	—	$	609	$	—
Notes payable — Other(b), excluding lessee finance leases	$	29	$	—	$	—	$	29	$	41	$	—	$	—	$	41
Long-term debt(c)	$	15,058	$	1,989	$	12,915	$	1,385	$	13,622	$	1,796	$	10,712	$	1,317

_______________________________________

(a) Current portion included in Current Assets — Other on DTE Energy's Consolidated Statements of Financial Position.

(b) Included in Current Liabilities — Other and Other Liabilities — Other on DTE Energy's Consolidated Statements of Financial Position.

(c) Includes debt due within one year, unamortized debt discounts, and issuance costs. Excludes finance lease obligations.

The following table presents the carrying amount and fair value of financial instruments for DTE Electric:

	June 30, 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	$	10	$	—	$	—	$	10	$	6	$	—	$	—	$	6
Short-term borrowings — affiliates	$	295	$	—	$	—	$	295	$	101	$	—	$	—	$	101
Short-term borrowings — other	$	—	$	—	$	—	$	—	$	149	$	—	$	149	$	—
Notes payable — Other(b), excluding lessee finance leases	$	23	$	—	$	—	$	23	$	21	$	—	$	—	$	21
Long-term debt(c)	$	7,178	$	—	$	7,749	$	167	$	6,538	$	—	$	6,552	$	161

_______________________________________

(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.

For further fair value information on financial and derivative instruments, see Note 8 to the Consolidated Financial Statements, "Financial and Other Derivative Instruments."

35

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (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.

The following table summarizes DTE Electric's fair value of the nuclear decommissioning trust fund assets:

	June 30, 2019		December 31, 2018
	(In millions)
Fermi 2	$	1,553	$	1,372
Fermi 1	3		3
Low-level radioactive waste	5		3
	$	1,561	$	1,378

The costs of securities sold are determined on the basis of specific identification. The following table sets forth DTE Electric's gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds:

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Realized gains	$	17		$	19		$	28		$	42
Realized losses	$	(10	)	$	(6	)	$	(17	)	$	(15	)
Proceeds from sale of securities	$	220		$	280		$	396		$	616

Realized gains and losses from the sale of securities and unrealized gains and losses incurred by the Fermi 2 trust are recorded to the Regulatory asset and Nuclear decommissioning liability. Realized gains and losses from the sale of securities and unrealized gains and losses on the low-level radioactive waste funds are recorded to the Nuclear decommissioning liability.

The following table sets forth DTE Electric's fair value and unrealized gains and losses for the nuclear decommissioning trust funds:

	June 30, 2019							December 31, 2018
	Fair Value		Unrealized Gains		Unrealized Losses			Fair Value		Unrealized Gains		Unrealized Losses
	(In millions)
Equity securities	$	988	$	335	$	(49	)	$	851	$	235	$	(79	)
Fixed income securities	532		21		(1		)	502		7		(8		)
Private equity and other	32		—		—			20		—		—
Cash equivalents	9		—		—			5		—		—
	$	1,561	$	356	$	(50	)	$	1,378	$	242	$	(87	)

The following table summarizes the fair value of the fixed income securities held in nuclear decommissioning trust funds by contractual maturity:

	June 30, 2019
	(In millions)
Due within one year	$	17
Due after one through five years	103
Due after five through ten years	110
Due after ten years	302
	$	532

36

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

Other Securities

At June 30, 2019 and December 31, 2018, the Registrants' securities, included in Other investments on the Consolidated Statements of Financial Position, were comprised primarily of money market and equity securities. For the three months ended June 30, 2019 and 2018, gains related to equity securities were $7 million and $1 million, respectively. For the six months ended June 30, 2019, gains related to equity securities were $24 million and losses related to equity securities held at June 30, 2018 were $1 million for the Registrants. Gains or losses related to the Rabbi Trust assets are allocated from DTE Energy to DTE Electric.

NOTE 8 — 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 portion of the derivative gain or loss that is effective in offsetting the change in the value of the underlying exposure is deferred in Accumulated other comprehensive income (loss) and later reclassified into earnings when the underlying transaction occurs. Gains or losses from the ineffective portion of cash flow hedges are recognized in earnings immediately. 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 coal forwards, futures, options, swaps, and foreign currency exchange contracts. Items not classified as derivatives include natural gas inventory, pipeline transportation contracts, renewable energy credits, and natural gas storage assets.

DTE Electric — DTE Electric generates, purchases, distributes, and sells electricity. DTE Electric uses forward contracts to manage changes in the price of electricity and fuel. Substantially all of these contracts meet the normal purchases and normal sales exception and are therefore accounted for under the accrual method. Other derivative contracts are MTM and recoverable through the PSCR mechanism when settled. This results in the deferral of unrealized gains and losses as Regulatory assets or liabilities until realized.

DTE Gas — DTE Gas purchases, stores, transports, distributes, and sells natural gas and sells storage and transportation capacity. DTE Gas has fixed-priced contracts for portions of its expected natural gas supply requirements through March 2022. 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.

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.

37

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

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 June 30, 2019 provision for credit losses, DTE Energy’s exposure to counterparty nonperformance is not expected to have a material adverse effect on DTE Energy's Consolidated Financial Statements.

Derivative Activities

DTE Energy manages its MTM risk on a portfolio basis based upon the delivery period of its contracts and the individual components of the risks within each contract. Accordingly, it records and manages the energy purchase and sale obligations under its contracts in separate components based on the commodity (e.g. electricity or natural gas), the product (e.g. electricity for delivery during peak or off-peak hours), the delivery location (e.g. by region), the risk profile (e.g. forward or option), and the delivery period (e.g. by month and year). The following describes the categories of activities represented by their operating characteristics and key risks:

• Asset Optimization — Represents derivative activity associated with assets owned and contracted by DTE Energy, including forward natural gas purchases and sales, natural gas transportation, and storage capacity. Changes in the value of derivatives in this category typically economically offset changes in the value of underlying non-derivative positions, which do not qualify for fair value accounting. The difference in accounting treatment of derivatives in this category and the underlying non-derivative positions can result in significant earnings volatility.

• Marketing and Origination — Represents derivative activity transacted by originating substantially hedged positions with wholesale energy marketers, producers, end-users, utilities, retail aggregators, and alternative energy suppliers.

• Fundamentals Based Trading — Represents derivative activity transacted with the intent of taking a view, capturing market price changes, or putting capital at risk. This activity is speculative in nature as opposed to hedging an existing exposure.

• Other — Includes derivative activity at DTE Electric related to FTRs. Changes in the value of derivative contracts at DTE Electric are recorded as Derivative assets or liabilities, with an offset to Regulatory assets or liabilities as the settlement value of these contracts will be included in the PSCR mechanism when realized.

38

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

The following table presents the fair value of derivative instruments for DTE Energy:

	June 30, 2019					December 31, 2018
	Derivative Assets		Derivative Liabilities			Derivative Assets		Derivative Liabilities
	(In millions)
Derivatives designated as hedging instruments
Interest rate contracts	$	—	$	(15	)	$	—	$	(3	)
Derivatives not designated as hedging instruments
Commodity contracts
Natural gas	$	235	$	(236	)	$	349	$	(380	)
Electricity	320		(321		)	303		(285		)
Other	9		—			7		(1		)
Foreign currency exchange contracts	1		—			4		—
Total derivatives not designated as hedging instruments	$	565	$	(557	)	$	663	$	(666	)
Current	$	449	$	(434	)	$	563	$	(518	)
Noncurrent	116		(138		)	100		(151		)
Total derivatives	$	565	$	(572	)	$	663	$	(669	)

The following table presents the fair value of derivative instruments for DTE Electric:

	June 30, 2019		December 31, 2018
	(In millions)
FTRs — Other current assets	$	9	$	6
Total derivatives not designated as hedging instruments	$	9	$	6

Certain of DTE Energy's derivative positions are subject to netting arrangements which provide for offsetting of asset and liability positions as well as related cash collateral. Such netting arrangements generally do not have restrictions. Under such netting arrangements, DTE Energy offsets the fair value of derivative instruments with cash collateral received or paid for those contracts executed with the same counterparty, which reduces DTE Energy's Total Assets and Liabilities. Cash collateral is allocated between the fair value of derivative instruments and customer accounts receivable and payable with the same counterparty on a pro-rata basis to the extent there is exposure. Any cash collateral remaining, after the exposure is netted to zero, is reflected in Accounts receivable and Accounts payable as collateral paid or received, respectively.

DTE Energy also provides and receives collateral in the form of letters of credit which can be offset against net Derivative assets and liabilities as well as Accounts receivable and payable. DTE Energy had issued letters of credit of $5 million and $4 million outstanding at June 30, 2019 and December 31, 2018, respectively, which could be used to offset net Derivative liabilities. Letters of credit received from third parties which could be used to offset net Derivative assets were $2 million and $8 million at June 30, 2019 and December 31, 2018, 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.

39

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

The following table presents net cash collateral offsetting arrangements for DTE Energy:

	June 30, 2019			December 31, 2018
	(In millions)
Cash collateral netted against Derivative assets	$	—		$	(17	)
Cash collateral netted against Derivative liabilities	4			—
Cash collateral recorded in Accounts receivable(a)	12			10
Cash collateral recorded in Accounts payable(a)	(3		)	(6		)
Total net cash collateral posted (received)	$	13		$	(13	)

_______________________________________

(a) Amounts are recorded net by counterparty.

The following table presents the netting offsets of Derivative assets and liabilities for DTE Energy:

	June 30, 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	$	235		$	(170	)	$	65		$	349		$	(277	)	$	72
Electricity	320			(236		)	84			303			(252		)	51
Other	9			—			9			7			(1		)	6
Foreign currency exchange contracts	1			—			1			4			—			4
Total derivative assets	$	565		$	(406	)	$	159		$	663		$	(530	)	$	133
Derivative liabilities
Commodity contracts
Natural gas	$	(236	)	$	170		$	(66	)	$	(380	)	$	272		$	(108	)
Electricity	(321		)	240			(81		)	(285		)	240			(45		)
Other	—			—			—			(1		)	1			—
Interest rate contracts	(15		)	—			(15		)	(3		)	—			(3		)
Total derivative liabilities	$	(572	)	$	410		$	(162	)	$	(669	)	$	513		$	(156	)

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:

	June 30, 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	$	449		$	116		$	(434	)	$	(138	)	$	563		$	100		$	(518	)	$	(151	)
Counterparty netting	(336		)	(70		)	336			70			(451		)	(62		)	451			62
Collateral adjustment	—			—			4			—			(10		)	(7		)	—			—
Total derivatives as reported	$	113		$	46		$	(94	)	$	(68	)	$	102		$	31		$	(67	)	$	(89	)

40

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (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 the Three Months Ended June 30,						Gain (Loss) Recognized in Income on Derivatives for the Six Months Ended June 30,
		2019			2018			2019			2018
		(In millions)
Commodity contracts
Natural gas	Operating Revenues — Non-utility operations	$	24		$	(48	)	$	9		$	(158	)
Natural gas	Fuel, purchased power, and gas — non-utility	(30		)	16			40			68
Electricity	Operating Revenues — Non-utility operations	16			28			(33		)	11
Other	Operating Revenues — Non-utility operations	(1		)	2			—			1
Foreign currency exchange contracts	Operating Revenues — Non-utility operations	(2		)	2			(3		)	4
Total		$	7		$	—		$	13		$	(74	)

Revenues and energy costs related to trading contracts are presented on a net basis in DTE Energy's Consolidated Statements of Operations. Commodity derivatives used for trading purposes, and financial non-trading commodity derivatives, are accounted for using the MTM method with unrealized and realized gains and losses recorded in Operating Revenues — Non-utility operations. Non-trading physical commodity sale and purchase derivative contracts are generally accounted for using the MTM method with unrealized and realized gains and losses for sales recorded in Operating Revenues — Non-utility operations and purchases recorded in Fuel, purchased power, and gas — non-utility.

The following represents the cumulative gross volume of DTE Energy's derivative contracts outstanding as of June 30, 2019:

Commodity	Number of Units
Natural gas (MMBtu)	1,986,388,951
Electricity (MWh)	33,786,455
Foreign currency exchange (CAD)	91,380,922

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, and coal) and the provisions and maturities of the underlying transactions. As of June 30, 2019, 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 $541 million.

As of June 30, 2019, DTE Energy had $493 million of derivatives in net liability positions, for which hard triggers exist. There is $4 million of collateral that has been posted against such liabilities, including cash and letters of credit. Associated derivative net asset positions for which contractual offset exists were $395 million. The net remaining amount of $94 million is derived from the $541 million noted above.

41

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

NOTE 9 — LONG-TERM DEBT

Debt Issuances

In 2019, 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
					$	1,450

_______________________________________

(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.

In June 2019, DTE Gas agreed to issue $140 million of 2.95% First Mortgage Bonds due October 1, 2029 and $140 million of 3.72% First Mortgage Bonds due October 1, 2049 to a group of institutional investors in a private placement transaction. The bond issuances are expected to occur in October 2019. Proceeds will be used for the repayment of short-term borrowings and for general corporate purposes.

NOTE 10 — 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 has other facilities to support letter of credit issuance.

The 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 capital 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 June 30, 2019, the total funded debt to total capitalization ratios for DTE Energy, DTE Electric, and DTE Gas were 0.57 to 1, 0.51 to 1, and 0.47 to 1, respectively, and were in compliance with this financial covenant.

42

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

The availability under the facilities in place at June 30, 2019 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 September 2019	70		—		—		70
Unsecured revolving credit facility, expiring April 2024	1,500		500		300		2,300
	1,720		500		300		2,520
Amounts outstanding at June 30, 2019
Commercial paper issuances	—		—		3		3
Letters of credit	179		—		—		179
	179		—		3		182
Net availability at June 30, 2019	$	1,541	$	500	$	297	$	2,338

DTE Energy has $9 million of other outstanding letters of credit which are used for various corporate purposes and are not included in the facilities described above.

In conjunction with maintaining certain exchange traded risk management positions, DTE Energy may be required to post collateral with its clearing agent. DTE Energy has a demand financing agreement for up to $100 million with its clearing agent. The 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 allows the right of setoff with posted collateral. At June 30, 2019, the capacity under this facility was $150 million. The amount outstanding under this agreement was $107 million and $93 million at June 30, 2019 and December 31, 2018, respectively, and was fully offset by the posted collateral.

NOTE 11 — LEASES

Disclosures related to the six months ended June 30, 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. Prior period disclosures under Topic 840 have been provided on an annual basis. As a result, the disclosures presented under Topic 842 and Topic 840 will not be fully comparable in specific disclosure requirements or time period.

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.

43

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

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.

The components of lease cost for DTE Energy were as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2019		2019
	(In millions)
Operating lease cost	$	10	$	21
Finance lease cost:
Amortization of right-of-use assets	2		3
Interest of lease liabilities	—		—
Total finance lease cost	2		3
Variable lease cost	1		6
Short-term lease cost	3		5
	$	16	$	35

The components of lease cost for DTE Electric were as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2019		2019
	(In millions)
Operating lease cost	$	4	$	8
Finance lease cost:
Amortization of right-of-use assets	2		3
Interest of lease liabilities	—		—
Total finance lease cost	2		3
Variable lease cost	—		—
Short-term lease cost	—		1
	$	6	$	12

44

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

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.

Other information related to leases for the six months ended June 30, 2019 were as follows:

	DTE Energy		DTE Electric
	2019		2019
	(In millions)
Supplemental Cash Flows Information
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows from finance leases	$	3	$	3
Operating cash flows from operating leases	$	19	$	7
Right-of-use assets obtained in exchange for lease obligations:
Operating leases	$	22	$	1
Weighted Average Remaining Lease Term
Operating leases	9.9 years		10.4 years
Finance leases	2.5 years		2.5 years
Weighted Average Discount Rate
Operating leases	3.8%		3.7%
Finance leases	3.1%		3.1%

The Registrants' future minimum lease payments under leases for remaining periods as of June 30, 2019 were as follows:

	DTE Energy					DTE Electric
	Operating Leases			Finance Leases		Operating Leases			Finance Leases
	(In millions)
2019	$	21		$	2	$	9		$	2
2020	32			4		12			4
2021	23			3		11			3
2022	16			—		7			—
2023	13			—		6			—
2024 and thereafter	61			—		30			—
Total future minimum lease payments	166			9		75			9
Imputed interest	(30		)	—		(14		)	—
	$	136		$	9	$	61		$	9

Finance leases reported on the Consolidated Statement of Financial Position were as follows:

	DTE Energy		DTE Electric
	June 30, 2019
	(In millions)
Right-of-use assets, within Property, plant, and equipment, net	$	9	$	9
Current lease liabilities, within Current Liabilities — Other	$	3	$	3

Topic 840 — The following disclosures are presented under Topic 840 for the year ended December 31, 2018.

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 and DTE Electric, respectively.

45

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

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

Lessor

Topic 842 — DTE Energy leases a portion of its pipeline system to the Vector Pipeline through a 20-year finance lease contract that expires in 2020, with renewal options extending for five years each. DTE Energy owns a 40% interest in the Vector Pipeline. In addition, DTE Energy has an energy services agreement that expires in 2026, of which a portion is accounted for as a finance lease.

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 3 to 24 years. Generally, the operating leases do not have renewal provisions or options to purchase the assets at the end of the lease. The operating leases generally do not have termination for convenience provisions. Termination may be allowed under specific circumstances stated in the lease contract, such as under an event of default.

Certain of the finance and operating leases have lease terms that extend to the end of the estimated economic life of the leased assets, thereby resulting in no residual value. Any remaining residual values under the finance and operating leases are expected to be recovered through rates, renewals or new lease contracts. Residual values have been determined using the estimated economic life of the leased assets. The finance and operating leases do not contain residual value guarantees.

Certain of the operating leases have both lease and non-lease components. The lease and non-lease components are allocated based upon estimated relative standalone selling prices.

A lease is deemed to exist when the Registrants have provided other parties with the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration received. The right to control is deemed to occur when the Registrants have provided other parties with the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.

DTE Energy’s lease income associated with operating leases was as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2019		2019
	(In millions)
Fixed payments	$	17	$	34
Variable payments	25		52
	$	42	$	86

46

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

DTE Energy’s minimum future rental revenues under operating leases for remaining periods as of June 30, 2019 were:

	DTE Energy
	(In millions)
2019	$	33
2020	66
2021	64
2022	22
2023	22
2024 and thereafter	216
	$	423

Depreciation expense associated with DTE Energy's property under operating leases was $5 million and $13 million for the three and six months ended June 30, 2019, respectively.

Property under operating leases for DTE Energy was as follows:

	DTE Energy
	June 30, 2019
	(In millions)
Gross property under operating leases	$	443
Accumulated amortization of property under operating leases	$	160

The components of DTE Energy’s net investment in finance leases for remaining periods were as follows:

	DTE Energy
	June 30, 2019
	(In millions)
2019	$	5
2020	9
2021	—
2022	—
2023	—
2024 and thereafter	1
Total minimum future lease receipts	15
Residual value of leased pipeline	40
Less unearned income	7
Net investment in finance lease	48
Less current portion	5
	$	43

Interest income recognized under finance leases was $1 million and $2 million for the three and six months ended June 30, 2019, respectively.

Topic 840 — DTE Energy leases various assets under operating leases for energy facilities and related equipment.

47

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

DTE Energy’s minimum future rental revenues under non-cancelable operating leases as of December 31, 2018 were:

	DTE Energy
	(In millions)
2019	$	66
2020	66
2021	64
2022	20
2023	20
2024 and thereafter	196
	$	432

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 expires in 2020, with renewal options extending for five years. DTE Energy owns a 40% interest in the Vector Pipeline. In addition, DTE Energy has two energy services agreements, for which a portion of are accounted for as capital leases. These agreements expire in 2019 and 2026.

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

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

48

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

NOTE 12 — 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 NO_X. The EPA and the State of Michigan have also issued emission reduction regulations relating to ozone, fine particulate, regional haze, mercury, and other air pollution. These rules have led to controls on fossil-fueled power plants to reduce SO₂, NO_X, mercury, and other emissions. Additional rulemakings may occur over the next few years which could require additional controls for SO₂, NO_X, and other hazardous air pollutants.

The EPA proposed revised air quality standards for ground level ozone in November 2014 and specifically requested comments on the form and level of the ozone standards. The standards were finalized in October 2015. The State of Michigan recommended to the EPA in October 2016 which areas of the state are not attaining the new standard. On April 30, 2018, the EPA finalized the State of Michigan's recommended marginal non-attainment designation for southeast Michigan. The State is required to develop and implement a plan to address the southeast Michigan ozone non-attainment area by 2021. The Registrants cannot predict the financial impact of the State's plan to address the ozone non-attainment area at this time.

In July 2009, the Registrants received a NOV/FOV from the EPA alleging, among other things, that five DTE Electric power plants violated New Source Performance standards, Prevention of Significant Deterioration requirements, and operating permit requirements under the Clean Air Act. In June 2010, the EPA issued a NOV/FOV making similar allegations related to a project and outage at Unit 2 of the Monroe Power Plant. In March 2013, DTE Energy received a supplemental NOV from the EPA relating to the July 2009 NOV/FOV. The supplemental NOV alleged additional violations relating to the New Source Review provisions under the Clean Air Act, among other things.

In August 2010, the U.S. Department of Justice, at the request of the EPA, brought a civil suit in the U.S. District Court for the Eastern District of Michigan against DTE Energy and DTE Electric, related to the June 2010 NOV/FOV and the outage work performed at Unit 2 of the Monroe Power Plant. In August 2011, the U.S. District Court judge granted DTE Energy's motion for summary judgment in the civil case, dismissing the case and entering judgment in favor of DTE Energy and DTE Electric. In October 2011, the EPA filed a Notice of Appeal to the Court of Appeals for the Sixth Circuit. In March 2013, the Court of Appeals remanded the case to the U.S. District Court for review of the procedural component of the New Source Review notification requirements. In September 2013, the EPA filed a motion seeking leave to amend their complaint regarding the June 2010 NOV/FOV adding additional claims related to outage work performed at the Trenton Channel and Belle River Power Plants as well as additional claims related to work performed at the Monroe Power Plant. In March 2014, the U.S. District Court judge again granted DTE Energy's motion for summary judgment dismissing the civil case related to Monroe Unit 2. In April 2014, the U.S. District Court judge granted motions filed by the EPA and the Sierra Club to amend their New Source Review complaint adding additional claims for Monroe Units 1, 2, and 3, Belle River Units 1 and 2, and Trenton Channel Unit 9. In October 2014, the EPA and the U.S. Department of Justice filed a notice of appeal of the U.S. District Court judge's dismissal of the Monroe Unit 2 case. The amended New Source Review claims were all stayed pending resolution of the appeal by the Court of Appeals for the Sixth Circuit. On January 10, 2017, a divided panel of the Court reversed the decision of the U.S. District Court. On May 8, 2017, DTE Energy and DTE Electric filed a motion to stay the mandate pending filing of a petition for writ of certiorari with the U.S. Supreme Court. The Sixth Circuit granted the motion on May 16, 2017, staying the claims in the U.S. District Court until the U.S. Supreme Court disposes of the case. DTE Electric and DTE Energy filed a petition for writ of certiorari on July 31, 2017. On December 11, 2017, the U.S. Supreme Court denied certiorari. As a result of the Supreme Court electing not to review the matter, the case was sent back to the U.S. District Court for further proceedings and on June 14, 2018 the case was stayed pending settlement negotiations. The proceedings at the District Court remain stayed while the parties discuss potential resolution of the matter.

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 two NOVs/FOVs, DTE Electric could be required to install additional pollution control equipment at some or all of the power plants in question, implement early retirement of facilities where control equipment is not economical, engage in supplemental environmental programs, and/or pay fines. The Registrants do not expect the outcome for this matter to have a material impact on their Consolidated Financial Statements.

49

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (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 Affordable Clean Energy (ACE) rule. These final rules do not impact DTE Energy's revised goal to reduce carbon emissions 32% by the early 2020s, 50% by 2030, and 80% by 2040 from the 2005 carbon emissions levels.

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 spent approximately $2.4 billion through 2018. DTE Electric does not anticipate additional capital expenditures for air pollution requirements through 2025.

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) permit application process to determine the type of technology needed to reduce impacts to fish. DTE Electric has initiated the process of completing the required studies. Final compliance for the installation of any required technology will be determined by the state on a case by case, site specific basis. DTE Electric is currently evaluating the compliance options and working with the State of Michigan on evaluating whether any controls are needed. These evaluations/studies may require modifications to some existing intake structures. It is not possible to quantify the impact of this rulemaking at this time.

Contaminated and Other Sites — Prior to the construction of major interstate natural gas pipelines, gas for heating and other uses was manufactured locally from processes involving coal, coke, or oil. The facilities, which produced gas, have been designated as MGP sites. DTE Electric conducted remedial investigations at contaminated sites, including three former MGP sites. 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 June 30, 2019 and December 31, 2018, DTE Electric had $8 million and $7 million, respectively, accrued for remediation. Any change in assumptions, such as remediation techniques, nature and extent of contamination, and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect DTE Electric’s financial position and cash flows. DTE Electric believes the likelihood of a material change to the accrued amount is remote based on current knowledge of the conditions at each site.

Coal Combustion Residuals and Effluent Limitations Guidelines — A final EPA rule for the disposal of coal combustion residuals, commonly known as coal ash, became effective in October 2015, and was revised in October 2016 and July 2018. Additionally, D.C. District Court Decisions on August 21, 2018 and March 19, 2019 may affect the timing of closure of coal ash impoundments that are not lined with an engineered liner system. In 2019, the EPA is expected to affirmatively undertake rulemaking to implement the D.C. District Court's decisions that will 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. The bill provides for a CCR program to be regulated in Michigan once approval is requested and received from the EPA.

50

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

DTE Electric owns and operates three permitted engineered coal ash storage facilities to dispose of coal ash from coal-fired power plants and operates a number of smaller impoundments at its power plants. CCR obligations vary based on plant life, but include the installation of monitoring wells, compliance with groundwater standards, and the closure of landfills and basins at the end of the useful life of the associated power plant or as a basin becomes inactive. Under the current CCR rules and uncertainty regarding the D.C. District Court decision, capital costs and timing associated with the building of new CCR facilities or retirement of existing CCR facilities are being evaluated.

In November 2015, the EPA finalized the ELG Rule for the steam electric power generating industry which requires additional controls to be installed between 2018 and 2023. Compliance schedules for individual facilities and individual waste streams are determined through issuance of new National Pollutant Discharge Elimination System (NPDES) permits by the State of Michigan. The State of Michigan has issued a NPDES permit for the Belle River Power Plant establishing a compliance deadline of December 31, 2021. No new permits that would require ELG compliance have been issued for other facilities, consequently no compliance timelines have been established.

On April 12, 2017, the EPA granted a petition for reconsideration of the ELG Rule. The EPA also signed an administrative stay of the ELG Rule’s compliance deadlines for fly ash transport water, bottom ash transport water, and flue gas desulfurization (FGD) wastewater, among others. On June 6, 2017, the EPA published in the Federal Register a proposed rule (Postponement Rule) to postpone certain applicable deadlines within the 2015 ELG rule. The Postponement Rule was published on September 18, 2017. The Postponement Rule nullified the administrative stay but also extended the earliest compliance deadlines for only FGD wastewater and bottom ash transport water until November 1, 2020 in order for the EPA to propose and finalize a new ruling. The ELG compliance requirements and final deadlines for bottom ash transport water and FGD wastewater, and total ELG related compliance costs will not be known until the EPA completes its reconsideration of the ELG Rule expected by the end of 2019.

DTE Gas

Contaminated and Other Sites — DTE Gas owns or previously owned, 14 former MGP sites. Investigations have revealed contamination related to the by-products of gas manufacturing at each site. Cleanup of seven of the MGP sites is complete, and the sites are closed. DTE Gas has also completed partial closure of seven 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 June 30, 2019 and December 31, 2018, DTE Gas had $27 million and $25 million, respectively, accrued for remediation. 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 environmental costs from having a material adverse impact on DTE Gas' results of operations.

Non-utility

DTE Energy's non-utility businesses are subject to a number of environmental laws and regulations dealing with the protection of the environment from various pollutants.

In March 2019, the EPA issued a finding of violation to EES Coke, the Michigan coke battery facility that is a wholly-owned subsidiary of DTE Energy, alleging that the 2008 and 2014 permits issued by the Michigan Department of Environment, Great Lakes, and Energy (formerly known as the Michigan Department of Environmental Quality) did not comply with the Clean Air Act. DTE Energy is currently evaluating the alleged violations and cannot predict the financial impact or outcome of this matter.

Other

In 2010, the EPA finalized a new one-hour SO₂ ambient air quality standard that requires states to submit plans and associated timelines for non-attainment areas that demonstrate attainment with the new SO₂ standard in phases. Phase 1 addresses non-attainment areas designated based on ambient monitoring data. Phase 2 addresses non-attainment areas with large sources of SO₂ and modeled concentrations exceeding the National Ambient Air Quality Standards for SO₂. Phase 3 addresses smaller sources of SO₂ with modeled or monitored exceedances of the new SO₂ standard.

51

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

Michigan's Phase 1 non-attainment area includes DTE Energy facilities in southwest Detroit and areas of Wayne County. Modeling runs by the MDEQ 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 process, DTE Energy has worked with the MDEQ 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 at this time.

Michigan's Phase 2 non-attainment area includes DTE Electric facilities in St. Clair County. State implementation plan (SIP) submittal and EPA approval describing 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 the end of 2019. DTE Energy is currently working with the MDEQ to develop the required SIP. DTE Energy is unable to determine the full impact of the SIP strategy.

Synthetic Fuel Guarantees

DTE Energy discontinued the operations of its synthetic fuel production facilities throughout the United States as of December 31, 2007. DTE Energy provided certain guarantees and indemnities in conjunction with the sales of interests in its synfuel facilities. The guarantees cover potential commercial, environmental, oil price, and tax-related obligations that will survive until 90 days after expiration of all applicable statutes of limitations. DTE Energy estimates that its maximum potential liability under these guarantees at June 30, 2019 was approximately $400 million. Payment under these guarantees are 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 June 30, 2019 was $476 million. Payments under these guarantees are considered remote.

NEXUS Guarantees

NEXUS entered into certain 15-year capacity agreements for the transportation of natural gas with DTE Gas and Texas Eastern Transmission, LP, an unrelated third party. Pursuant to the terms of those agreements, in December 2016, DTE Energy executed separate guarantee agreements with DTE Gas and Texas Eastern Transmission, LP, with maximum potential payments totaling $242 million and $377 million at June 30, 2019, 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.

NEXUS also entered into 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 June 30, 2019, 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.

In conjunction with the execution of an agreement under which NEXUS agreed to purchase Generation Pipeline, LLC, in January 2019, DTE Energy executed a guarantee agreement with the sellers of Generation Pipeline. The maximum potential payment, which represents a portion of the purchase price due and payable by NEXUS at the completion of the closing of the acquisition, totals $15 million at June 30, 2019. The guarantee terminates upon any of the following events: (i) all NEXUS obligations under the purchase agreement have been paid in full; (ii) the completion of the closing, or (iii) the termination of the purchase agreement by NEXUS in accordance with its terms.

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.

52

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

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 million at June 30, 2019. Payments under these guarantees are considered remote.

DTE Energy is 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 June 30, 2019, DTE Energy had $77 million of performance bonds outstanding. In the event that such bonds are called for nonperformance, DTE Energy would be obligated to reimburse the issuer of the performance bond. DTE Energy is 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

On July 5, 2019, DTE Energy, as lender, entered into a revolving term credit facility with Vector, as borrower, in the amount of C$70 million CAD. 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. As the agreement was entered into subsequent to June 30, 2019, there is no maximum potential liability under the line of credit at June 30, 2019. The funding of a loan under the terms of the credit facility is considered remote.

Labor Contracts

There are several bargaining units for DTE Energy subsidiaries' approximate 5,200 represented employees, including DTE Electric's approximate 2,800 represented employees. The majority of the represented employees are under contracts that expire in 2020 and 2021.

Purchase Commitments

Utility capital expenditures, expenditures for non-utility businesses, and contributions to equity method investees will be approximately $3.9 billion and $2.2 billion in 2019 for DTE Energy and DTE Electric, respectively. The Registrants have made certain commitments in connection with the estimated 2019 annual capital expenditures and contributions to equity method investees.

Bankruptcies

DTE Energy's Power and Industrial Projects segment holds ownership interests in, and operates, five generating plants that sell electric output from renewable sources under long-term power purchase agreements with PG&E. PG&E filed for Chapter 11 bankruptcy protection on January 29, 2019. As of June 30, 2019, PG&E's account is substantially current and outstanding accounts receivable from PG&E are not material. Therefore, DTE Energy determined no reserve was necessary.

As of June 30, 2019, the book value of long-lived assets used in producing electric output for sale to PG&E was approximately $103 million. The Power and Industrial Projects segment also has equity investments, including a note receivable, of approximately $73 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. There were no other new events occurring during the six months ended June 30, 2019, that would negatively impact the assumptions made within the December 31, 2018 impairment analysis. Therefore, no triggering events were identified. 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.

53

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

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 5 and 8 to the Consolidated Financial Statements, "Regulatory Matters" and "Financial and Other Derivative Instruments," respectively.

NOTE 13 — RETIREMENT BENEFITS AND TRUSTEED ASSETS

The following tables detail the components of net periodic benefit costs (credits) for pension benefits and other postretirement benefits for DTE Energy:

	Pension Benefits						Other Postretirement Benefits
	Three Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Service cost	$	21		$	25		$	6		$	7
Interest cost	54			50			17			17
Expected return on plan assets	(81		)	(83		)	(31		)	(35		)
Amortization of:
Net actuarial loss	34			45			3			2
Prior service credit	—			—			(2		)	—
Net periodic benefit cost (credit)	$	28		$	37		$	(7	)	$	(9	)

	Pension Benefits						Other Postretirement Benefits
	Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Service cost	$	42		$	50		$	11		$	14
Interest cost	109			100			35			34
Expected return on plan assets	(162		)	(165		)	(62		)	(71		)
Amortization of:
Net actuarial loss	66			89			6			5
Prior service credit	—			—			(4		)	—
Net periodic benefit cost (credit)	$	55		$	74		$	(14	)	$	(18	)

54

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (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 DTE Energy's subsidiary, DTE Energy Corporate Services, LLC. DTE Electric accounts for its participation in DTE Energy's qualified and nonqualified pension plans by applying multiemployer accounting. DTE Electric accounts for its participation in other postretirement benefit plans by applying multiple-employer accounting. Within multiemployer and multiple-employer plans, participants pool plan assets for investment purposes and to reduce the cost of plan administration. The primary difference between plan types is assets contributed in multiemployer plans can be used to provide benefits for all participating employers, while assets contributed within a multiple-employer plan are restricted for use by the contributing employer. As a result of multiemployer accounting treatment, capitalized costs associated with these plans are reflected in Property, plant, and equipment in DTE Electric's Consolidated Statements of Financial Position. The same capitalized costs are reflected as Regulatory assets and liabilities in DTE Energy's Consolidated Statements of Financial Position. In addition, the service cost and non-service cost components are presented in Operation and maintenance in DTE Electric's Consolidated Statements of Operations. The same non-service cost components are presented in Other (Income) and Deductions — Non-operating retirement benefits, net in DTE Energy's Consolidated Statements of Operations. Plan participants of all plans are solely DTE Energy and affiliate participants.

DTE Energy's subsidiaries are responsible for their share of qualified and nonqualified pension benefit costs. DTE Electric's allocated portion of pension benefit costs included in capital expenditures and operating and maintenance expense were $22 million and $30 million for the three months ended June 30, 2019 and 2018, respectively, and $45 million and $60 million for the six months ended June 30, 2019 and 2018, respectively. These amounts include recognized contractual termination benefit charges, curtailment gains, and settlement charges.

The following tables detail the components of net periodic benefit costs (credits) for other postretirement benefits for DTE Electric:

	Other Postretirement Benefits
	Three Months Ended June 30,
	2019			2018
	(In millions)
Service cost	$	4		$	5
Interest cost	14			14
Expected return on plan assets	(21		)	(25		)
Amortization of:
Net actuarial loss	1			2
Prior service credit	(3		)	—
Net periodic benefit credit	$	(5	)	$	(4	)

	Other Postretirement Benefits
	Six Months Ended June 30,
	2019			2018
	(In millions)
Service cost	$	8		$	10
Interest cost	27			27
Expected return on plan assets	(42		)	(49		)
Amortization of:
Net actuarial loss	2			4
Prior service credit	(4		)	—
Net periodic benefit credit	$	(9	)	$	(8	)

55

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (Continued)

Pension and Other Postretirement Contributions

During 2019, DTE Energy contributed the following amounts of DTE Energy common stock to the DTE Energy Company Affiliates Employee Benefit Plans Master Trust:

Date	Number of Shares	Price per Share	Amount
			(In millions)
March 5, 2019	814,597	$122.76	$	100

The above contribution was made on behalf of DTE Electric, for which DTE Electric paid DTE Energy cash consideration of $100 million in March 2019. At the discretion of management and depending upon financial market conditions, DTE Energy anticipates making up to an additional $50 million in contributions to the qualified pension plans in 2019. DTE Energy does not anticipate making any contributions to the other postretirement benefit plans in 2019.

NOTE 14 — SEGMENT AND RELATED INFORMATION

DTE Energy sets strategic goals, allocates resources, and evaluates performance based on the following structure:

Electric segment consists principally of DTE Electric, which is engaged in the generation, purchase, distribution, and sale of electricity to approximately 2.2 million residential, commercial, and industrial customers in southeastern Michigan.

Gas segment consists principally of DTE Gas, which is engaged in the purchase, storage, transportation, distribution, and sale of natural gas to approximately 1.3 million residential, commercial, and industrial customers throughout Michigan and the sale of storage and transportation capacity.

Gas Storage and Pipelines is primarily engaged in services related to the gathering, transportation, and storage of natural gas.

Power and Industrial Projects is comprised primarily of projects that deliver energy and utility-type products and services to industrial, commercial, and institutional customers, produce reduced emissions fuel, and sell electricity and pipeline-quality gas from renewable energy projects.

Energy Trading consists of energy marketing and trading operations.

Corporate and Other includes various holding company activities, holds certain non-utility debt, and holds energy-related investments.

The federal income tax provisions or benefits of DTE Energy’s subsidiaries are determined on an individual company basis and recognize the tax benefit of tax credits and net operating losses, if applicable. The state and local income tax provisions of the utility subsidiaries are determined on an individual company basis and recognize the tax benefit of various tax credits and net operating losses, if applicable. The subsidiaries record federal, state, and local income taxes payable to or receivable from DTE Energy based on the federal, state, and local tax provisions of each company.

56

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements (Unaudited) — (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:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions)
Electric	$	13	$	13	$	27	$	26
Gas	3		4		5		6
Gas Storage and Pipelines	3		14		6		22
Power and Industrial Projects	157		162		302		317
Energy Trading	5		5		12		12
Corporate and Other	—		—		1		1
	$	181	$	198	$	353	$	384

Financial data of DTE Energy's business segments follows:

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Operating Revenues — Utility operations
Electric	$	1,190		$	1,276		$	2,425		$	2,481
Gas	243			255			888			805
Operating Revenues — Non-utility operations
Gas Storage and Pipelines	121			122			237			241
Power and Industrial Projects	402			538			790			1,105
Energy Trading	1,113			1,164			2,414			2,662
Corporate and Other	—			2			1			2
Reconciliation and Eliminations	(181		)	(198		)	(353		)	(384		)
Total	$	2,888		$	3,159		$	6,402		$	6,912

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	133		$	163		$	280		$	303
Gas	8			14			159			118
Gas Storage and Pipelines	50			60			98			122
Power and Industrial Projects	29			43			55			88
Energy Trading	(6		)	(5		)	26			26
Corporate and Other	(32		)	(41		)	(35		)	(62		)
Net Income Attributable to DTE Energy Company	$	182		$	234		$	583		$	595

57

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following combined discussion is separately filed by DTE Energy and DTE Electric. However, DTE Electric does not make any representations as to information related solely to DTE Energy or the subsidiaries of DTE Energy other than itself.

EXECUTIVE OVERVIEW

DTE Energy is a diversified energy company and is the parent company of DTE Electric and DTE Gas, regulated electric and natural gas utilities engaged primarily in the business of providing electricity and natural gas sales, distribution, and storage services throughout Michigan. DTE Energy operates three energy-related non-utility segments with operations throughout the United States.

The following table summarizes DTE Energy's financial results:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions, except per share amounts)
Net Income Attributable to DTE Energy Company	$	182	$	234	$	583	$	595
Diluted Earnings per Common Share	$	0.99	$	1.29	$	3.18	$	3.29

The decrease in Net Income for the second quarter was primarily due to lower earnings in the Electric, Gas, Gas Storage and Pipelines, and Power and Industrial Projects segments, partially offset by higher earnings in the Corporate and Other segment. The decrease in Net Income for the six-month period was primarily due to lower earnings in the Electric, Gas Storage and Pipelines, and Power and Industrial Projects segments, partially offset by higher earnings in the Gas and Corporate and Other segments.

Please see detailed explanations of segment performance in the following "Results of Operations" section.

DTE Energy's strategy is to achieve long-term earnings growth, a strong balance sheet, and an attractive dividend yield.

DTE Energy's utilities are investing capital to improve customer reliability through investments in base infrastructure and new generation, and to comply with environmental requirements. DTE Energy expects that planned significant capital investments will result in earnings growth. DTE Energy is focused on executing plans to achieve operational excellence and customer satisfaction with a focus on customer affordability. DTE Energy operates in a constructive regulatory environment and has solid relationships with its regulators.

In March 2019, DTE Energy announced updated plans for accelerating its reduction of carbon emissions to 32% by the early 2020s, at least 50% by 2030, and 80% by 2040 from the 2005 carbon emissions levels. To achieve this reduction, DTE Energy will transition away from coal-powered sources and incorporate more renewable energy, energy waste reduction projects, demand response, and natural gas fueled generation. DTE Energy has already begun the transition in the way it produces power through the continued retirement of its aging coal-fired plants. Refer to the "Capital Investments" section below for further discussion.

DTE Energy has significant investments in non-utility businesses. DTE Energy employs disciplined investment criteria when assessing growth opportunities that leverage its assets, skills, and expertise, and provides diversity in earnings and geography. Specifically, DTE Energy invests in targeted energy markets with attractive competitive dynamics where meaningful scale is in alignment with its risk profile. DTE Energy expects growth opportunities in the Gas Storage and Pipelines and Power and Industrial Projects segments.

A key priority for DTE Energy is to maintain a strong balance sheet which facilitates access to capital markets and reasonably priced short-term and long-term financing. Near-term growth will be funded through internally generated cash flows and the issuance of debt and equity. DTE Energy has an enterprise risk management program that, among other things, is designed to monitor and manage exposure to earnings and cash flow volatility related to commodity price changes, interest rates, and counterparty credit risk.

58

CAPITAL INVESTMENTS

DTE Energy's utility businesses require significant capital investments to maintain and improve the electric generation and electric and natural gas distribution infrastructure and to comply with environmental regulations and renewable energy requirements.

DTE Electric's capital investments over the 2019-2023 period are estimated at $11.3 billion comprised of $4.0 billion for capital replacements and other projects, $4.6 billion for distribution infrastructure, and $2.7 billion for new generation. DTE Electric has retired five coal-fired generation units at the Trenton Channel, River Rouge, and St. Clair facilities and has announced plans to retire its remaining twelve coal-fired generating units. Six of these coal-fired generating units will be retired through 2022 at the Trenton Channel, River Rouge, and St. Clair facilities. The remaining coal-fired generating units at the Belle River and Monroe facilities are expected to be retired by 2040. The retired facilities will be replaced with renewables, energy waste reduction, demand response, and natural gas fueled generation.

DTE Gas' capital investments over the 2019-2023 period are estimated at $2.5 billion comprised of $1.2 billion for base infrastructure, and $1.3 billion for gas main renewal, meter move out, and pipeline integrity programs. DTE Gas plans to seek regulatory approval for capital expenditures consistent with ratemaking treatment.

DTE Energy's non-utility businesses' capital investments are primarily for expansion, growth, and ongoing maintenance. Gas Storage and Pipelines' capital investments over the 2019-2023 period are estimated at $4.0 billion to $5.0 billion for gathering and pipeline investments and expansions. Power and Industrial Projects' capital investments over the 2019-2023 period are estimated at $1.0 billion to $1.4 billion for industrial energy services and RNG projects.

ENVIRONMENTAL MATTERS

The Registrants are subject to extensive environmental regulation. Additional costs may result as the effects of various substances on the environment are studied and governmental regulations are developed and implemented. Actual costs to comply could vary substantially. The Registrants expect to continue recovering environmental costs related to utility operations through rates charged to customers, as authorized by the MPSC.

Increased costs for energy produced from traditional coal-based sources due to recent, pending, and future regulatory initiatives, could also increase the economic viability of energy produced from renewable, natural gas fueled generation, and/or nuclear sources, energy waste reduction initiatives, and the potential development of market-based trading of carbon instruments which could provide new business opportunities for DTE Energy's utility and non-utility segments. At the present time, it is not possible to quantify the financial impacts of these climate related regulatory initiatives on the Registrants or their customers.

For further discussion of environmental matters, see Note 12 to the Consolidated Financial Statements, "Commitments and Contingencies."

OUTLOOK

The next few years will be a period of rapid change for DTE Energy and for the energy industry. DTE Energy's strong utility base, combined with its integrated non-utility operations, position it well for long-term growth.

59

Looking forward, DTE Energy will focus on several areas that are expected to improve future performance:

• electric and gas customer satisfaction;

• electric distribution system reliability;

• new electric generation;

• gas distribution system renewal;

• rate competitiveness and affordability;

• regulatory stability and investment recovery for the electric and gas utilities;

• employee safety and engagement;

• cost structure optimization across all business segments;

• cash, capital, and liquidity to maintain or improve financial strength; and

• investments that integrate assets and leverage skills and expertise.

DTE Energy will continue to pursue opportunities to grow its businesses in a disciplined manner if it can secure opportunities that meet its strategic, financial, and risk criteria.

RESULTS OF OPERATIONS

Management’s Discussion and Analysis of Financial Condition and Results of Operations includes financial information prepared in accordance with GAAP, as well as the non-GAAP financial measures, Utility Margin and Non-utility Margin, discussed below, which DTE Energy uses as measures of its operational performance. Generally, a non-GAAP financial measure is a numerical measure of financial performance, financial position or cash flows that excludes (or includes) amounts that are included in (or excluded from) the most directly comparable measure calculated and presented in accordance with GAAP.

DTE Energy uses Utility Margin and Non-utility Margin, non-GAAP financial measures, to assess its performance by reportable segment.

Utility Margin includes electric and gas Operating Revenues net of Fuel, purchased power, and gas expenses. The utilities’ fuel, purchased power, and natural gas supply are passed through to customers, and therefore, result in changes to the utilities’ revenues that are comparable to changes in such expenses. As such, DTE Energy believes Utility Margin provides a meaningful basis for evaluating the utilities’ operations across periods, as it excludes the revenue effect of fluctuations in these expenses.

The Non-utility Margin relates to the Power and Industrial Projects and Energy Trading segments. For the Power and Industrial Projects segment, Non-utility Margin primarily includes Operating Revenues net of Fuel, purchased power, and gas expenses. Operating Revenues include sales of refined coal to third parties and the affiliated Electric utility, metallurgical coke and related by-products, petroleum coke, renewable natural gas, and electricity, as well as rental income and revenues from utility-type consulting, management, and operational services. For the Energy Trading segment, Non-utility Margin includes revenue and realized and unrealized gains and losses from physical and financial power and gas marketing, optimization, and trading activities, net of Purchased power and gas related to these activities. DTE Energy evaluates its operating performance of these non-utility businesses using the measure of Operating Revenues net of Fuel, purchased power, and gas expenses.

Utility Margin and Non-utility Margin are not measures calculated in accordance with GAAP and should be viewed as a supplement to and not a substitute for the results of operations presented in accordance with GAAP. Utility Margin and Non-utility Margin do not intend to represent operating income, the most comparable GAAP measure, as an indicator of operating performance and are not necessarily comparable to similarly titled measures reported by other companies.

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The following sections provide a detailed discussion of the operating performance and future outlook of DTE Energy's segments. Segment information, described below, includes intercompany revenues and expenses, and other income and deductions that are eliminated in the Consolidated Financial Statements.

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Net Income (Loss) Attributable to DTE Energy by Segment
Electric	$	133		$	163		$	280		$	303
Gas	8			14			159			118
Gas Storage and Pipelines	50			60			98			122
Power and Industrial Projects	29			43			55			88
Energy Trading	(6		)	(5		)	26			26
Corporate and Other	(32		)	(41		)	(35		)	(62		)
Net Income Attributable to DTE Energy Company	$	182		$	234		$	583		$	595

ELECTRIC

The Results of Operations discussion for DTE Electric is presented in a reduced disclosure format in accordance with General Instruction H(2) of Form 10-Q.

The Electric segment consists principally of DTE Electric. Electric results are discussed below:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions)
Operating Revenues — Utility operations	$	1,190	$	1,276	$	2,425	$	2,481
Fuel and purchased power — utility	322		386		668		725
Utility Margin	868		890		1,757		1,756
Operation and maintenance	330		337		682		649
Depreciation and amortization	229		202		450		414
Taxes other than income	69		74		153		155
Asset (gains) losses and impairments, net	13		—		13		—
Operating Income	227		277		459		538
Other (Income) and Deductions	69		70		125		144
Income Tax Expense	25		44		54		91
Net Income Attributable to DTE Energy Company	$	133	$	163	$	280	$	303

See DTE Electric's Consolidated Statements of Operations for a complete view of its results. For an explanation of differences between the Electric segment and DTE Electric's Consolidated Statements of Operations, refer to Note 13 to the Consolidated Financial Statements, "Retirement Benefits and Trusteed Assets."

Utility Margin decreased $22 million and increased $1 million in the three and six months ended June 30, 2019, respectively. Revenues associated with certain mechanisms and surcharges are offset by related expenses elsewhere in the Registrants' Consolidated Statements of Operations.

The following table details changes in various Utility Margin components relative to the comparable prior period:

	Three Months			Six Months
	(In millions)
Implementation of new rates	$	37		$	45
Base sales	(8		)	(4		)
Regulatory mechanism — TRM	(6		)	(8		)
Weather	(61		)	(53		)
Regulatory mechanisms and other	16			21
Increase (decrease) in Utility Margin	$	(22	)	$	1

61

	Three Months Ended June 30,		Six Months Ended June 30,
	2019	2018	2019	2018
	(In thousands of MWh)
DTE Electric Sales
Residential	3,209	3,682	6,897	7,359
Commercial	4,068	4,352	8,145	8,382
Industrial	2,498	2,648	4,958	5,252
Other	48	51	111	108
	9,823	10,733	20,111	21,101
Interconnection sales(a)	711	812	1,741	1,894
Total DTE Electric Sales	10,534	11,545	21,852	22,995
DTE Electric Deliveries
Retail and wholesale	9,823	10,733	20,111	21,101
Electric retail access, including self-generators(b)	1,114	1,215	2,234	2,357
Total DTE Electric Sales and Deliveries	10,937	11,948	22,345	23,458

______________________________

(a) Represents power that is not distributed by DTE Electric.

(b) Represents deliveries for self-generators that have purchased power from alternative energy suppliers to supplement their power requirements.

Operation and maintenance expense decreased $7 million and increased $33 million in the three and six months ended June 30, 2019, respectively. The decrease in the second quarter was primarily due to the deferral of previously accrued expenses for the new customer billing system approved in the 2018 rate order received on May 2, 2019 of $11 million. The increase in the six-month period was primarily due to increased distribution operations expense of $12 million, insurance proceeds from a 2016 fire at a generation facility received in 2018 of $8 million, an increase in energy waste reduction expense of $6 million, an increase in renewable energy expense of $4 million, and higher customer service expense of $8 million, partially offset by the deferral of previously accrued expenses for the new customer billing system approved in the 2018 rate order received on May 2, 2019 of $11 million.

Depreciation and amortization expense increased $27 million and $36 million in the three and six months ended June 30, 2019, respectively. The increase in the second quarter was primarily due to an increase of $32 million in depreciable base and the change in deprecation rates effective in May 2019, partially offset by a decrease of $5 million associated with the TRM. The increase in the six-month period was primarily due to an increase of $47 million in depreciable base and the change in deprecation rates effective in May 2019, partially offset by a decrease of $9 million associated with the TRM.

Asset (gains) losses and impairments, net increased $13 million for both the three and six months ended June 30, 2019. The increase was due to previously recorded capital expenditures of $13 million that were disallowed in the May 2, 2019 rate order.

Other (Income) and Deductions decreased $1 million and $19 million in the three and six months ended June 30, 2019, respectively. The decrease in the second quarter was primarily due to increased investment earnings of $6 million, lower non-operating retirement benefits of $3 million, increased AFUDC equity on increased plant base of $1 million, partially offset by increased debt expense of $9 million. The decrease in the six-month period was primarily due to increased investment earnings of $25 million, lower non-operating retirement benefits of $6 million, increased AFUDC equity on increased plant base of $3 million, partially offset by increased debt expense of $17 million.

Income Tax Expense decreased $19 million and $37 million in the three and six months ended June 30, 2019, respectively. The decrease in the second quarter was primarily due to lower earnings and amortization of the TCJA regulatory liability. The decrease in the six-month period was primarily due to lower earnings, amortization of the TCJA regulatory liability, and $8 million of true-up adjustments for the remeasurement of deferred tax assets and liabilities in 2018.

Outlook — DTE Electric will continue to move forward in its efforts to achieve operational excellence, sustain strong cash flows, and earn its authorized return on equity. DTE Electric expects that planned significant capital investments will result in earnings growth. DTE Electric will maintain a strong focus on customers by increasing reliability and satisfaction while keeping customer rate increases affordable. Looking forward, additional factors may impact earnings such as weather, the outcome of regulatory proceedings, benefit plan design changes, investment returns and changes in discount rate assumptions in benefit plans and health care costs, uncertainty of legislative or regulatory actions regarding climate change, and effects of energy waste reduction programs.

62

DTE Electric filed a rate case with the MPSC on July 8, 2019 requesting an increase in base rates of $351 million based on a projected twelve-month period ending April 30, 2021. The requested increase in base rates is primarily due to an increase in net plant resulting from infrastructure and generation investments. The rate filing also requests an increase in return on equity from 10.0% to 10.5% and includes projected changes in sales and operating and maintenance expenses. A final MPSC order in this case is expected by May 2020. Refer to Note 5 to the Consolidated Financial Statements, "Regulatory Matters" for additional information.

GAS

The Gas segment consists principally of DTE Gas. Gas results are discussed below:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions)
Operating Revenues — Utility operations	$	243	$	255	$	888	$	805
Cost of gas — utility	43		53		284		273
Utility Margin	200		202		604		532
Operation and maintenance	118		122		246		233
Depreciation and amortization	34		31		69		63
Taxes other than income	19		18		43		39
Operating Income	29		31		246		197
Other (Income) and Deductions	17		13		33		27
Income Tax Expense	4		4		54		52
Net Income Attributable to DTE Energy Company	$	8	$	14	$	159	$	118

Utility Margin decreased $2 million and increased $72 million in the three and six months ended June 30, 2019, respectively. Revenues associated with certain mechanisms and surcharges are offset by related expenses elsewhere in DTE Energy's Consolidated Statements of Operations.

The following table details changes in various Utility Margin components relative to the comparable prior period:

	Three Months			Six Months
	(In millions)
Implementation of new rates	$	6		$	29
Weather	(4		)	14
Midstream storage and transportation revenues	4			13
Regulatory mechanism — RDM	1			4
TCJA rate reduction liability	(12		)	2
Other regulatory mechanisms and other	3			10
Increase (decrease) in Utility Margin	$	(2	)	$	72

	Three Months Ended June 30,		Six Months Ended June 30,
	2019	2018	2019	2018
	(In Bcf)
Gas Markets
Gas sales	19	21	88	83
End-user transportation	38	45	96	104
	57	66	184	187
Intermediate transportation	106	62	233	134
Total Gas sales	163	128	417	321

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Operation and maintenance expense decreased $4 million and increased $13 million in the three and six months ended June 30, 2019, respectively. The decrease in the second quarter was primarily due to the deferral of previously accrued expenses for the new customer billing system of $6 million, partially offset by higher gas operations expense of $2 million. The increase in the six-month period was primarily due to higher gas operations expense of $10 million, one-time benefits expense reimbursement of $3 million in 2018, and an increase in energy waste reduction expense and other expense of $6 million, partially offset by the deferral of previously accrued expenses for the new customer billing system of $6 million.

Depreciation and amortization expense increased $3 million and $6 million in the three and six months ended June 30, 2019, respectively. The increase in both periods was primarily due to higher depreciable base.

Income Tax Expense increased $2 million in the six months ended June 30, 2019. The increase in the six-month period was primarily due to higher earnings, partially offset by $8 million of true-up adjustments for the remeasurement of deferred tax assets and liabilities in 2018.

Outlook — DTE Gas will continue to move forward in its efforts to achieve operational excellence, sustain strong cash flows, and earn its authorized return on equity. DTE Gas expects that planned significant infrastructure capital investments will result in earnings growth. Looking forward, additional factors may impact earnings such as weather, the outcome of regulatory proceedings, benefit plan design changes, and investment returns and changes in discount rate assumptions in benefit plans and health care costs. DTE Gas expects to continue its efforts to improve productivity and decrease costs while improving customer satisfaction with consideration of customer rate affordability.

DTE Gas filed its Calculation C case with the MPSC on November 16, 2018 to reduce the annual revenue requirement by $12 million related to the amortization of deferred tax remeasurement. Calculation C addresses all remaining issues relative to the enactment of the TCJA, which is primarily the remeasurement of deferred taxes and how the amounts deferred as Regulatory liabilities will flow to ratepayers. A final MPSC order in this case is expected by August 2019. Refer to Note 5 to the Consolidated Financial Statements, "Regulatory Matters" for additional information.

GAS STORAGE AND PIPELINES

The Gas Storage and Pipelines segment consists of the non-utility gas pipelines and storage businesses. Gas Storage and Pipelines results are discussed below:

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Operating Revenues — Non-utility operations	$	121		$	122		$	237		$	241
Cost of gas — Non-utility	1			9			1			13
Operation and maintenance	25			23			50			46
Depreciation and amortization	22			19			44			39
Taxes other than income	2			2			5			5
Asset (gains) losses and impairments, net	—			—			—			(2		)
Operating Income	71			69			137			140
Other (Income) and Deductions	(3		)	(16		)	(9		)	(33		)
Income Tax Expense	19			17			37			36
Net Income	55			68			109			137
Less: Net Income Attributable to Noncontrolling Interests	5			8			11			15
Net Income Attributable to DTE Energy Company	$	50		$	60		$	98		$	122

Operating Revenues — Non-utility operations decreased $1 million and $4 million in the three and six months ended June 30, 2019, respectively. The decrease in both periods was primarily due to lower physical sales of gas from AGS customers for resale to optimize available transportation capacity and lower storage revenue, partially offset by higher pipeline and gathering revenue.

Cost of gas — Non-utility decreased $8 million and $12 million in the three and six months ended June 30, 2019, respectively. The decrease in both periods was due to lower physical purchase of gas from AGS customers for resale to optimize available transportation capacity.

64

Other (Income) and Deductions decreased $13 million and $24 million in the three and six months ended June 30, 2019, respectively. The decrease in both periods was primarily due to decreased earnings from pipeline investments and higher interest expense.

Net Income Attributable to Noncontrolling Interests decreased $3 million and $4 million in the three and six months ended June 30, 2019, respectively. The decrease in both periods was primarily due to the May 2019 purchase of an additional 30% ownership interest in SGG.

Outlook — DTE Energy believes its long-term agreements with producers and the quality of the natural gas reserves in the Marcellus/Utica region soundly position the gathering systems for future revenues.

The NEXUS Pipeline provides a transportation path for Appalachian Basin shale gas, including Utica and Marcellus shale gas, directly to consuming markets in northern Ohio, southeastern Michigan, and Dawn Ontario. DTE Energy owns a 50% partnership interest in the NEXUS Pipeline.

On January 11, 2019, NEXUS signed an agreement to purchase Generation Pipeline, LLC, a public utility regulated by the Public Utilities Commission of Ohio. This 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 4 miles away from NEXUS. The transaction is expected to close in 2019 upon regulatory approvals.

AGS and SGG provide a platform for midstream growth and access to further investment opportunities in the Appalachian basin, an additional connection to the NEXUS Pipeline which should drive incremental volumes on the NEXUS Pipeline, and producer relationships that may lead to more partnering opportunities.

Gas Storage and Pipelines expects to maintain its steady growth by developing an asset portfolio with multiple growth platforms through investment in new projects and expansions. Gas Storage and Pipelines will continue to look for additional investment opportunities and other storage and pipeline projects at favorable prices.

POWER AND INDUSTRIAL PROJECTS

The Power and Industrial Projects segment 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. Power and Industrial Projects results are discussed below:

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Operating Revenues — Non-utility operations	$	402		$	538		$	790		$	1,105
Fuel, purchased power, and gas — non-utility	320			464			624			962
Non-utility Margin	82			74			166			143
Operation and maintenance	83			90			164			172
Depreciation and amortization	17			17			34			33
Taxes other than income	2			3			6			7
Operating Loss	(20		)	(36		)	(38		)	(69		)
Other (Income) and Deductions	(26		)	(23		)	(53		)	(41		)
Income Taxes
Expense (Benefit)	3			(2		)	6			(2		)
Production Tax Credits	(18		)	(48		)	(39		)	(91		)
	(15		)	(50		)	(33		)	(93		)
Net Income	21			37			48			65
Less: Net Loss Attributable to Noncontrolling Interests	(8		)	(6		)	(7		)	(23		)
Net Income Attributable to DTE Energy Company	$	29		$	43		$	55		$	88

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Operating Revenues — Non-utility operations decreased $136 million and $315 million in the three and six months ended June 30, 2019, respectively. The decrease in both periods was due to the following:

	Three Months			Six Months
	(In millions)
Higher demand and prices in the Steel business	$	—		$	8
Lower demand in the Steel business	(3		)	—
Lower revenue due to sale of membership interests in three projects and project terminations in the REF business	(135		)	(330		)
Other	2			7
	$	(136	)	$	(315	)

Non-utility Margin increased $8 million and $23 million in the three and six months ended June 30, 2019, respectively. The following table details changes in Non-utility margin relative to the comparable prior periods:

	Three Months		Six Months
	(In millions)
Higher due to sale of membership interests in three projects and project terminations in the REF business	$	4	$	11
Higher prices in the Steel business	2		7
Other	2		5
	$	8	$	23

Operation and maintenance expense decreased $7 million and $8 million in the three and six months ended June 30, 2019, respectively. The decrease in the second quarter and six-month period was primarily due to sale of membership interests in the REF business, partially offset by increasing spending in the On-site and Steel businesses.

Other (Income) and Deductions increased $3 million and $12 million in the three and six months ended June 30, 2019, respectively. The increase in the second quarter and six-month period was primarily due to sale of membership interests in the REF business.

Income Taxes — Production Tax Credits decreased $30 million and $52 million in the three and six months ended June 30, 2019, respectively. The decrease in the second quarter and six-month period was primarily due to sale of membership interests in the REF business.

Net Loss Attributable to Noncontrolling Interests increased $2 million and decreased $16 million in the three and six months ended June 30, 2019, respectively. The decrease in the six-month period was primarily due to projects terminated in the REF business.

Outlook — Power and Industrial Projects will continue to leverage its extensive energy-related operating experience and project management capability to develop additional energy projects to serve energy intensive industrial customers in addition to optimizing the REF facilities until the phase out at the end of 2021.

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ENERGY TRADING

Energy Trading focuses on physical and financial power and natural gas marketing and trading, structured transactions, enhancement of returns from its asset portfolio, and optimization of contracted natural gas pipeline transportation and storage positions. Energy Trading also provides natural gas, power, and related services, which may include the management of associated storage and transportation contracts on the customers' behalf, and the supply or purchase of renewable energy credits to various customers. Energy Trading results are discussed below:

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019		2018
	(In millions)
Operating Revenues — Non-utility operations	$	1,113		$	1,164		$	2,414	$	2,662
Purchased power and gas — non-utility	1,100			1,149			2,335		2,585
Non-utility Margin	13			15			79		77
Operation and maintenance	17			17			36		34
Depreciation and amortization	2			2			3		3
Taxes other than income	1			1			3		3
Operating Income (Loss)	(7		)	(5		)	37		37
Other (Income) and Deductions	1			1			2		2
Income Tax Expense (Benefit)	(2		)	(1		)	9		9
Net Income (Loss) Attributable to DTE Energy Company	$	(6	)	$	(5	)	$	26	$	26

Operating Revenues — Non-utility operations decreased $51 million and $248 million in the three and six months ended June 30, 2019, respectively. The decrease in the second quarter and the six-month period was primarily due to a decrease in gas prices and volumes, primarily in the gas structured and gas transportation strategies.

Non-utility Margin decreased $2 million and increased $2 million in the three and six months ended June 30, 2019, respectively. The following tables detail changes in Non-utility margin relative to the comparable prior periods:

	Three Months
	(In millions)
Unrealized Margins(a)
Favorable results, primarily in the gas structured strategy(b)	$	25
Unfavorable results, primarily in gas trading and power full requirements strategies	(12		)
	13
Realized Margins(a)
Favorable results, primarily in the environmental trading strategy	6
Unfavorable results, primarily in gas structured and gas trading strategies(c)	(21		)
	(15		)
Decrease in Non-utility Margin	$	(2	)

_______________________________________

(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 $29 million of timing related gains related to gas strategies which will reverse in future periods as the underlying contracts settle.

(c) Amount includes $13 million of timing related gains related to gas strategies recognized in previous periods that reversed as the underlying contracts settled.

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	Six Months
	(In millions)
Unrealized Margins(a)
Favorable results, primarily in gas structured and gas transportation strategies(b)	$	73
Unfavorable results, primarily in gas trading and power full requirements strategies	(15		)
	58
Realized Margins(a)
Favorable results, primarily in power full requirements and gas and power trading strategies	31
Unfavorable results, primarily in gas structured and gas storage strategies(c)	(87		)
	(56		)
Increase in Non-utility Margin	$	2

_______________________________________

(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 $71 million of timing related gains related to gas strategies which will reverse in future periods as the underlying contracts settle.

(c) Amount includes $60 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, and 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 Regional Transmission Organizations. Significant portions of the Energy Trading portfolio are economically hedged. Most financial instruments and physical power and natural gas contracts are deemed derivatives, whereas natural gas inventory, pipeline transportation, renewable energy credits, and storage assets 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 7 and 8 to the Consolidated Financial Statements, "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. The net loss of $32 million and $35 million for the three and six months ended June 30, 2019, respectively, represents a decrease of $9 million and $27 million from the net losses of $41 million and $62 million in the comparable 2018 period. The net loss decrease in the second quarter was primarily due to effective income tax rate adjustments, partially offset by higher interest expense. For the six-month period, the decrease was primarily due to effective income tax rate adjustments and higher excess tax benefits on stock-based compensation, partially offset by higher interest expense.

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 2019 will be approximately $2.4 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 2019 of approximately $3.9 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.

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	Six Months Ended June 30,
	2019			2018
	(In millions)
Cash, Cash Equivalents, and Restricted Cash
Cash Flow From (Used For)
Operating Activities
Net Income	$	587		$	587
Adjustments to reconcile Net Income to Net cash from operating activities:
Depreciation and amortization	601			553
Nuclear fuel amortization	30			25
Allowance for equity funds used during construction	(13		)	(13		)
Deferred income taxes	80			80
Asset (gains) losses and impairments, net	13			—
Working capital and other	69			201
Net cash from operating activities	1,367			1,433
Investing Activities
Plant and equipment expenditures — utility	(1,294		)	(1,027		)
Plant and equipment expenditures — non-utility	(102		)	(130		)
Contributions to equity method investees	(38		)	(233		)
Notes receivable	(62		)	5
Other	(18		)	5
Net cash used for investing activities	(1,514		)	(1,380		)
Financing Activities
Issuance of long-term debt, net of issuance costs	1,438			520
Redemption of long-term debt	—			(102		)
Short-term borrowings, net	(606		)	(147		)
Issuance of common stock	—			6
Dividends paid on common stock	(345		)	(309		)
Contributions from noncontrolling interests, principally REF entities	17			22
Distributions to noncontrolling interests	(31		)	(17		)
Purchases of noncontrolling interest, principally SGG	(300		)	—
Other	(40		)	(29		)
Net cash from (used for) financing activities	133			(56		)
Net Decrease in Cash, Cash Equivalents, and Restricted Cash	$	(14	)	$	(3	)

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.

Cash from operations decreased by $66 million in 2019 due primarily to a decrease in cash from working capital items, partially offset by an increase in Depreciation and amortization expense.

The change in working capital items in 2019 was primarily related to an increase in cash used for accounts payable, regulatory assets and liabilities, and other current and noncurrent assets and liabilities, partially offset by an increase in cash from accounts receivable and accrued pension liability.

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. In any given year, DTE Energy looks to realize cash from under-performing or non-strategic assets or matured, fully valued assets.

69

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 increased by $134 million in 2019 due primarily to the increase in Plant and equipment expenditures — utility and Notes Receivable, partially offset by the decrease in Contributions to equity method investees and Plant and equipment expenditures — non-utility.

Cash from (used for) 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 increased by $189 million in 2019 due primarily to an increase in Issuance of long-term debt and the reduction of Redemption of long-term debt, partially offset by the increase in repayments of Short-term borrowings and Purchases of noncontrolling interests, principally related to SGG.

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.

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 $1.5 billion in long-term debt, including finance leases, maturing in the next twelve months. The repayment of the debt is expected to be paid through internally generated funds or the issuance of long-term debt.

DTE Energy has approximately $2.4 billion of available liquidity at June 30, 2019, consisting of cash and amounts available under unsecured revolving credit agreements.

DTE Energy expects to issue equity up to $250 million in 2019 through the pension and other employee benefit plans, which is exclusive from any amounts related to the Equity Units described in Note 14 to the Consolidated Financial Statements, "Long-Term Debt," within the combined DTE Energy and DTE Electric 2018 Annual Report on Form 10-K. For contribution amounts related to pension plans, refer to Note 13 of the Consolidated Financial Statements, "Retirement Benefits and Trusteed Assets."

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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, and coal) and the provisions and maturities of the underlying transactions. As of June 30, 2019, 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 $541 million.

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 of 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 5, 9, 10, 12, and 13 to the Consolidated Financial Statements, "Regulatory Matters," "Long-Term Debt," "Short-Term Credit Arrangements and Borrowings," "Commitments and Contingencies," and "Retirement Benefits and Trusteed Assets," respectively.

NEW ACCOUNTING PRONOUNCEMENTS

See Note 3 to the Consolidated Financial Statements, "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, 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 inventory, pipeline transportation contracts, renewable energy credits, and storage assets. See Notes 7 and 8 to the Consolidated Financial Statements, "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 credits 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 7 to the Consolidated Financial Statements, "Fair Value."

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The following table provides details on changes in DTE Energy's MTM net asset (or liability) position:

	DTE Energy
	(In millions)
MTM at December 31, 2018	$	(23	)
Reclassified to realized upon settlement	(9		)
Changes in fair value recorded to income	13
Amounts recorded to unrealized income	4
Changes in fair value recorded in regulatory liabilities	7
Amounts recorded in other comprehensive income, pretax	(12		)
Change in collateral	21
MTM at June 30, 2019	$	(3	)

The table below shows the maturity of DTE Energy's MTM positions. The positions from 2022 and beyond principally represent longer tenor gas structured transactions:

Source of Fair Value	2019			2020			2021			2022 and Beyond			Total Fair Value
	(In millions)
Level 1	$	(16	)	$	(3	)	$	(2	)	$	(1	)	$	(22	)
Level 2	(8		)	9			1			4			6
Level 3	14			17			—			(22		)	9
MTM before collateral adjustments	$	(10	)	$	23		$	(1	)	$	(19	)	(7		)
Collateral adjustments													4
MTM at June 30, 2019													$	(3	)

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Item 3. 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 to natural gas price fluctuations which impact the pricing for natural gas storage, gathering, and transportation. 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, 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-determined 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 June 30, 2019, PG&E's account is substantially current and outstanding accounts receivable from PG&E are not material. Therefore, DTE Energy determined no reserve was necessary.

As of June 30, 2019, the book value of long-lived assets used in producing electric output for sale to PG&E was approximately $103 million. The Power and Industrial Projects segment also has equity investments, including a note receivable, of approximately $73 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. There were no other new events occurring during the six months ended June 30, 2019, that would negatively impact the assumptions made within the December 31, 2018 impairment analysis. Therefore, no triggering events were identified. 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.

Other

The Registrants regularly review contingent matters 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.

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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 June 30, 2019:

	Credit Exposure Before Cash Collateral		Cash Collateral			Net Credit Exposure
	(In millions)
Investment Grade(a)
A- and Greater	$	252	$	—		$	252
BBB+ and BBB	315		—			315
BBB-	38		—			38
Total Investment Grade	605		—			605
Non-investment grade(b)	8		—			8
Internally Rated — investment grade(c)	243		(1		)	242
Internally Rated — non-investment grade(d)	25		(2		)	23
Total	$	881	$	(3	)	$	878

_______________________________________

(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 22% 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 11% 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.

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 London Inter-Bank Offered Rates (LIBOR). As of June 30, 2019, DTE Energy had a floating rate debt-to-total debt ratio of 0.02%.

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 June 2023.

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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 June 30, 2019 and 2018 by a hypothetical 10% and calculating the resulting change in the fair values.

The results of the sensitivity analyses:

	Assuming a 10% Increase in Prices/Rates						Assuming a 10% Decrease in Prices/Rates
	As of June 30,						As of June 30,
Activity	2019			2018			2019			2018			Change in the Fair Value of
	(In millions)
Gas contracts	$	11		$	5		$	(10	)	$	(5	)	Commodity contracts
Power contracts	$	1		$	3		$	(2	)	$	(7	)	Commodity contracts
Interest rate risk — DTE Energy	$	(633	)	$	(633	)	$	661		$	608		Long-term debt
Interest rate risk — DTE Electric	$	(298	)	$	(283	)	$	320		$	306		Long-term debt

For further discussion of market risk, see Note 8 to the Consolidated Financial Statements, "Financial and Other Derivative Instruments."

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Item 4. Controls and Procedures

DTE Energy

(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 June 30, 2019, 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) 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 June 30, 2019 that have materially affected, or are reasonably likely to materially affect, DTE Energy's internal control over financial reporting.

DTE Electric

(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 June 30, 2019, 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) 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 June 30, 2019 that have materially affected, or are reasonably likely to materially affect, DTE Electric's internal control over financial reporting.

76

Part II — Other Information

Item 1. Legal Proceedings

In March 2018, the Trenton Channel Power Plant experienced exceedances of its mercury emission limits. The exceedances were reported to the EPA and the MDEQ. On September 12, 2018, the EPA issued a NOV. On June 28, 2019, DTE Electric entered into a Consent Agreement and Final Order (CAFO) with the EPA to resolve the allegations in the NOV. Under the CAFO, DTE Electric agreed to pay a civil penalty in the amount of $25,133 and to spend $95,000 on environmental projects that will benefit the Grosse Ile School District and the City of Trenton.

For more information on legal proceedings and matters related to the Registrants, see Notes 5 and 12 to the Consolidated Financial Statements, "Regulatory Matters" and "Commitments and Contingencies," respectively.

Item 1A. Risk Factors

There are various risks associated with the operations of the Registrants' businesses. To provide a framework to understand the operating environment of the Registrants, a brief explanation of the more significant risks associated with the Registrants' businesses is provided in Part 1, Item 1A. Risk Factors in DTE Energy's and DTE Electric's combined 2018 Annual Report on Form 10-K. Although the Registrants have tried to identify and discuss key risk factors, others could emerge in the future.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

Purchases of DTE Energy Equity Securities by the Issuer and Affiliated Purchasers

The following table provides information about DTE Energy purchases of equity securities that are registered by DTE Energy pursuant to Section 12 of the Exchange Act of 1934 for the quarter ended June 30, 2019:

	Number of Shares Purchased(a)	Average Price Paid per Share(a)		Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Average Price Paid per Share	Maximum Dollar Value that May Yet Be Purchased Under the Plans or Programs
04/01/2019 — 04/30/2019	2,920	$	113.87	—	—	—
05/01/2019 — 05/31/2019	653	$	107.73	—	—	—
06/01/2019 — 06/30/2019	—	$	—	—	—	—
Total	3,573			—

_______________________________________

(a) Represents shares of common stock withheld to satisfy income tax obligations upon the vesting of restricted stock based on the price in effect at the grant date.

77

Item 6. Exhibits

Exhibit Number	Description	DTE Energy	DTE Electric
	(i) Exhibits filed herewith:
4.306	Supplemental Indenture dated as of June 1, 2019, to the Amended and Restated Indenture, dated as of April 9, 1924, between DTE Energy Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee. (2019 Series B and C)	X
31.165	Chief Executive Officer Section 302 Form 10-Q Certification of Periodic Report	X
31.166	Chief Financial Officer Section 302 Form 10-Q Certification of Periodic Report	X
31.167	Chief Executive Officer Section 302 Form 10-Q Certification of Periodic Report		X
31.168	Chief Financial Officer Section 302 Form 10-Q Certification of Periodic Report		X
101.INS	XBRL Instance Document - The instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL 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
	(ii) Exhibits furnished herewith:
32.165	Chief Executive Officer Section 906 Form 10-Q Certification of Periodic Report	X
32.166	Chief Financial Officer Section 906 Form 10-Q Certification of Periodic Report	X
32.167	Chief Executive Officer Section 906 Form 10-Q Certification of Periodic Report		X
32.168	Chief Financial Officer Section 906 Form 10-Q Certification of Periodic Report		X
	(iii) Exhibits incorporated by reference:
4.307	Form of Fourth Amended and Restated Five-Year Credit Agreement, dated as of April 15, 2019, by and among DTE Energy, the lenders party thereto, Citibank, N.A., as Administrative Agent. (Exhibit 10.01 to DTE Energy's Form 8-K filed on April 16, 2019)	X
4.308	Form of Fourth Amended and Restated Five-Year Credit Agreement, dated as of April 15, 2019, by and among DTE Gas, the lenders party thereto, Citibank, N.A., as Administrative Agent. (Exhibit 10.02 to DTE Energy's Form 8-K filed on April 16, 2019)	X
4.309	Form of Fourth Amended and Restated Five-Year Credit Agreement, dated as of April 15, 2019, by and among DTE Electric Company, the lenders party thereto, Citibank, N.A., as Administrative Agent. (Exhibit 10.01 to DTE Energy's Form 8-K filed on April 16, 2019)	X	X

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Signatures

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrants have duly caused this report to be signed on their behalf by the undersigned, thereunto duly authorized. The signature for each undersigned Registrant shall be deemed to relate only to matters having reference to such Registrant and any subsidiaries thereof.

Date:	July 24, 2019
			DTE ENERGY COMPANY
		By:	/S/ MARK C. ROLLING
			Mark C. Rolling Vice President, Controller, and Chief Accounting Officer
			(Duly Authorized Officer)
			DTE ELECTRIC COMPANY
		By:	/S/ MARK C. ROLLING
			Mark C. Rolling Vice President, Controller, and Chief Accounting Officer
			(Duly Authorized Officer)

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EX-4.306

Exhibit 4.306

DTE ENERGY COMPANY
AND
THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A.,
TRUSTEE

__________________________

SUPPLEMENTAL INDENTURE
DATED AS OF JUNE 1, 2019

__________________________

SUPPLEMENTING THE AMENDED AND RESTATED INDENTURE
DATED AS OF APRIL 9, 2001

PROVIDING FOR

2019 SERIES B 2.60% SENIOR NOTES DUE 2022

AND

2019 SERIES C 3.40% SENIOR NOTES DUE 2029

1

SUPPLEMENTAL INDENTURE, dated as of the 1st day of June, 2019, between DTE ENERGY COMPANY, a corporation organized and existing under the laws of the State of Michigan (the “Company”), and The Bank of New York Mellon Trust Company, N.A., as successor trustee (the “Trustee”);

WHEREAS, the Company has heretofore executed and delivered to the Trustee an Amended and Restated Indenture, dated as of April 9, 2001 (the “Original Indenture”), as amended, supplemented or modified (as so amended, supplemented or modified, the “Indenture”) providing for the issuance by the Company from time to time of its debt securities; and

WHEREAS, the Company now desires to provide for the issuance of two series of its unsecured, senior debt securities pursuant to the Original Indenture; and

WHEREAS, the Company, in the exercise of the power and authority conferred upon and reserved to it under the provisions of the Original Indenture, including Section 901 thereof, and pursuant to appropriate resolutions of the Board of Directors, has duly determined to make, execute and deliver to the Trustee this Supplemental Indenture to the Original Indenture as permitted by Section 201 and Section 301 of the Original Indenture in order to establish the forms or terms of, and to provide for the creation and issue of, two series of its debt securities under the Original Indenture, the first of which shall be known as the “2019 Series B 2.60% Senior Notes due 2022” and the second of which shall be known as the “2019 Series C 3.40% Senior Notes due 2029”; and

WHEREAS, all things necessary to make such debt securities, when executed by the Company and authenticated and delivered by the Trustee or any Authenticating Agent and issued upon the terms and subject to the conditions hereinafter and in the Original Indenture set forth against payment therefor, the valid, binding and legal obligations of the Company and to make this Supplemental Indenture a valid, binding and legal agreement of the Company, have been done;

NOW, THEREFORE, THIS SUPPLEMENTAL INDENTURE WITNESSETH that, in order to establish the terms of two series of debt securities, and for and in consideration of the premises and of the covenants contained in the Original Indenture and in this Supplemental Indenture and for other good and valuable consideration the receipt and sufficiency of which are hereby acknowledged, it is mutually covenanted and agreed as follows:

article 1
DEFINITIONS AND OTHER
PROVISIONS OF GENERAL APPLICATION

SECTION 101.Definitions. Each capitalized term that is used herein and is defined in the Original Indenture shall have the meaning specified in the Original Indenture unless such term is otherwise defined herein. The following term shall have the meaning set forth below:

“Business Day” means any day other than a Saturday or Sunday or a day on which commercial banks in the state of New York or the state of Michigan are required or authorized by law or executive order to be closed.

1

SECTION 102.Section References. Each reference to a particular section set forth in this Supplemental Indenture shall, unless the context otherwise requires, refer to this Supplemental Indenture.

ARTICLE 2
TITLE AND TERMS OF THE 2019 SERIES B 2.60% SENIOR NOTES DUE 2022

SECTION 201.Title of the Series B Notes; Stated Maturity. This Supplemental Indenture hereby establishes a series of Securities, which shall be known as the Company's “2019 Series B 2.60% Senior Notes due 2022” (the “Series B Notes”). The Stated Maturity on which the principal of the Series B Notes shall be due and payable will be June 15, 2022.

SECTION 202.Rank. The Series B Notes shall rank equally with all other unsecured and unsubordinated indebtedness of the Company from time to time outstanding.

SECTION 203.Variations from the Original Indenture. Section 1009 of the Original Indenture shall be applicable to the Series B Notes. Section 403(2) and Section 403(3) shall be applicable to the Series B Notes; the Company's obligations under Section 1009, without limitation, shall be subject to defeasance in accordance with Section 403(3).

SECTION 204.Amount and Denominations; DTC. (a) The aggregate principal amount of the Series B Notes that may be issued under this Supplemental Indenture is limited initially to $300,000,000 (except as provided in Section 301(2) of the Original Indenture); provided that the Company may, without the consent of the Holders of the Outstanding Series B Notes, “reopen” the Series B Notes so as to increase the aggregate principal amount of the Series B Notes Outstanding in compliance with the procedures set forth in the Original Indenture, including Section 301 and Section 303 thereof, so long as any such additional Series B Notes have the same tenor and terms (including, without limitation, rights to receive accrued and unpaid interest) as the Series B Notes then Outstanding. No additional Series B Notes may be issued if an Event of Default has occurred. The Series B Notes shall be issuable only in fully registered form and, as permitted by Section 301 and Section 302 of the Original Indenture, in denominations of $2,000 and integral multiples of $1,000 in excess thereof. The Series B Notes will initially be issued in global form (the “Global Series B Notes”) under a book-entry system, registered in the name of The Depository Trust Company, as depository (“DTC”), or its nominee, which is hereby designated as “Depositary” under the Indenture.

(a)Further to Section 305 of the Original Indenture, any Global Series B Note shall be exchangeable for Series B Notes registered in the name of, and a transfer of a Global Series B Note may be registered to, any Person other than the Depositary for such Series B Note or its nominee only if (i) such Depositary notifies the Company that it is unwilling or unable to continue as Depositary for such Global Series B Note or if at any time such Depositary ceases to be a clearing agency registered under the Exchange Act, and, in either such case, the Company does not appoint a successor Depositary within 90 days thereafter, (ii) the Company executes and delivers to the Trustee a Company Order that such Global Series B Note shall be so exchangeable and the transfer thereof so registrable or (iii) there shall have occurred and be continuing an Event of Default or an

2

event which, with the giving of notice or lapse of time, or both, would constitute an Event of Default with respect to the Series B Notes. Upon the occurrence in respect of a Global Series B Note of any or more of the conditions specified in clause (i), (ii) or (iii) of the preceding sentence, such Global Series B Note may be exchanged for Series B Notes registered in the name of, and the transfer of such Global Series B Note may be registered to, such Persons (including Persons other than the Depositary and its nominees) as such Depositary, in the case of an exchange, and the Company, in the case of a transfer, shall direct.

SECTION 205.Terms of the Series B Notes.

(a)    The Series B Notes shall bear interest at the rate of 2.60% per annum on the principal amount thereof from June 13, 2019, or from the most recent Interest Payment Date to which interest has been paid or duly provided for, until the principal of the Series B Notes becomes due and payable, and on any overdue principal and premium and (to the extent that payment of such interest is enforceable under applicable law) on any overdue installment of interest at the same rate per annum during such overdue period. Interest on the Series B Notes will be payable semiannually in arrears on June 15 and December 15 of each year (each such date, an “Interest Payment Date”), commencing December 15, 2019. The amount of interest payable for any period shall be computed on the basis of twelve 30-day months and a 360-day year.

(b)    In the event that any Interest Payment Date, redemption date or other date of Maturity of the Series B Notes is not a Business Day, then payment of the amount payable on such date will be made on the next succeeding day which is a Business Day (and without any interest or other payment in respect of any such delay), in each case with the same force and effect as if made on such date. The interest installment so payable, and punctually paid or duly provided for, on any Interest Payment Date with respect to any Series B Note will, as provided in the Original Indenture, be paid to the person in whose name the Series B Note (or one or more Predecessor Securities, as defined in said Indenture) is registered at the close of business on the relevant record date for such interest installment, which shall be the fifteenth calendar day (whether or not a Business Day) prior to the relevant Interest Payment Date (the “Regular Record Date”). Any such interest installment not punctually paid or duly provided for shall forthwith cease to be payable to the registered Holders on such Regular Record Date, and may either be paid to the person in whose name the Series B Note (or one or more Predecessor Securities) is registered at the close of business on a Special Record Date to be fixed by the Trustee for the payment of such defaulted interest, notice whereof shall be given to the registered Holders of the Series B Notes not less than ten days prior to such Special Record Date, or may be paid at any time in any other lawful manner not inconsistent with the requirements of any securities exchange on which the Series B Notes may be listed, and upon such notice as may be required by such exchange, all as more fully provided in the Original Indenture. The principal of, and premium, if any, and the interest on the Series B Notes shall be payable at the office or agency of the Company maintained for that purpose in the Borough of Manhattan, City of New York, in any coin or currency of the United States of America which at the time of payment is legal tender for payment of public and private debts; provided, however, that payment of interest may be made at the option of the Company by check mailed to the registered Holder at the close of business on the Regular Record Date at such address as shall appear in the Security Register.

3

(c)    The Series B Notes are not subject to repayment at the option of the Holders thereof and are not subject to any sinking fund. As provided in the form of Series B Note attached hereto as Exhibit A, the Series B Notes are subject to optional redemption, as a whole or in part, by the Company prior to Stated Maturity of the principal thereof on the terms set forth therein. Except as modified in the form of the Series B Note, redemption shall be effected in accordance with Article Eleven of the Original Indenture.

(a)The Series B Notes shall have such other terms and provisions as are set forth in the form of Series B Note attached hereto as Exhibit A (which is incorporated by reference in and made a part of this Supplemental Indenture as if set forth in full at this place).

SECTION 206.Form of Series B Notes. Attached hereto as Exhibit A is the form of the Series B Notes.

ARTICLE 3
TITLE AND TERMS OF THE 2019 SERIES C 3.40% SENIOR NOTES DUE 2029

SECTION 301.Title of the Series C Notes; Stated Maturity. This Supplemental Indenture hereby establishes a series of Securities, which shall be known as the Company's “2019 Series C 3.40% Senior Notes due 2029” (the “Series C Notes” and together with the Series B Notes, the “Notes”). The Stated Maturity on which the principal of the Series C Notes shall be due and payable will be June 15, 2029.

SECTION 302.Rank. The Series C Notes shall rank equally with all other unsecured and unsubordinated indebtedness of the Company from time to time outstanding.

SECTION 303.Variations from the Original Indenture. Section 1009 of the Original Indenture shall be applicable to the Series C Notes. Section 403(2) and Section 403(3) shall be applicable to the Series C Notes; the Company's obligations under Section 1009, without limitation, shall be subject to defeasance in accordance with Section 403(3).

SECTION 304.Amount and Denominations; DTC. (a) The aggregate principal amount of the Series C Notes that may be issued under this Supplemental Indenture is limited initially to $500,000,000 (except as provided in Section 301(2) of the Original Indenture); provided that the Company may, without the consent of the Holders of the Outstanding Series C Notes, “reopen” the Series C Notes so as to increase the aggregate principal amount of the Series C Notes Outstanding in compliance with the procedures set forth in the Original Indenture, including Section 301 and Section 303 thereof, so long as any such additional Series C Notes have the same tenor and terms (including, without limitation, rights to receive accrued and unpaid interest) as the Series C Notes then Outstanding. No additional Series C Notes may be issued if an Event of Default has occurred. The Series C Notes shall be issuable only in fully registered form and, as permitted by Section 301 and Section 302 of the Original Indenture, in denominations of $2,000 and integral multiples of $1,000 in excess thereof. The Series C Notes will initially be issued in global form (the “Global Series C Notes”) under a book-entry system, registered in the name of DTC, as depository, or its nominee, which is hereby designated as “Depositary” under the Indenture.

4

(a)Further to Section 305 of the Original Indenture, any Global Series C Note shall be exchangeable for Series C Notes registered in the name of, and a transfer of a Global Series C Note may be registered to, any Person other than the Depositary for such Series C Note or its nominee only if (i) such Depositary notifies the Company that it is unwilling or unable to continue as Depositary for such Global Series C Note or if at any time such Depositary ceases to be a clearing agency registered under the Exchange Act, and, in either such case, the Company does not appoint a successor Depositary within 90 days thereafter, (ii) the Company executes and delivers to the Trustee a Company Order that such Global Series C Note shall be so exchangeable and the transfer thereof so registrable or (iii) there shall have occurred and be continuing an Event of Default or an event which, with the giving of notice or lapse of time, or both, would constitute an Event of Default with respect to the Series C Notes. Upon the occurrence in respect of a Global Series C Note of any or more of the conditions specified in clause (i), (ii) or (iii) of the preceding sentence, such Global Series C Note may be exchanged for Series C Notes registered in the name of, and the transfer of such Global Series C Note may be registered to, such Persons (including Persons other than the Depositary and its nominees) as such Depositary, in the case of an exchange, and the Company, in the case of a transfer, shall direct.

SECTION 305.Terms of the Series C Notes.

(a)    The Series C Notes shall bear interest at the rate of 3.40% per annum on the principal amount thereof from June 13, 2019, or from the most recent Interest Payment Date to which interest has been paid or duly provided for, until the principal of the Series C Notes becomes due and payable, and on any overdue principal and premium and (to the extent that payment of such interest is enforceable under applicable law) on any overdue installment of interest at the same rate per annum during such overdue period. Interest on the Series C Notes will be payable semiannually in arrears on June 15 and December 15 of each year (each such date, an “Interest Payment Date”), commencing December 15, 2019. The amount of interest payable for any period shall be computed on the basis of twelve 30-day months and a 360-day year.

(b)    In the event that any Interest Payment Date, redemption date or other date of Maturity of the Series C Notes is not a Business Day, then payment of the amount payable on such date will be made on the next succeeding day which is a Business Day (and without any interest or other payment in respect of any such delay), in each case with the same force and effect as if made on such date. The interest installment so payable, and punctually paid or duly provided for, on any Interest Payment Date with respect to any Series C Note will, as provided in the Original Indenture, be paid to the person in whose name the Series C Note (or one or more Predecessor Securities, as defined in said Indenture) is registered at the close of business on the relevant record date for such interest installment, which shall be the fifteenth calendar day (whether or not a Business Day) prior to the relevant Interest Payment Date (the “Regular Record Date”). Any such interest installment not punctually paid or duly provided for shall forthwith cease to be payable to the registered Holders on such Regular Record Date, and may either be paid to the person in whose name the Series C Note (or one or more Predecessor Securities) is registered at the close of business on a Special Record Date to be fixed by the Trustee for the payment of such defaulted interest, notice whereof shall be given to the registered Holders of the Series C Notes not less than ten days prior to such Special Record Date, or may be paid at any time in any other lawful manner not inconsistent with

5

the requirements of any securities exchange on which the Series C Notes may be listed, and upon such notice as may be required by such exchange, all as more fully provided in the Original Indenture. The principal of, and premium, if any, and the interest on the Series C Notes shall be payable at the office or agency of the Company maintained for that purpose in the Borough of Manhattan, City of New York, in any coin or currency of the United States of America which at the time of payment is legal tender for payment of public and private debts; provided, however, that payment of interest may be made at the option of the Company by check mailed to the registered Holder at the close of business on the Regular Record Date at such address as shall appear in the Security Register.

(c)    The Series C Notes are not subject to repayment at the option of the Holders thereof and are not subject to any sinking fund. As provided in the form of Series C Note attached hereto as Exhibit B, the Series C Notes are subject to optional redemption, as a whole or in part, by the Company prior to Stated Maturity of the principal thereof on the terms set forth therein. Except as modified in the form of the Series C Note, redemption shall be effected in accordance with Article Eleven of the Original Indenture.

(d)    The Series C Notes shall have such other terms and provisions as are set forth in the form of Series C Note attached hereto as Exhibit B (which is incorporated by reference in and made a part of this Supplemental Indenture as if set forth in full at this place).

SECTION 306.Form of Series C Notes. Attached hereto as Exhibit B is the form of the Series C Notes.

ARTICLE 4
MISCELLANEOUS PROVISIONS

The Trustee makes no undertaking or representations in respect of, and shall not be responsible in any manner whatsoever for and in respect of, the validity or sufficiency of this Supplemental Indenture or the proper authorization or the due execution hereof by the Company or for or in respect of the recitals and statements contained herein, all of which recitals and statements are made solely by the Company.

Except as expressly amended hereby, the Original Indenture shall continue in full force and effect in accordance with the provisions thereof and the Original Indenture is in all respects hereby ratified and confirmed. This Supplemental Indenture and all its provisions shall be deemed a part of the Original Indenture in the manner and to the extent herein and therein provided.

This Supplemental Indenture and the Notes shall be governed by, and construed in accordance with, the laws of the State of New York.

This Supplemental Indenture may be executed in any number of counterparts, each of which so executed shall be deemed to be an original, but all such counterparts shall together constitute but one and the same instrument.

6

IN WITNESS WHEREOF, the parties hereto have caused this Supplemental Indenture to be duly executed, all as of the day and year first above written.

DTE ENERGY COMPANY

By: /s/ Jeffrey A. Jewell            

Name:    Jeffrey A. Jewell

Title:     Vice President, Treasurer

and Chief Risk Officer

ATTEST:

By: /s/ Lisa A. Muschong         

Name:    Lisa A. Muschong

Title:     Vice President, Corporate Secretary

and Chief of Staff

[Signature Page to Supplemental Indenture]

7

THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A., as Trustee

By /s/ Valere Boyd    

Name:    Valere Boyd

Title:     Vice President

[Signature Page to Supplemental Indenture]

8

EXHIBIT A

FORM OF SERIES B NOTE

THIS NOTE IS A GLOBAL NOTE WITHIN THE MEANING OF THE INDENTURE HEREINAFTER REFERRED TO AND IS REGISTERED IN THE NAME OF A DEPOSITARY OR A NOMINEE OF A DEPOSITARY. UNLESS AND UNTIL IT IS EXCHANGED IN WHOLE OR IN PART FOR NOTES IN CERTIFICATED FORM, THIS NOTE MAY NOT BE TRANSFERRED EXCEPT AS A WHOLE BY THE DEPOSITORY TRUST COMPANY (“DTC”), TO A NOMINEE OF DTC OR BY DTC OR ANY SUCH NOMINEE TO A SUCCESSOR OF DTC OR A NOMINEE OF SUCH SUCCESSOR. UNLESS THIS NOTE IS PRESENTED BY AN AUTHORIZED REPRESENTATIVE OF DTC TO THE ISSUER OR ITS AGENT FOR REGISTRATION OF TRANSFER, EXCHANGE OR PAYMENT, AND ANY NOTE ISSUED IS REGISTERED IN THE NAME OF CEDE & CO., OR IN SUCH OTHER NAME AS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF DTC (AND ANY PAYMENT HEREON IS MADE TO CEDE & CO., OR TO SUCH OTHER ENTITY AS IS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF DTC), ANY TRANSFER, PLEDGE OR OTHER USE HEREOF FOR VALUE OR OTHERWISE BY A PERSON IS WRONGFUL, INASMUCH AS THE REGISTERED OWNER HEREOF, CEDE & CO., HAS AN INTEREST HEREIN.

CUSIP NO. 233331 BB2                              $__________

NO. : ______

DTE ENERGY COMPANY
2019 SERIES B 2.60% SENIOR NOTES DUE 2022

DTE ENERGY COMPANY, a corporation duly organized and existing under the laws of the State of Michigan (herein referred to as the “Company”, which term includes any successor Person under the Indenture hereinafter referred to), for value received, hereby promises to pay to CEDE & CO., or registered assigns, the principal sum of $__________ on June 15, 2022 (“Stated Maturity” with respect to the principal of this Note), unless previously redeemed, and to pay interest at the rate of 2.60% per annum on said principal sum from June 13, 2019, or from the most recent Interest Payment Date to which interest has been paid or duly provided for, until the principal of this Note becomes due and payable, and on any overdue principal and premium and (to the extent that payment of such interest is enforceable under applicable law) on any overdue installment of interest at the same rate per annum during such overdue period. Interest on this Note will be payable semiannually in arrears on June 15 and December 15 of each year (each such date, an “Interest Payment Date”), commencing December 15, 2019. The amount of interest payable for any period shall be computed on the basis of twelve 30-day months and a 360-day year.

In the event that any Interest Payment Date, redemption date or other date of Maturity of the Notes is not a Business Day, then payment of the amount payable on such date will be made on the next succeeding day which is a Business Day (and without any interest or other payment in respect of any such delay), in each case with the same force and effect as if made on such date. A

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“Business Day” means any day other than a Saturday or Sunday or a day on which commercial banks in the state of New York or the state of Michigan are required or authorized by law or executive order to be closed. The interest installment so payable, and punctually paid or duly provided for, on any Interest Payment Date with respect to this Note will, as provided in the Indenture, be paid to the person in whose name this Note is registered at the close of business on the relevant record date for such interest installment, which shall be the fifteenth calendar day (whether or not a Business Day) prior to the relevant Interest Payment Date (the “Regular Record Date”). Any such interest installment not punctually paid or duly provided for shall forthwith cease to be payable to the registered Holders on such Regular Record Date, and may either be paid to the person in whose name this Note is registered at the close of business on a Special Record Date to be fixed by the Trustee for the payment of such defaulted interest, notice whereof shall be given to the registered Holders of the Notes not less than ten days prior to such Special Record Date, or may be paid at any time in any other lawful manner not inconsistent with the requirements of any securities exchange on which the Notes may be listed, and upon such notice as may be required by such exchange, all as more fully provided in the Indenture. The principal of, and premium, if any, and the interest on the Notes shall be payable at the office or agency of the Company maintained for that purpose in the Borough of Manhattan, City of New York, in any coin or currency of the United States of America which at the time of payment is legal tender for payment of public and private debts; provided, however, that payment of interest may be made at the option of the Company by check mailed to the registered Holder at the close of business on the Regular Record Date at such address as shall appear in the Security Register. Notwithstanding anything else contained herein, if this Note is a Global Note and is held in book-entry form through the facilities of the Depositary, payments on this Note will be made to the Depositary or its nominee in accordance with arrangements then in effect between the Trustee and the Depositary.

This Note is one of a duly authorized series of Securities of the Company, designated as the “2019 Series B 2.60% Senior Notes due 2022” (the “Notes”), initially limited to an aggregate principal amount of $300,000,000 (except for Notes authenticated and delivered upon transfer of, or in exchange for, or in lieu of other Notes, and except as further provided in the Indenture), all issued or to be issued under and pursuant to an Amended and Restated Indenture, dated as of April 9, 2001, as supplemented through and including the Supplemental Indenture dated as of June 1, 2019 (together, as amended, supplemented or modified, the “Indenture”), duly executed and delivered between the Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (herein referred to as the “Trustee”, which term includes any successor trustee under the Indenture), to which Indenture reference is hereby made for a description of the respective rights, limitations of rights, obligations, duties and immunities thereunder of the Trustee, the Company and the registered Holders of the Notes and of the terms upon which the Notes are, and are to be, authenticated and delivered.

This Note is not subject to repayment at the option of the Holder hereof. This Note is not subject to any sinking fund.

This Note will be redeemable at the option of the Company, in whole at any time or in part from time to time (any such date of optional redemption, an “Optional Redemption Date,” which shall be a “Redemption Date” for purposes of the Indenture) at the redemption prices set forth below.

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The optional redemption price (which shall be a “Redemption Price” for purposes of the Indenture) will be equal to the greater of (i) 100% of the principal amount of this Note to be redeemed and (ii) the sum of the present values of the principal amount of this Note to be redeemed and the remaining scheduled payments of interest on the principal amount of this Note to be redeemed (exclusive of interest accrued to the related Optional Redemption Date) until Stated Maturity, in each case discounted from their respective scheduled payment dates to such Optional Redemption Date on a semiannual basis (assuming a 360-day year consisting of 30-day months) at the Adjusted Treasury Rate (as defined below) plus 15 basis points, as determined by the Quotation Agent (as defined below), plus in either case, accrued interest thereon to the date of redemption.

Notwithstanding the foregoing, installments of interest on this Note that are due and payable on Interest Payment Dates falling on or prior to a Redemption Date will be payable on the Interest Payment Date to the registered Holders as of the close of business on the relevant Record Date.

“Adjusted Treasury Rate” means, with respect to any Optional Redemption Date, the rate per annum equal to the semiannual equivalent yield to maturity of the Comparable Treasury Issue, calculated on the third Business Day preceding such Optional Redemption Date, using a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such Optional Redemption Date.

“Comparable Treasury Issue” means the United States Treasury security selected by the Quotation Agent as having a maturity comparable to the remaining term of this Note that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity with the remaining term of this Note.

“Comparable Treasury Price” means, with respect to any Optional Redemption Date, (i) the average of the Reference Treasury Dealer Quotations for such Optional Redemption Date, after excluding the highest and lowest such Reference Treasury Dealer Quotations, or (ii) if the Quotation Agent obtains fewer than three such Reference Treasury Dealer Quotations, the average of all such quotations, or (iii) if only one Reference Treasury Dealer Quotation is received, such quotation.

“Quotation Agent” means one of the Reference Treasury Dealers appointed by the Company.

“Reference Treasury Dealer” means: (i) each of BNP Paribas Securities Corp., Citigroup Global Markets, Inc. and Mizuho Securities USA LLC (or their respective affiliates which are a primary U.S. Government securities dealer in the United States (a “Primary Treasury Dealer”), and a Primary Treasury Dealer selected by MUFG Securities Americas Inc., or their respective successors; provided, however, that if any of the foregoing cease to be a Primary Treasury Dealer, the Company shall substitute therefor another Primary Treasury Dealer; and (ii) any other Primary Treasury Dealer(s) selected by the Company.

“Reference Treasury Dealer Quotation” means, with respect to each Reference Treasury Dealer and any Optional Redemption Date, the average, as determined by the Quotation Agent, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to the Quotation Agent by such Reference Treasury Dealer

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at 5:00 p.m., New York City time, on the third Business Day preceding such Optional Redemption Date.

Notice of any optional redemption will be mailed at least 30 days but not more than 60 days before the Optional Redemption Date to the Holder hereof at its registered address.

If money sufficient to pay the applicable Redemption Price with respect to the principal amount of and accrued interest on the principal amount of this Note to be redeemed on the applicable Redemption Date is deposited with the Trustee or Paying Agent on or before the related Redemption Date and certain other conditions are satisfied, then on or after such Redemption Date, interest will cease to accrue on the principal amount of this Note called for redemption. If the Notes are only partially redeemed by the Company, the Trustee shall select which Notes are to be redeemed by lot or in a manner it deems fair and appropriate in accordance with the terms of the Indenture.

In the event of redemption of this Note in part only, a new Note or Notes for the unredeemed portion hereof will be issued in the name of the registered Holder hereof upon the cancellation hereof.

In case an Event of Default, as defined in the Indenture, shall have occurred and be continuing, the principal hereof may be declared, and upon such declaration shall become, due and payable, in the manner, with the effect and subject to the conditions provided in the Indenture.

The Indenture contains provisions for defeasance at any time of the entire indebtedness of this Note upon compliance by the Company with certain conditions set forth therein.

The Indenture permits, with certain exceptions as therein provided, the amendment thereof and the modification of the rights and obligations of the Company and the rights of the Holders of the Notes under the Indenture at any time by the Company and the Trustee with the consent of the Holders of a majority of the aggregate principal amount of all Notes issued under the Indenture at the time outstanding and affected thereby; provided, however, that no such amendment shall without the consent of the Holder of each Note so affected, among other things (i) change the stated maturity of the principal of, or any installment of principal of or interest on any Notes, or reduce the principal amount thereof, or reduce the rate of interest thereon, or reduce any premium payable upon the redemption thereof or (ii) reduce the percentage of Notes, the Holders of which are required to consent to any amendment or waiver or for certain other matters as set forth in the Indenture. The Indenture also contains provisions permitting (i) the registered Holders of 66 2/3% in aggregate principal amount of the Securities at the time outstanding affected thereby, on behalf of the registered Holders of the Securities, to waive compliance by the Company with certain provisions of the Indenture and (ii) the registered Holders of not less than a majority in aggregate principal amount of the Securities at the time outstanding affected thereby, on behalf of the registered Holders of the Securities, to waive certain past defaults under the Indenture and their consequences. Any such consent or waiver by the registered Holder of this Note (unless revoked as provided in the Indenture) shall be conclusive and binding upon such registered Holder and upon all future registered Holders and owners of this Note and of any Note issued in exchange hereof or in place hereof (whether by registration of transfer or otherwise), irrespective of whether or not any notation of such consent or waiver is made upon this Note.

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No reference herein to the Indenture and no provision of this Note or of the Indenture shall alter or impair the obligation of the Company, which is absolute and unconditional, to pay the principal of and premium, if any, and interest on this Note at the time and place and at the rate and in the coin or currency herein prescribed.

As provided in the Indenture and subject to certain limitations therein set forth, the transfer of this Note is registrable in the Security Register of the Company, upon surrender of this Note for registration of transfer at the office or agency of the Company in any place where the principal of and any interest on this Note are payable or at such other offices or agencies as the Company may designate, duly endorsed by or accompanied by a written instrument or instruments of transfer in form satisfactory to the Company and the Security Registrar or any transfer agent duly executed by the registered Holder hereof or his or her attorney duly authorized in writing, and thereupon one or more new Notes of this series and of like tenor, of authorized denominations and for the same aggregate principal amount will be issued to the designated transferee or transferees. No service charge will be made for any such transfer, but the Company may require payment of a sum sufficient to cover any tax or other governmental charge payable in relation thereto.

Prior to due presentment for registration of transfer of this Note, the Company, the Trustee, any paying agent and any Security Registrar may deem and treat the registered Holder hereof as the absolute owner hereof (whether or not this Note shall be overdue and notwithstanding any notice of ownership or writing hereon made by anyone other than the Security Registrar) for the purpose of receiving payment of or on account of the principal hereof and interest due hereon and for all other purposes, and neither the Company nor the Trustee nor any paying agent nor any Security Registrar shall be affected by any notice to the contrary.

The Notes are issuable only in fully registered form without coupons in denominations of $1,000 and any integral multiple thereof. This Global Note is exchangeable for Notes in definitive form only under certain limited circumstances set forth in the Indenture. The Notes so issued are issuable only in registered form without coupons in denominations of $2,000 and any integral multiple of $1,000 in excess thereof. As provided in the Indenture and subject to certain limitations therein set forth, the Notes are exchangeable for a like aggregate principal amount of the Notes of a different authorized denomination, as requested by the registered Holder surrendering the same.

As set forth in, and subject to the provisions of, the Indenture, no registered owner of any Note will have any right to institute any proceeding with respect to the Indenture or for any remedy thereunder, unless (i) such registered owner shall have previously given to the Trustee written notice of a continuing Event of Default with respect to the Notes, (ii) the registered owners of not less than 25% in principal amount of the outstanding Notes shall have made written request, and offered reasonable indemnity, to the Trustee to institute such proceeding as trustee, (iii) the Trustee shall have failed to institute such proceeding within 60 days and (iv) the Trustee shall not have received from the registered owners of a majority in principal amount of the outstanding Notes a direction inconsistent with such request within such 60-day period; provided, however, that such limitations do not apply to a suit instituted by the registered owner hereof for the enforcement of payment of the principal of or premium, if any, or any interest on this Note on or after the respective due dates expressed herein.

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Unless the Certificate of Authentication hereon has been executed by the Trustee or a duly appointed Authentication Agent referred to herein, this Note shall not be entitled to any benefit under the Indenture or be valid or obligatory for any purpose.

The Indenture and this Note shall be governed by and construed in accordance with the laws of the State of New York.

All terms used in this Note which are defined in the Indenture shall have the meanings assigned to them in the Indenture.

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IN WITNESS WHEREOF, the Company has caused this Instrument to be duly executed.

DTE ENERGY COMPANY

By: _________________________________

Name: 

Title: 

Date: June 13, 2019

Attest:

By: _________________________________

Name: 

Title: 

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CERTIFICATE OF AUTHENTICATION

This is one of the Notes described in the within mentioned Indenture.

THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A.
as Trustee

By __________________________
Authorized Signatory

Date: June 13, 2019

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FOR VALUE RECEIVED, the undersigned hereby sell(s), assign(s) and transfer(s) unto

(Please insert Social Security or Other Identifying Number of Assignee)

(Please print or type name and address, including zip code of assignee)

the within Note and all rights thereunder, hereby irrevocably constituting and appointing such person attorneys to transfer the within Note on the books of the Issuer, with full power of substitution in the premises.

Dated:________________________

NOTICE: The signature of this assignment must correspond with the name as written upon the face of the within Note in every particular, without alteration or enlargement or any change whatever and NOTICE: Signature(s) must be guaranteed by a financial institution that is a member of the Securities Transfer Agents Medallion Program (“STAMP”), the Stock Exchange, Inc. Medallion Signature Program (“MSP”). When assignment is made by a guardian, trustee, executor or administrator, an officer of a corporation, or anyone in a representative capacity, proof of his or her authority to act must accompany this Note.

EXHIBIT B

FORM OF SERIES C NOTE

THIS NOTE IS A GLOBAL NOTE WITHIN THE MEANING OF THE INDENTURE HEREINAFTER REFERRED TO AND IS REGISTERED IN THE NAME OF A DEPOSITARY OR A NOMINEE OF A DEPOSITARY. UNLESS AND UNTIL IT IS EXCHANGED IN WHOLE OR IN PART FOR NOTES IN CERTIFICATED FORM, THIS NOTE MAY NOT BE TRANSFERRED EXCEPT AS A WHOLE BY THE DEPOSITORY TRUST COMPANY (“DTC”), TO A NOMINEE OF DTC OR BY DTC OR ANY SUCH NOMINEE TO A SUCCESSOR OF DTC OR A NOMINEE OF SUCH SUCCESSOR. UNLESS THIS NOTE IS PRESENTED BY AN AUTHORIZED REPRESENTATIVE OF DTC TO THE ISSUER OR ITS AGENT FOR REGISTRATION OF TRANSFER, EXCHANGE OR PAYMENT, AND ANY NOTE ISSUED IS REGISTERED IN THE NAME OF CEDE & CO., OR IN SUCH OTHER NAME AS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF DTC (AND ANY PAYMENT HEREON IS MADE TO CEDE & CO., OR TO SUCH OTHER ENTITY AS IS REQUESTED BY AN AUTHORIZED REPRESENTATIVE OF DTC), ANY TRANSFER, PLEDGE OR OTHER USE HEREOF FOR VALUE OR OTHERWISE BY A PERSON IS WRONGFUL, INASMUCH AS THE REGISTERED OWNER HEREOF, CEDE & CO., HAS AN INTEREST HEREIN.

CUSIP NO. 233331 BC0                             $__________

NO. : ______

DTE ENERGY COMPANY
2019 SERIES C 3.40% SENIOR NOTES DUE 2029

DTE ENERGY COMPANY, a corporation duly organized and existing under the laws of the State of Michigan (herein referred to as the “Company”, which term includes any successor Person under the Indenture hereinafter referred to), for value received, hereby promises to pay to CEDE & CO., or registered assigns, the principal sum of $__________ on June 15, 2029 (“Stated Maturity” with respect to the principal of this Note), unless previously redeemed, and to pay interest at the rate of 3.40% per annum on said principal sum from June 13, 2019, or from the most recent Interest Payment Date to which interest has been paid or duly provided for, until the principal of this Note becomes due and payable, and on any overdue principal and premium and (to the extent that payment of such interest is enforceable under applicable law) on any overdue installment of interest at the same rate per annum during such overdue period. Interest on this Note will be payable semiannually in arrears on June 15 and December 15 of each year (each such date, an “Interest Payment Date”), commencing December 15, 2019. The amount of interest payable for any period shall be computed on the basis of twelve 30-day months and a 360-day year.

In the event that any Interest Payment Date, redemption date or other date of Maturity of the Notes is not a Business Day, then payment of the amount payable on such date will be made on the next succeeding day which is a Business Day (and without any interest or other payment in respect of any such delay), in each case with the same force and effect as if made on such date. A “Business Day” means any day other than a Saturday or Sunday or a day on which commercial banks in the state of New York or the state of Michigan are required or authorized by law or executive order to be closed. The interest installment so payable, and punctually paid or duly provided for, on any Interest Payment Date with respect to this Note will, as provided in the Indenture, be paid to the person in whose name this Note is registered at the close of business on the relevant record date for such interest installment, which shall be the fifteenth calendar day (whether or not a Business Day) prior to the relevant Interest Payment Date (the “Regular Record Date”). Any such interest installment not punctually paid or duly provided for shall forthwith cease to be payable to the registered Holders on such Regular Record Date, and may either be paid to the person in whose name this Note is registered at the close of business on a Special Record Date to be fixed by the Trustee for the payment of such defaulted interest, notice whereof shall be given to the registered Holders of the Notes not less than ten days prior to such Special Record Date, or may be paid at any time in any other lawful manner not inconsistent with the requirements of any securities exchange on which the Notes may be listed, and upon such notice as may be required by such exchange, all as more fully provided in the Indenture. The principal of, and premium, if any, and the interest on the Notes shall be payable at the office or agency of the Company maintained for that purpose in the Borough of Manhattan, City of New York, in any coin or currency of the United States of America which at the time of payment is legal tender for payment of public and private debts; provided, however, that payment of interest may be made at the option of the Company by check mailed to the registered Holder at the close of business on the Regular Record Date at such address as shall appear in the Security Register. Notwithstanding anything else contained herein, if this Note is a Global Note and is held in book-entry form through the facilities of the Depositary, payments on this Note will be made to the Depositary or its nominee in accordance with arrangements then in effect between the Trustee and the Depositary.

This Note is one of a duly authorized series of Securities of the Company, designated as the “2019 Series C 3.40% Senior Notes due 2029” (the “Notes”), initially limited to an aggregate principal amount of $500,000,000 (except for Notes authenticated and delivered upon transfer of, or in exchange for, or in lieu of other Notes, and except as further provided in the Indenture), all issued or to be issued under and pursuant to an Amended and Restated Indenture, dated as of April 9, 2001, as supplemented through and including the Supplemental Indenture dated as of June 1, 2019 (together, as amended, supplemented or modified, the “Indenture”), duly executed and delivered between the Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (herein referred to as the “Trustee”, which term includes any successor trustee under the Indenture), to which Indenture reference is hereby made for a description of the respective rights, limitations of rights, obligations, duties and immunities thereunder of the Trustee, the Company and the registered Holders of the Notes and of the terms upon which the Notes are, and are to be, authenticated and delivered.

This Note is not subject to repayment at the option of the Holder hereof. This Note is not subject to any sinking fund.

This Note will be redeemable at the option of the Company, in whole at any time or in part from time to time (any such date of optional redemption, an “Optional Redemption Date,” which shall be a “Redemption Date” for purposes of the Indenture) at the redemption prices set forth below. At any time prior to the Par Call Date (as defined below) the optional redemption price (which shall be a “Redemption Price” for purposes of the Indenture) will be equal to the greater of (i) 100% of the principal amount of this Note to be redeemed and (ii) the sum of the present values of the principal amount of this Note to be redeemed and the remaining scheduled payments of interest on the principal amount of this Note to be redeemed that would be due if this Note matured on the Par Call Date (exclusive of interest accrued to the related Optional Redemption Date), in each case discounted from their respective scheduled payment dates to such Optional Redemption Date on a semiannual basis (assuming a 360-day year consisting of 30-day months) at the Adjusted Treasury Rate (as defined below) plus 20 basis points, as determined by the Quotation Agent (as defined below), plus in either case, accrued interest thereon to the date of redemption. At any time on or after the Par Call Date, the optional redemption price will be equal to 100% of the principal amount of this bond to be redeemed plus accrued and unpaid interest thereon to the redemption date.

Notwithstanding the foregoing, installments of interest on this Note that are due and payable on Interest Payment Dates falling on or prior to a Redemption Date will be payable on the Interest Payment Date to the registered Holders as of the close of business on the relevant Record Date.

“Adjusted Treasury Rate” means, with respect to any Optional Redemption Date, the rate per annum equal to the semiannual equivalent yield to maturity of the Comparable Treasury Issue, calculated on the third Business Day preceding such Optional Redemption Date, using a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such Optional Redemption Date.

“Comparable Treasury Issue” means the United States Treasury security selected by the Quotation Agent as having a maturity comparable to the remaining term of this Note that would be utilized (assuming for this purpose that the stated maturity of this Note is the Par Call Date) at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity with the remaining term of this Note.

“Comparable Treasury Price” means, with respect to any Optional Redemption Date, (i) the average of the Reference Treasury Dealer Quotations for such Optional Redemption Date, after excluding the highest and lowest such Reference Treasury Dealer Quotations, or (ii) if the Quotation Agent obtains fewer than three such Reference Treasury Dealer Quotations, the average of all such quotations, or (iii) if only one Reference Treasury Dealer Quotation is received, such quotation.

“Par Call Date” means March 15, 2029.

“Quotation Agent” means one of the Reference Treasury Dealers appointed by the Company.

“Reference Treasury Dealer” means: (i) each of BNP Paribas Securities Corp., Citigroup Global Markets, Inc. and Mizuho Securities USA LLC (or their respective affiliates which are a primary U.S. Government securities dealer in the United States (a “Primary Treasury Dealer”), and a Primary Treasury Dealer selected by MUFG Securities Americas Inc., or their respective successors; provided, however, that if any of the foregoing cease to be a Primary Treasury Dealer, the Company shall substitute therefor another Primary Treasury Dealer; and (ii) any other Primary Treasury Dealer(s) selected by the Company.

“Reference Treasury Dealer Quotation” means, with respect to each Reference Treasury Dealer and any Optional Redemption Date, the average, as determined by the Quotation Agent, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to the Quotation Agent by such Reference Treasury Dealer at 5:00 p.m., New York City time, on the third Business Day preceding such Optional Redemption Date.

Notice of any optional redemption will be mailed at least 30 days but not more than 60 days before the Optional Redemption Date to the Holder hereof at its registered address.

If money sufficient to pay the applicable Redemption Price with respect to the principal amount of and accrued interest on the principal amount of this Note to be redeemed on the applicable Redemption Date is deposited with the Trustee or Paying Agent on or before the related Redemption Date and certain other conditions are satisfied, then on or after such Redemption Date, interest will cease to accrue on the principal amount of this Note called for redemption. If the Notes are only partially redeemed by the Company, the Trustee shall select which Notes are to be redeemed by lot or in a manner it deems fair and appropriate in accordance with the terms of the Indenture.

In the event of redemption of this Note in part only, a new Note or Notes for the unredeemed portion hereof will be issued in the name of the registered Holder hereof upon the cancellation hereof.

In case an Event of Default, as defined in the Indenture, shall have occurred and be continuing, the principal hereof may be declared, and upon such declaration shall become, due and payable, in the manner, with the effect and subject to the conditions provided in the Indenture.

The Indenture contains provisions for defeasance at any time of the entire indebtedness of this Note upon compliance by the Company with certain conditions set forth therein.

The Indenture permits, with certain exceptions as therein provided, the amendment thereof and the modification of the rights and obligations of the Company and the rights of the Holders of the Notes under the Indenture at any time by the Company and the Trustee with the consent of the Holders of a majority of the aggregate principal amount of all Notes issued under the Indenture at the time outstanding and affected thereby; provided, however, that no such amendment shall without the consent of the Holder of each Note so affected, among other things (i) change the stated maturity of the principal of, or any installment of principal of or interest on any Notes, or reduce the principal amount thereof, or reduce the rate of interest thereon, or reduce any premium payable upon the redemption thereof or (ii) reduce the percentage of Notes, the Holders of which are required to consent to any amendment or waiver or for certain other matters as set forth in the Indenture. The Indenture also contains provisions permitting (i) the registered Holders of 66 2/3% in aggregate principal amount of the Securities at the time outstanding affected thereby, on behalf of the registered Holders of the Securities, to waive compliance by the Company with certain provisions of the Indenture and (ii) the registered Holders of not less than a majority in aggregate principal amount of the Securities at the time outstanding affected thereby, on behalf of the registered Holders of the Securities, to waive certain past defaults under the Indenture and their consequences. Any such consent or waiver by the registered Holder of this Note (unless revoked as provided in the Indenture) shall be conclusive and binding upon such registered Holder and upon all future registered Holders and owners of this Note and of any Note issued in exchange hereof or in place hereof (whether by registration of transfer or otherwise), irrespective of whether or not any notation of such consent or waiver is made upon this Note.

No reference herein to the Indenture and no provision of this Note or of the Indenture shall alter or impair the obligation of the Company, which is absolute and unconditional, to pay the principal of and premium, if any, and interest on this Note at the time and place and at the rate and in the coin or currency herein prescribed.

As provided in the Indenture and subject to certain limitations therein set forth, the transfer of this Note is registrable in the Security Register of the Company, upon surrender of this Note for registration of transfer at the office or agency of the Company in any place where the principal of and any interest on this Note are payable or at such other offices or agencies as the Company may designate, duly endorsed by or accompanied by a written instrument or instruments of transfer in form satisfactory to the Company and the Security Registrar or any transfer agent duly executed by the registered Holder hereof or his or her attorney duly authorized in writing, and thereupon one or more new Notes of this series and of like tenor, of authorized denominations and for the same aggregate principal amount will be issued to the designated transferee or transferees. No service charge will be made for any such transfer, but the Company may require payment of a sum sufficient to cover any tax or other governmental charge payable in relation thereto.

Prior to due presentment for registration of transfer of this Note, the Company, the Trustee, any paying agent and any Security Registrar may deem and treat the registered Holder hereof as the absolute owner hereof (whether or not this Note shall be overdue and notwithstanding any notice of ownership or writing hereon made by anyone other than the Security Registrar) for the purpose of receiving payment of or on account of the principal hereof and interest due hereon and for all other purposes, and neither the Company nor the Trustee nor any paying agent nor any Security Registrar shall be affected by any notice to the contrary.

The Notes are issuable only in fully registered form without coupons in denominations of $1,000 and any integral multiple thereof. This Global Note is exchangeable for Notes in definitive form only under certain limited circumstances set forth in the Indenture. The Notes so issued are issuable only in registered form without coupons in denominations of $2,000 and any integral multiple of $1,000 in excess thereof. As provided in the Indenture and subject to certain limitations therein set forth, the Notes are exchangeable for a like aggregate principal amount of the Notes of a different authorized denomination, as requested by the registered Holder surrendering the same.

As set forth in, and subject to the provisions of, the Indenture, no registered owner of any Note will have any right to institute any proceeding with respect to the Indenture or for any remedy thereunder, unless (i) such registered owner shall have previously given to the Trustee written notice of a continuing Event of Default with respect to the Notes, (ii) the registered owners of not less than 25% in principal amount of the outstanding Notes shall have made written request, and offered reasonable indemnity, to the Trustee to institute such proceeding as trustee, (iii) the Trustee shall have failed to institute such proceeding within 60 days and (iv) the Trustee shall not have received from the registered owners of a majority in principal amount of the outstanding Notes a direction inconsistent with such request within such 60-day period; provided, however, that such limitations do not apply to a suit instituted by the registered owner hereof for the enforcement of payment of the principal of or premium, if any, or any interest on this Note on or after the respective due dates expressed herein.

Unless the Certificate of Authentication hereon has been executed by the Trustee or a duly appointed Authentication Agent referred to herein, this Note shall not be entitled to any benefit under the Indenture or be valid or obligatory for any purpose.

The Indenture and this Note shall be governed by and construed in accordance with the laws of the State of New York.

All terms used in this Note which are defined in the Indenture shall have the meanings assigned to them in the Indenture.

IN WITNESS WHEREOF, the Company has caused this Instrument to be duly executed.

DTE ENERGY COMPANY

By: _________________________________

Name: 

Title: 

Date: June 13, 2019

Attest:

By: _________________________________

Name: 

Title: 

CERTIFICATE OF AUTHENTICATION

This is one of the Notes described in the within mentioned Indenture.

THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A.
as Trustee

By __________________________
Authorized Signatory

Date: June 13, 2019

FOR VALUE RECEIVED, the undersigned hereby sell(s), assign(s) and transfer(s) unto

(Please insert Social Security or Other Identifying Number of Assignee)

(Please print or type name and address, including zip code of assignee)

the within Note and all rights thereunder, hereby irrevocably constituting and appointing such person attorneys to transfer the within Note on the books of the Issuer, with full power of substitution in the premises.

Dated:________________________

NOTICE: The signature of this assignment must correspond with the name as written upon the face of the within Note in every particular, without alteration or enlargement or any change whatever and NOTICE: Signature(s) must be guaranteed by a financial institution that is a member of the Securities Transfer Agents Medallion Program (“STAMP”), the Stock Exchange, Inc. Medallion Signature Program (“MSP”). When assignment is made by a guardian, trustee, executor or administrator, an officer of a corporation, or anyone in a representative capacity, proof of his or her authority to act must accompany this Note.

A-9

EX-31.165

Exhibit 31.165

FORM 10-Q CERTIFICATION

I, Gerardo Norcia, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of DTE Energy Company;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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;

c. Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d. Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a. All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b. Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/S/ GERARDO NORCIA	Date:	July 24, 2019
Gerardo Norcia President and Chief Executive Officer of DTE Energy Company

EX-31.166

Exhibit 31.166

FORM 10-Q CERTIFICATION

I, Peter B. Oleksiak, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of DTE Energy Company;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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;

c. Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d. Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a. All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b. Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/S/ PETER B. OLEKSIAK	Date:	July 24, 2019
Peter B. Oleksiak Senior Vice President and Chief Financial Officer of DTE Energy Company

EX-31.167

Exhibit 31.167

FORM 10-Q CERTIFICATION

I, Gerard M. Anderson, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of DTE Electric Company;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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;

c. Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d. Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a. All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b. Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/S/ GERARD M. ANDERSON	Date:	July 24, 2019
Gerard M. Anderson Chairman of the Board and Chief Executive Officer of DTE Electric Company

EX-31.168

Exhibit 31.168

FORM 10-Q CERTIFICATION

I, Peter B. Oleksiak, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of DTE Electric Company;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, 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;

c. Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d. Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a. All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b. Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/S/ PETER B. OLEKSIAK	Date:	July 24, 2019
Peter B. Oleksiak Senior Vice President and Chief Financial Officer of DTE Electric Company

EX-32.165

Exhibit 32.165

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of DTE Energy Company (the “Company”) for the quarter ended June 30, 2019, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Gerardo Norcia, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge and belief:

(1) the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:	July 24, 2019	/S/ GERARDO NORCIA
		Gerardo Norcia President and Chief Executive Officer of DTE Energy Company

A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.166

Exhibit 32.166

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of DTE Energy Company (the “Company”) for the quarter ended June 30, 2019, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Peter B. Oleksiak, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge and belief:

(1) the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:	July 24, 2019	/S/ PETER B. OLEKSIAK
		Peter B. Oleksiak Senior Vice President and Chief Financial Officer of DTE Energy Company

A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.167

Exhibit 32.167

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of DTE Electric Company (the “Company”) for the quarter ended June 30, 2019, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Gerard M. Anderson, certify, pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge and belief:

(1) the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:	July 24, 2019	/S/ GERARD M. ANDERSON
		Gerard M. Anderson Chairman of the Board and Chief Executive Officer of DTE Electric Company

A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.168

Exhibit 32.168

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of DTE Electric Company (the “Company”) for the quarter ended June 30, 2019, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Peter B. Oleksiak, certify, pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge and belief:

(1) the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:	July 24, 2019	/S/ PETER B. OLEKSIAK
		Peter B. Oleksiak Senior Vice President and Chief Financial Officer of DTE Electric Company

A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Document and Entity Information	6 Months Ended
	Jun. 30, 2019 shares
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2019
Document Transition Report	false
Entity File Number	1-11607
Entity Registrant Name	DTE Energy Co
Entity Incorporation, State or Country Code	MI
Entity Tax Identification Number	38-3217752
Entity Address, Address Line One	One Energy Plaza
Entity Address, City or Town	Detroit
Entity Address, State or Province	MI
Entity Address, Postal Zip Code	48226-1279
City Area Code	313
Local Phone Number	235-4000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	183,301,732
Entity Central Index Key	0000936340
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q2
Amendment Flag	false
DTE Electric
Entity File Number	1-2198
Entity Registrant Name	DTE Electric Co
Entity Incorporation, State or Country Code	MI
Entity Tax Identification Number	38-0478650
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	138,632,324
Entity Central Index Key	0000028385
Common stock, without par value
Title of 12(b) Security	Common stock, without par value
Trading Symbol	DTE
Security Exchange Name	NYSE
2012 Series C 5.25% Junior Subordinated Debentures due 2062
Title of 12(b) Security	2012 Series C 5.25% Junior Subordinated Debentures due 2062
Trading Symbol	DTQ
Security Exchange Name	NYSE
2016 Series B 5.375% Junior Subordinated Debentures due 2076
Title of 12(b) Security	2016 Series B 5.375% Junior Subordinated Debentures due 2076
Trading Symbol	DTJ
Security Exchange Name	NYSE
2016 Series F 6.00% Junior Subordinated Debentures due 2076
Title of 12(b) Security	2016 Series F 6.00% Junior Subordinated Debentures due 2076
Trading Symbol	DTY
Security Exchange Name	NYSE
2017 Series E 5.25% Junior Subordinated Debentures due 2077
Title of 12(b) Security	2017 Series E 5.25% Junior Subordinated Debentures due 2077
Trading Symbol	DTW
Security Exchange Name	NYSE
6.50% Corporate Units
Title of 12(b) Security	6.50% Corporate Units
Trading Symbol	DTV
Security Exchange Name	NYSE

XML

Consolidated Statements of Operations (Unaudited) - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Operating Revenues
Utility operations	$ 1,417	$ 1,514	$ 3,281	$ 3,254
Non-utility operations	1,471	1,645	3,121	3,658
Operating Revenues	2,888	3,159	6,402	6,912
Operating Expenses
Fuel, purchased power, and gas — utility	360	434	942	987
Fuel, purchased power, and gas — non-utility	1,258	1,443	2,643	3,216
Operation and maintenance	560	583	1,151	1,117
Depreciation and amortization	305	272	601	553
Taxes other than income	92	97	210	208
Asset (gains) losses and impairments, net	13	1	13	(2)
Operating Expenses	2,588	2,830	5,560	6,079
Operating Income	300	329	842	833
Other (Income) and Deductions
Interest expense	154	135	306	270
Interest income	(3)	(3)	(7)	(6)
Non-operating retirement benefits, net	10	9	19	18
Other income	(73)	(82)	(161)	(163)
Other expenses	12	15	23	40
Other (Income) and Deductions	100	74	180	159
Income Before Income Taxes	200	255	662	674
Income Tax Expense	21	19	75	87
Net Income	179	236	587	587
Less: Net Income (Loss) Attributable to Noncontrolling Interests	(3)	2	4	(8)
Net Income Attributable to DTE Energy Company/DTE Electric Company	$ 182	$ 234	$ 583	$ 595
Basic Earnings per Common Share
Net Income Attributable to DTE Energy Company (in dollars per share)	$ 0.99	$ 1.29	$ 3.19	$ 3.29
Diluted Earnings per Common Share
Net Income Attributable to DTE Energy Company (in dollars per share)	$ 0.99	$ 1.29	$ 3.18	$ 3.29
Weighted Average Common Shares Outstanding
Basic (in shares)	183	181	183	180
Diluted (in shares)	184	181	183	180
DTE Electric
Operating Revenues
Utility operations	$ 1,190	$ 1,276	$ 2,425	$ 2,481
Operating Expenses
Fuel, purchased power, and gas — utility	322	386	668	725
Operation and maintenance	334	345	692	665
Depreciation and amortization	229	202	450	414
Taxes other than income	69	74	153	155
Asset (gains) losses and impairments, net	13	0	13	0
Operating Expenses	967	1,007	1,976	1,959
Operating Income	223	269	449	522
Other (Income) and Deductions
Interest expense	78	69	154	137
Interest income	0	0	(1)	0
Other income	(25)	(22)	(58)	(49)
Other expenses	12	15	20	40
Other (Income) and Deductions	65	62	115	128
Income Before Income Taxes	158	207	334	394
Income Tax Expense	25	44	54	91
Net Income Attributable to DTE Energy Company/DTE Electric Company	$ 133	$ 163	$ 280	$ 303

XML

Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Net Income	$ 179	$ 236	$ 587	$ 587
Net Income	182	234	583	595
Other comprehensive income (loss), net of tax:
Benefit obligations, net of taxes of $1, $1, $2 and $2, respectively	3	3	7	5
Net unrealized losses on derivatives during the period, net of taxes of $(2), $—, $(3), and $—, respectively	(6)		(9)
Net unrealized losses on derivatives during the period, net of taxes of $(2), $—, $(3), and $—, respectively		0		0
Foreign currency translation	0	(1)	1	(1)
Other comprehensive income (loss)	(3)	2	(1)	4
Comprehensive income	176	238	586	591
Less: Comprehensive income (loss) attributable to noncontrolling interests	(3)	2	4	(8)
Comprehensive Income Attributable to DTE Energy Company/DTE Electric Company	179	236	582	599
DTE Electric
Net Income	133	163	280	303
Other comprehensive income (loss), net of tax:
Other comprehensive income (loss)	0	0	0	0
Comprehensive Income Attributable to DTE Energy Company/DTE Electric Company	$ 133	$ 163	$ 280	$ 303

XML

Consolidated Statements of Comprehensive Income (Unaudited) (Parentheticals) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Tax effect on benefit obligation	$ 1	$ 1	$ 2	$ 2
Tax effect on net unrealized losses on derivatives during the period	(2)		(3)
Tax effect on net unrealized losses on derivatives during the period		0		0
Tax effect on net unrealized gains on investments during the period	$ 0	$ 0	$ 0	$ 0

XML

Consolidated Statements of Financial Position (Unaudited) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Current Assets
Cash and cash equivalents	$ 62	$ 71
Restricted cash	0	5
Accounts receivable (less allowance for doubtful accounts)
Customer	1,436	1,789
Other	93	108
Inventories
Fuel and gas	334	406
Materials and supplies	431	405
Derivative assets	113	102
Regulatory assets	79	153
Other	178	221
Total Current Assets	2,726	3,260
Investments
Nuclear decommissioning trust funds	1,561	1,378
Investments in equity method investees	1,758	1,771
Other	247	219
Total Investments	3,566	3,368
Property
Property, plant, and equipment	32,834	31,810
Accumulated depreciation and amortization	(10,537)	(10,160)
Property, plant, and equipment, net	22,297	21,650
Other Assets
Goodwill	2,293	2,293
Regulatory assets	4,508	4,568
Intangible assets	837	849
Notes receivable	168	64
Derivative assets	46	31
Prepaid postretirement costs	83	45
Operating lease right-of-use assets	142
Other	185	160
Total Other Assets	8,262	8,010
Total Assets	36,851	36,288
Accounts payable
Accounts payable	1,051	1,329
Accrued interest	141	127
Dividends payable	346	172
Short-term borrowings	3	609
Current portion long-term debt, including finance leases	1,498	1,499
Derivative liabilities	94	67
Gas inventory equalization	45	0
Regulatory liabilities	37	126
Short-term borrowings
Operating lease liabilities	34
Other	405	509
Total Current Liabilities	3,654	4,438
Long-Term Debt (net of current portion)
Mortgage bonds, notes, and other	12,418	10,982
Junior subordinated debentures	1,146	1,145
Finance lease liabilities	5	7
Total Long-Term Debt (net of current portion)	13,569	12,134
Other Liabilities
Deferred income taxes	2,063	1,975
Regulatory liabilities	2,880	2,922
Asset retirement obligations	2,531	2,469
Unamortized investment tax credit	136	138
Derivative liabilities	68	89
Accrued pension liability	715	837
Nuclear decommissioning	231	205
Operating lease liabilities	102
Other	333	364
Total Other Liabilities	9,059	8,999
Commitments and Contingencies (Notes 5 and 12)
Equity
Common stock	4,344	4,245
Retained earnings	6,198	6,112
Accumulated other comprehensive loss	(146)	(120)
Total DTE Energy/DTE Electric Company Equity	10,396	10,237
Noncontrolling interests	173	480
Total Equity	10,569	10,717
Total Liabilities and Equity	36,851	36,288
DTE Electric
Current Assets
Cash and cash equivalents	9	18
Accounts receivable (less allowance for doubtful accounts)
Customer	715	750
Affiliates	5	11
Other	42	54
Inventories
Fuel and gas	179	171
Materials and supplies	283	279
Regulatory assets	78	148
Other	89	89
Total Current Assets	1,400	1,520
Investments
Nuclear decommissioning trust funds	1,561	1,378
Other	36	34
Total Investments	1,597	1,412
Property
Property, plant, and equipment	23,537	22,747
Accumulated depreciation and amortization	(7,574)	(7,310)
Property, plant, and equipment, net	15,963	15,437
Other Assets
Regulatory assets	3,787	3,829
Intangible assets	22	21
Prepaid postretirement costs — affiliates	189	189
Operating lease right-of-use assets	67
Other	152	121
Total Other Assets	4,217	4,160
Total Assets	23,177	22,529
Accounts payable
Affiliates	56	71
Other	421	441
Accrued interest	84	74
Current portion long-term debt, including finance leases	3	4
Regulatory liabilities	28	98
Short-term borrowings
Affiliates	295	101
Other	0	149
Operating lease liabilities	13
Other	138	139
Total Current Liabilities	1,038	1,077
Long-Term Debt (net of current portion)
Mortgage bonds, notes, and other	7,178	6,538
Finance lease liabilities	5	7
Total Long-Term Debt (net of current portion)	7,183	6,545
Other Liabilities
Deferred income taxes	2,294	2,246
Regulatory liabilities	2,140	2,171
Asset retirement obligations	2,329	2,271
Unamortized investment tax credit	135	137
Nuclear decommissioning	231	205
Accrued pension liability — affiliates	613	718
Accrued postretirement liability — affiliates	254	278
Operating lease liabilities	48
Other	86	88
Total Other Liabilities	8,130	8,114
Commitments and Contingencies (Notes 5 and 12)
Equity
Common stock	4,631	4,631
Retained earnings	2,195	2,162
Total DTE Energy/DTE Electric Company Equity	6,826	6,793
Total Liabilities and Equity	$ 23,177	$ 22,529

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Consolidated Statements of Financial Position (Unaudited) (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Allowance for doubtful accounts	$ 91	$ 91
Shareholder’s Equity
Common stock, shares authorized (in shares)	400,000,000	400,000,000
Common stock, shares issued (in shares)	183,301,732	181,925,281
Common stock, shares outstanding (in shares)	183,301,732	181,925,281
DTE Electric
Allowance for doubtful accounts	$ 47	$ 53
Shareholder’s Equity
Par value (in dollars per share)	$ 10	$ 10
Common stock, shares authorized (in shares)	400,000,000	400,000,000
Common stock, shares issued (in shares)	138,632,324	138,632,324
Common stock, shares outstanding (in shares)	138,632,324	138,632,324

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Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018
Operating Activities
Net Income	$ 587	$ 587
Net Income	583	595
Adjustments to reconcile Net Income to Net cash from operating activities:
Depreciation and amortization	601	553
Nuclear fuel amortization	30	25
Allowance for equity funds used during construction	(13)	(13)
Deferred income taxes	80	80
Equity earnings of equity method investees	(43)	(53)
Dividends from equity method investees	89	34
Asset (gains) losses and impairments, net	13	0
Changes in assets and liabilities:
Accounts receivable, net	369	20
Inventories	46	104
Prepaid postretirement benefit costs	(38)	(9)
Accounts payable	(247)	(34)
Gas inventory equalization	45	37
Accrued pension liability	(122)	(197)
Accrued postretirement liability	0	(61)
Derivative assets and liabilities	(20)	(8)
Regulatory assets and liabilities	142	230
Other current and noncurrent assets and liabilities	(152)	138
Net cash from operating activities	1,367	1,433
Investing Activities
Plant and equipment expenditures — utility	(1,294)	(1,027)
Plant and equipment expenditures — non-utility	(102)	(130)
Proceeds from sale of nuclear decommissioning trust fund assets	396	616
Investment in nuclear decommissioning trust funds	(399)	(613)
Distributions from equity method investees	5	5
Contributions to equity method investees	(38)	(233)
Notes receivable	(62)
Notes receivable		5
Other	(20)	(3)
Net cash used for investing activities	(1,514)	(1,380)
Financing Activities
Issuance of long-term debt, net of issuance costs	1,438	520
Redemption of long-term debt	0	(102)
Short-term borrowings, net	(606)	(147)
Issuance of common stock	0	6
Dividends paid on common stock	(345)	(309)
Contributions from noncontrolling interests, principally REF entities	17	22
Distributions to noncontrolling interests	(31)	(17)
Purchases of noncontrolling interest, principally SGG	(300)	0
Other	(40)	(29)
Net cash from (used for) financing activities	133	(56)
Net Decrease in Cash, Cash Equivalents, and Restricted Cash	(14)	(3)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	76	89
Cash, Cash Equivalents, and Restricted Cash at End of Period	62	86
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	270	216
DTE Electric
Operating Activities
Net Income	280	303
Adjustments to reconcile Net Income to Net cash from operating activities:
Depreciation and amortization	450	414
Nuclear fuel amortization	30	25
Allowance for equity funds used during construction	(12)	(9)
Deferred income taxes	38	91
Asset (gains) losses and impairments, net	13	0
Changes in assets and liabilities:
Accounts receivable, net	53	(86)
Inventories	(12)	24
Accounts payable	(13)	(2)
Accrued pension liability — affiliates	(105)	(182)
Accrued postretirement liability — affiliates	(24)	(47)
Regulatory assets and liabilities	137	158
Other current and noncurrent assets and liabilities	(169)	(4)
Net cash from operating activities	666	685
Investing Activities
Plant and equipment expenditures	(1,073)	(825)
Proceeds from sale of nuclear decommissioning trust fund assets	396	616
Investment in nuclear decommissioning trust funds	(399)	(613)
Notes receivable	(5)	0
Other	(19)	(4)
Net cash used for investing activities	(1,100)	(826)
Financing Activities
Issuance of long-term debt, net of issuance costs	643	520
Short-term borrowings, net — affiliate	194	(41)
Short-term borrowings, net — other	(149)	(108)
Dividends paid on common stock	(247)	(230)
Other	(16)	(7)
Net cash from (used for) financing activities	425	134
Net Decrease in Cash, Cash Equivalents, and Restricted Cash	(9)	(7)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	18	15
Cash, Cash Equivalents, and Restricted Cash at End of Period	9	8
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	$ 159	$ 117

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Consolidated Statements of Changes in Equity (Unaudited) - USD ($) $ in Millions	Total	Common Stock	Retained Earnings	Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interests	DTE Electric	DTE Electric Common Stock	DTE Electric Additional Paid-in Capital	DTE Electric Retained Earnings	DTE Electric Accumulated Other Comprehensive Income (Loss)
Beginning Balance (in shares) at Dec. 31, 2017		179,387,000					138,632,000
Beginning Balance at Dec. 31, 2017	$ 9,990	$ 3,989	$ 5,643	$ (120)	$ 478
Beginning Balance at Dec. 31, 2017						$ 6,265	$ 1,386	$ 2,920	$ 1,956	$ 3
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income						140			140
Net Income (Loss)	351		361		(10)
Dividends declared on common stock	(160)		(160)			(115)			(115)
Contribution of common stock to pension plan (in shares)		1,751,000
Contribution of common stock to pension plan	175	$ 175
Other comprehensive income (loss), net of tax	2			2
Stock-based compensation, net contributions from (distributions to) noncontrolling interests, and other (in shares)		345,000
Stock-based compensation, net contributions from (distributions to) noncontrolling interests, and other	5	$ (1)	(1)		7
Ending Balance (in shares) at Mar. 31, 2018		181,483,000					138,632,000
Ending Balance at Mar. 31, 2018	10,363	$ 4,163	5,848	(123)	475
Ending Balance at Mar. 31, 2018						6,290	$ 1,386	2,920	1,984	0
Beginning Balance (in shares) at Dec. 31, 2017		179,387,000					138,632,000
Beginning Balance at Dec. 31, 2017	9,990	$ 3,989	5,643	(120)	478
Beginning Balance at Dec. 31, 2017						6,265	$ 1,386	2,920	1,956	3
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	595					303
Net Income (Loss)	587
Other comprehensive income (loss), net of tax	4					0
Ending Balance (in shares) at Jun. 30, 2018		181,773,000					138,632,000
Ending Balance at Jun. 30, 2018	10,318	$ 4,205	5,760	(121)	474
Ending Balance at Jun. 30, 2018						6,338	$ 1,386	2,920	2,032	0
Beginning Balance (in shares) at Mar. 31, 2018		181,483,000					138,632,000
Beginning Balance at Mar. 31, 2018	10,363	$ 4,163	5,848	(123)	475
Beginning Balance at Mar. 31, 2018						6,290	$ 1,386	2,920	1,984	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	234					163			163
Net Income (Loss)	236		234		2
Dividends declared on common stock	(321)		(321)			(115)			(115)
Issuance of common stock (in shares)		160,000
Issuance of common stock	16	$ 16
Other comprehensive income (loss), net of tax	2			2		0
Stock-based compensation, net contributions from (distributions to) noncontrolling interests, and other (in shares)		130,000
Stock-based compensation, net contributions from (distributions to) noncontrolling interests, and other	22	$ 26	(1)		(3)
Ending Balance (in shares) at Jun. 30, 2018		181,773,000					138,632,000
Ending Balance at Jun. 30, 2018	$ 10,318	$ 4,205	5,760	(121)	474
Ending Balance at Jun. 30, 2018						$ 6,338	$ 1,386	2,920	2,032	$ 0
Beginning Balance (in shares) at Dec. 31, 2018	181,925,281	181,925,000				138,632,324	138,632,000
Beginning Balance at Dec. 31, 2018	$ 10,717	$ 4,245	6,112	(120)	480
Beginning Balance at Dec. 31, 2018	10,237					$ 6,793	$ 1,386	3,245	2,162
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income						147			147
Net Income (Loss)	408		401		7
Dividends declared on common stock	(173)		(173)			(124)			(124)
Contribution of common stock to pension plan (in shares)		815,000
Contribution of common stock to pension plan	100	$ 100
Other comprehensive income (loss), net of tax	2			2
Stock-based compensation, net contributions from (distributions to) noncontrolling interests, and other (in shares)		472,000
Stock-based compensation, net contributions from (distributions to) noncontrolling interests, and other	(34)	$ (21)	(1)		(12)
Ending Balance (in shares) at Mar. 31, 2019		183,212,000					138,632,000
Ending Balance at Mar. 31, 2019	$ 11,020	$ 4,324	6,364	(143)	475
Ending Balance at Mar. 31, 2019						$ 6,816	$ 1,386	3,245	2,185
Beginning Balance (in shares) at Dec. 31, 2018	181,925,281	181,925,000				138,632,324	138,632,000
Beginning Balance at Dec. 31, 2018	$ 10,717	$ 4,245	6,112	(120)	480
Beginning Balance at Dec. 31, 2018	10,237					$ 6,793	$ 1,386	3,245	2,162
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	583					280
Net Income (Loss)	587
Other comprehensive income (loss), net of tax	$ (1)					$ 0
Ending Balance (in shares) at Jun. 30, 2019	183,301,732	183,302,000				138,632,324	138,632,000
Ending Balance at Jun. 30, 2019	$ 10,569	$ 4,344	6,198	(146)	173
Ending Balance at Jun. 30, 2019	10,396					$ 6,826	$ 1,386	3,245	2,195
Beginning Balance (in shares) at Mar. 31, 2019		183,212,000					138,632,000
Beginning Balance at Mar. 31, 2019	11,020	$ 4,324	6,364	(143)	475
Beginning Balance at Mar. 31, 2019						6,816	$ 1,386	3,245	2,185
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income	182					133			133
Net Income (Loss)	179		182		(3)
Dividends declared on common stock	(347)		(347)			(123)			(123)
Other comprehensive income (loss), net of tax	(3)			(3)		$ 0
Purchase of noncontrolling interests, principally SGG	(300)	$ (3)			(297)
Stock-based compensation, net contributions from (distributions to) noncontrolling interests, and other (in shares)		90,000
Stock-based compensation, net contributions from (distributions to) noncontrolling interests, and other	$ 20	$ 23	(1)		(2)
Ending Balance (in shares) at Jun. 30, 2019	183,301,732	183,302,000				138,632,324	138,632,000
Ending Balance at Jun. 30, 2019	$ 10,569	$ 4,344	$ 6,198	$ (146)	$ 173
Ending Balance at Jun. 30, 2019	$ 10,396					$ 6,826	$ 1,386	$ 3,245	$ 2,195

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Consolidated Statements of Changes in Equity (Unaudited) (Parenthetical) - $ / shares	3 Months Ended
	Jun. 30, 2019	Mar. 31, 2019	Jun. 30, 2018	Mar. 31, 2018
Statement of Stockholders' Equity [Abstract]
Dividends declared on common stock (in dollars per share)	$ 1.89	$ 0.945	$ 1.77	$ 0.88

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Organization and Basis of Presentation

6 Months Ended

Jun. 30, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Organization and Basis of Presentation

ORGANIZATION AND BASIS OF PRESENTATION

Corporate Structure

DTE Energy owns the following businesses:

• DTE Electric is a public utility engaged in the generation, purchase, distribution, and sale of electricity to approximately 2.2 million customers in southeastern Michigan;

• DTE Gas is a public utility engaged in the purchase, storage, transportation, distribution, and sale of natural gas to approximately 1.3 million customers throughout Michigan and the sale of storage and transportation capacity; and

• Other businesses 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 MDEQ, and for DTE Energy, the CFTC.

Basis of Presentation

The Consolidated Financial Statements should be read in conjunction with the Combined Notes to Consolidated Financial Statements included in the combined DTE Energy and DTE Electric 2018 Annual Report on Form 10-K.

The accompanying Consolidated Financial Statements of the Registrants are prepared using accounting principles generally accepted in the United States of America. These accounting principles require management to use estimates and assumptions that impact reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results may differ from the Registrants' estimates.

The Consolidated Financial Statements are unaudited but, in the Registrants' opinions, include all adjustments necessary to present a fair statement of the results for the interim periods. All adjustments are of a normal recurring nature, except as otherwise disclosed in these Consolidated Financial Statements and Combined Notes to Consolidated Financial Statements. Financial results for this interim period are not necessarily indicative of results that may be expected for any other interim period or for the fiscal year ending December 31, 2019.

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 cost method is used. These Consolidated Financial Statements also reflect the Registrants' proportionate interests in certain jointly-owned utility plants. The Registrants eliminate all intercompany balances and transactions.

The Registrants evaluate whether an entity is a VIE whenever reconsideration events occur. The Registrants consolidate VIEs for which they are the primary beneficiary. If a Registrant is not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, a Registrant considers all relevant facts and circumstances, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. The Registrants perform ongoing reassessments of all VIEs to determine if the primary beneficiary status has changed.

Legal entities within DTE Energy's Power and Industrial Projects segment enter into long-term contractual arrangements with customers to supply energy-related products or services. The entities are generally designed to pass-through the commodity risk associated with these contracts to the customers, with DTE Energy retaining operational and customer default risk. These entities generally are VIEs and consolidated when DTE Energy is the primary beneficiary. In addition, DTE Energy has interests in certain VIEs through which control of all significant activities is shared with partners, and therefore are generally accounted for under the equity method.

DTE Energy currently owns an 85% interest in SGG, which owns and operates midstream natural gas assets. SGG has contracts through which certain construction risk is designed to pass-through to the customers, with DTE Energy retaining operational and customer default risk. SGG is a VIE with DTE Energy as the primary beneficiary.

The Registrants have variable interests in NEXUS, which include DTE Energy's 50% ownership interest and DTE Electric's transportation services contract. NEXUS is a joint venture which owns a 256-mile pipeline to transport Utica and Marcellus shale gas to Ohio, Michigan, and Ontario market centers. NEXUS 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 as, an operational business providing energy-related products. These entities are generally VIEs as a result of certain characteristics of the limited partnership voting rights. The ownership interests are accounted for under the equity method as the Registrants are not the primary beneficiaries.

DTE Energy has variable interests in VIEs through certain of its long-term purchase and sale contracts. DTE Electric has variable interests in VIEs through certain of its long-term purchase contracts. As of June 30, 2019, 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 June 30, 2019, the carrying amount of assets and liabilities in DTE Electric's Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase contracts are predominantly related to working capital accounts and generally represent the amounts owed by DTE Electric for the deliveries associated with the current billing cycle under the contracts. The Registrants have not provided any significant form of financial support associated with these long-term contracts. There is no significant potential exposure to loss as a result of DTE Energy's variable interests through these long-term purchase and sale contracts. In addition, there is no significant 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 12 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 12 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 June 30, 2019 and December 31, 2018. 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:

	June 30, 2019						December 31, 2018
	SGG(a)		Other		Total		SGG(a)		Other		Total
	(In millions)
ASSETS
Cash and cash equivalents	$	18	$	14	$	32	$	25	$	14	$	39
Restricted cash	—		—		—		—		5		5
Accounts receivable	10		38		48		9		37		46
Inventories	—		84		84		1		92		93
Property, plant, and equipment, net	400		40		440		395		46		441
Goodwill	25		—		25		25		—		25
Intangible assets	550		—		550		557		—		557
Other current and long-term assets	2		1		3		3		—		3
	$	1,005	$	177	$	1,182	$	1,015	$	194	$	1,209
LIABILITIES
Accounts payable and accrued current liabilities	$	5	$	25	$	30	$	3	$	31	$	34
Other current and long-term liabilities	9		9		18		9		10		19
	$	14	$	34	$	48	$	12	$	41	$	53

_____________________________________

(a)Amounts shown are 100% of SGG's assets and liabilities, of which DTE Energy owns 85% at June 30, 2019 and 55% at December 31, 2018.

Amounts for DTE Energy's non-consolidated VIEs are as follows:

	June 30, 2019		December 31, 2018
	(In millions)
Investments in equity method investees	$	1,402	$	1,425
Notes receivable	$	26	$	15
Future funding commitments	$	51	$	55

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Significant Accounting Policies

6 Months Ended

Jun. 30, 2019

Accounting Policies [Abstract]

Significant Accounting Policies

SIGNIFICANT ACCOUNTING POLICIES

Other Income

The following is a summary of DTE Energy's Other income:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions)
Income from REF entities	$	29	$	25	$	56	$	48
Equity earnings of equity method investees	20		32		43		53
Gains from equity securities	7		1		24		1
Contract services	6		12		14		32
Allowance for equity funds used during construction	6		6		13		13
Other	5		6		11		16
	$	73	$	82	$	161	$	163

The following is a summary of DTE Electric's Other income:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions)
Gains from equity securities allocated from DTE Energy	$	7	$	1	$	24	$	1
Contract services	8		13		16		33
Allowance for equity funds used during construction	6		4		12		9
Other	4		4		6		6
	$	25	$	22	$	58	$	49

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 three and six months ended June 30, 2019 and 2018, reclassifications out of Accumulated other comprehensive income (loss) not relating to the adoption of new accounting pronouncements for DTE Energy were not material.

Income Taxes

The 2019 estimated annual effective tax rates for DTE Energy and DTE Electric are 12% and 16%, respectively. These tax rates are affected by estimated annual permanent items, including AFUDC equity, production tax credits, and other flow-through items, as well as discrete items that may occur in any given period, but are not consistent from period to period.

The interim effective tax rate of the Registrants are as follows:

	Effective Tax Rate
	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
DTE Energy	11	%	7	%	11	%	13	%
DTE Electric	16	%	21	%	16	%	23	%

The 4% increase in DTE Energy's effective tax rate for the three months ended June 30, 2019 was primarily due to lower production tax credits of 7% in 2019, partially offset by the amortization of the TCJA regulatory liability of 3% in 2019. The 2% decrease in DTE Energy's effective tax rate for the six months ended June 30, 2019 was primarily due to the amortization of the TCJA regulatory liability of 3% in 2019 and the remeasurement of deferred taxes in 2018 of $21 million that impacted the effective tax rate by 3%. The decrease in the effective tax rate was partially offset by lower production tax credits of 4% in 2019.

The 5% and 7% decrease in DTE Electric's effective tax rate for the three and six months ended June 30, 2019, respectively, was primarily due to the amortization of the TCJA regulatory liability of 4% and higher production tax credits of 1% in 2019. The remeasurement of deferred taxes in 2018 of $8 million impacted the effective tax rate by 2% for the six months ended June 30, 2019.

DTE Energy's total amount of unrecognized tax benefits as of June 30, 2019 was $8 million, which if recognized, would favorably impact its effective tax rate. DTE Electric's total amount of unrecognized tax benefits as of June 30, 2019 was $10 million, which if recognized, would favorably impact its effective tax rate. The Registrants do not anticipate any material changes to the unrecognized tax benefits in the next twelve months.

DTE Electric had income tax receivables of $9 million with DTE Energy at June 30, 2019 and income tax receivables with DTE Energy of $8 million at December 31, 2018.

Unrecognized Compensation Costs

As of June 30, 2019, DTE Energy had $104 million of total unrecognized compensation cost related to non-vested stock incentive plan arrangements. That cost is expected to be recognized over a weighted-average period of 1.54 years.

Allocated Stock-Based Compensation

DTE Electric received an allocation of costs from DTE Energy associated with stock-based compensation of $11 million and $8 million for the three months ended June 30, 2019 and 2018, respectively, while such allocation was $24 million and $17 million for the six months ended June 30, 2019 and 2018, respectively.

Cash, Cash Equivalents, and Restricted Cash

Cash and cash equivalents include cash on hand, cash in banks, and temporary investments purchased with remaining maturities of three months or less. Restricted cash consists of funds held to satisfy requirements of certain debt and DTE Energy partnership operating agreements. Restricted cash designated for interest and principal payments within one year is classified as a Current Asset.

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New Accounting Pronouncements

6 Months Ended

Jun. 30, 2019

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New Accounting Pronouncements

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-of-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 11 to the Consolidated Financial Statements, "Leases."

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 from 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 replace the 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 current generally accepted accounting principles. Entities will 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 ASU is effective for the Registrants beginning after December 15, 2019, and interim periods therein. 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.

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 ASU is effective for the Registrants for fiscal years beginning after December 15, 2019, and interim periods therein. Early adoption is permitted. 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 — Changes to the Disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. The amendments in this update modify the disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. The ASU is effective for the Registrants for fiscal years ending after December 15, 2020. Early adoption is permitted. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements.

In August 2018, the FASB issued ASU No. 2018-15, Intangibles — Goodwill and Other — Internal-Use Software (Subtopic 350-40): Customer's Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That is a Service Contract. The amendments in this update align the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software (and hosting arrangements that include an internal use software license). The ASU is effective for the Registrants for fiscal years beginning after December 15, 2019, and interim periods therein. Early adoption is permitted. The Registrants anticipate adopting the ASU on its effective date. The ASU may be applied using either a retrospective or prospective approach. The Registrants are currently evaluating the transition methods and assessing the impact of this standard on their Consolidated Financial Statements.

In October 2018, the FASB issued ASU No. 2018-17, Consolidation (Topic 810): Targeted Improvements to Related Party Guidance for Variable Interest Entities. The amendments in this update modify the requirements for determining whether a decision-making fee is a variable interest 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. Early adoption is permitted. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements.

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Revenue

6 Months Ended

Jun. 30, 2019

Revenue from Contract with Customer [Abstract]

Revenue

REVENUE

Disaggregation of Revenue

The following is a summary of revenues disaggregated by segment for DTE Energy:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions)
Electric(a)
Residential	$	494	$	584	$	1,047	$	1,170
Commercial	423		446		843		875
Industrial	158		178		322		354
Other(b)	115		68		213		82
Total Electric operating revenues(c)	$	1,190	$	1,276	$	2,425	$	2,481
Gas
Gas sales	$	163	$	180	$	640	$	637
End User Transportation	42		49		122		134
Intermediate Transportation	15		11		41		29
Other(b)	23		15		85		5
Total Gas operating revenues(d)	$	243	$	255	$	888	$	805
Other segment operating revenues
Gas Storage and Pipelines(e)	$	121	$	122	$	237	$	241
Power and Industrial Projects(f)	$	402	$	538	$	790	$	1,105
Energy Trading(g)	$	1,113	$	1,164	$	2,414	$	2,662

_______________________________________

(a) Revenues under the Electric segment generally represent those of DTE Electric.

(b) Includes revenue adjustments related to various regulatory mechanisms.

(c) Includes $5 million and $4 million of other revenues outside the scope of Topic 606 for the three months ended June 30, 2019 and 2018, respectively, and $8 million and $9 million for the six months ended June 30, 2019 and 2018, respectively.

(d) Includes $1 million and $4 million under Alternative Revenue Programs for the three and six months ended June 30, 2018, respectively, and $2 million of other revenues for the three months ended June 30, 2019 and 2018 and $4 million for the six months ended June 30, 2019 and 2018, which are both outside the scope of Topic 606.

(e) Includes revenues outside the scope of Topic 606 primarily related to $2 million and $4 million of contracts accounted for as leases for the three and six months ended June 30, 2019, respectively.

(f) Includes revenues outside the scope of Topic 606 primarily related to $30 million and $28 million of contracts accounted for as leases for the three months ended June 30, 2019 and 2018, respectively, and $61 million and $56 million for the six months ended June 30, 2019 and 2018, respectively.

(g) Includes revenues outside the scope of Topic 606 primarily related to $879 million and $937 million of derivatives for the three months ended June 30, 2019 and 2018, respectively, and $1.8 billion and $2.1 billion of derivatives for the six months ended June 30, 2019 and 2018, respectively.

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	35
Revenue recognized that was included in the deferred revenue balance at the beginning of the period	(26		)
Ending Balance, June 30, 2019	$	83

The deferred revenues at DTE Energy generally represent amounts paid by or receivable from customers for which the associated performance obligation has not yet been satisfied.

Deferred revenues include amounts associated with REC performance obligations under certain wholesale full requirements power contracts. Deferred revenues associated with RECs are recognized as revenue when control of the RECs has transferred.

Other performance obligations associated with deferred revenues include providing products and services related to customer prepayments. Deferred revenues associated with these products and services are recognized when control has transferred to the customer.

The following table represents deferred revenue amounts for DTE Energy that are expected to be recognized as revenue in future periods:

	DTE Energy
	(In millions)
2019	$	48
2020	5
2021	5
2022	7
2023	3
2024 and thereafter	15
	$	83

Transaction Price Allocated to the Remaining Performance Obligations

In accordance with optional exemptions available under Topic 606, the Registrants did not disclose the value of unsatisfied performance obligations for (1) contracts with an original expected length of one year or less, (2) with the exception of fixed consideration, contracts for which revenue is recognized at the amount to which the Registrants have the right to invoice for goods provided and services performed, and (3) contracts for which variable consideration relates entirely to an unsatisfied performance obligation.

Such contracts consist of varying types of performance obligations across the segments, including the supply and delivery of energy related products and services. Contracts with variable volumes and/or variable pricing, including those with pricing provisions tied to a consumer price or other index, have also been excluded as the related consideration under the contract is variable at inception of the contract. Contract lengths vary from cancelable 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)
2019	$	111	$	5
2020	305		—
2021	249		—
2022	191		—
2023	133		—
2024 and thereafter	645		—
	$	1,634	$	5

Other Matters

The following table represents expenses recognized for estimated uncollectible accounts receivable:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions)
DTE Energy	$	24	$	31	$	53	$	56
DTE Electric	$	14	$	17	$	30	$	31

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Regulatory Matters

6 Months Ended

Jun. 30, 2019

Public Utilities, General Disclosures [Abstract]

Regulatory Matters

REGULATORY MATTERS

2018 Electric Rate Case Filing

DTE Electric filed a rate case with the MPSC on July 6, 2018 requesting an increase in base rates of $328 million based on a projected twelve-month period ending April 30, 2020. The requested increase in base rates was primarily due to an increase in net plant resulting from infrastructure investments, depreciation expense, as requested in the 2016 DTE Electric Depreciation Case Filing, and reliability improvement projects. The rate filing also requested an increase in return on equity from 10.0% 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, the MPSC issued an order approving an annual revenue increase of $125 million for services rendered on or after May 9, 2019. The 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.

2019 Electric Rate Case Filing

DTE Electric filed a rate case with the MPSC on July 8, 2019 requesting an increase in base rates of $351 million based on a projected twelve-month period ending April 30, 2021. The requested increase in base rates is primarily due to an increase in net plant resulting from infrastructure and generation investments. The rate filing also requests an increase in return on equity from 10.0% to 10.5% and includes projected changes in sales and operating and maintenance expenses. A final MPSC order in this case is expected by May 2020.

2016 DTE Electric Depreciation Case Filing

DTE Electric filed a depreciation case with 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 to increase its composite depreciation rate from 3.06% to 3.72%. The new rates are effective for service rendered on or after May 9, 2019, per the final order in DTE Electric's 2018 rate case issued on May 2, 2019.

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, DTE Electric and DTE Gas filed information 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 follow 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 and a final MPSC order in this case is expected by August 2019. DTE Electric proposed an amortization schedule for Calculation C in its general rate case filed July 6, 2018, which was approved by the MPSC in the May 2, 2019 rate order.

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Earnings Per Share

6 Months Ended

Jun. 30, 2019

Earnings Per Share [Abstract]

Earnings Per Share

EARNINGS PER SHARE

Basic earnings per share is calculated by dividing the net income, adjusted for income allocated to participating securities, by the weighted average number of common shares outstanding during the period. Diluted earnings per share reflect the dilution that would occur if any potentially dilutive instruments were exercised or converted into common shares. DTE Energy’s participating securities are restricted shares under the stock incentive program that contain rights to receive non-forfeitable dividends. Equity units, performance shares, and stock options do not receive cash dividends; as such, these awards are not considered participating securities.

The following is a reconciliation of DTE Energy's basic and diluted income per share calculation:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions, except per share amounts)
Basic Earnings per Share
Net Income Attributable to DTE Energy Company	$	182	$	234	$	583	$	595
Less: Allocation of earnings to net restricted stock awards	—		—		1		1
Net income available to common shareholders — basic	$	182	$	234	$	582	$	594
Average number of common shares outstanding — basic	183		181		183		180
Basic Earnings per Common Share	$	0.99	$	1.29	$	3.19	$	3.29
Diluted Earnings per Share
Net Income Attributable to DTE Energy Company	$	182	$	234	$	583	$	595
Less: Allocation of earnings to net restricted stock awards	—		—		1		1
Net income available to common shareholders — diluted	$	182	$	234	$	582	$	594
Average number of common shares outstanding — basic	183		181		183		180
Incremental shares attributable to:
Average dilutive equity units, performance share awards, and stock options	1		—		—		—
Average number of common shares outstanding — diluted	184		181		183		180
Diluted Earnings per Common Share(a)	$	0.99	$	1.29	$	3.18	$	3.29

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(a)

The 2016 Equity Units excluded from the calculation of diluted EPS were approximately 6.6 million for the three and six months ended June 30, 2018 as the dilutive stock price threshold was not met.

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Fair Value

6 Months Ended

Jun. 30, 2019

Fair Value Disclosures [Abstract]

Fair Value

FAIR VALUE

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable inputs. The Registrants make certain assumptions they believe that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. Credit risk of the Registrants and their counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at June 30, 2019 and December 31, 2018. The Registrants believe they use valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.

A fair value hierarchy has been established that prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. All assets and liabilities are required to be classified in their entirety based on the lowest level of input that is significant to the fair value measurement in its entirety. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. The Registrants classify fair value balances based on the fair value hierarchy defined as follows:

• Level 1 — Consists of unadjusted quoted prices in active markets for identical assets or liabilities that the Registrants have the ability to access as of the reporting date.

• Level 2 — Consists of inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.

• Level 3 — Consists of unobservable inputs for assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost-benefit constraints.

The following table presents assets and liabilities for DTE Energy measured and recorded at fair value on a recurring basis^(a):

	June 30, 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)	$	26		$	—		$	—		$	—	$	—		$	26		$	16		$	2		$	—		$	—	$	—		$	18
Nuclear decommissioning trusts
Equity securities	988			—			—			—		—			988			851			—			—			—		—			851
Fixed income securities	9			523			—			—		—			532			12			490			—			—		—			502
Private equity and other	—			—			—			32		—			32			—			—			—			20		—			20
Cash equivalents	9			—			—			—		—			9			5			—			—			—		—			5
Other investments(e)
Equity securities	128			—			—			—		—			128			110			—			—			—		—			110
Fixed income securities	75			—			—			—		—			75			69			—			—			—		—			69
Cash equivalents	4			—			—			—		—			4			4			—			—			—		—			4
Derivative assets
Commodity contracts
Natural gas	97			78			60			—		(170		)	65			199			87			63			—		(277		)	72
Electricity	—			239			81			—		(236		)	84			—			247			56			—		(252		)	51
Other	—			—			9			—		—			9			—			—			7			—		(1		)	6
Foreign currency exchange contracts	—			1			—			—		—			1			—			4			—			—		—			4
Total derivative assets	97			318			150			—		(406		)	159			199			338			126			—		(530		)	133
Total	$	1,336		$	841		$	150		$	32	$	(406	)	$	1,953		$	1,266		$	830		$	126		$	20	$	(530	)	$	1,712
Liabilities
Derivative liabilities
Commodity contracts
Natural gas	$	(119	)	$	(47	)	$	(70	)	$	—	$	170		$	(66	)	$	(197	)	$	(71	)	$	(112	)	$	—	$	272		$	(108	)
Electricity	—			(250		)	(71		)	—		240			(81		)	—			(227		)	(58		)	—		240			(45		)
Other	—			—			—			—		—			—			—			(1		)	—			—		1			—
Interest rate contracts	—			(15		)	—			—		—			(15		)	—			(3		)	—			—		—			(3		)
Total derivative liabilities	(119		)	(312		)	(141		)	—		410			(162		)	(197		)	(302		)	(170		)	—		513			(156		)
Total	$	(119	)	$	(312	)	$	(141	)	$	—	$	410		$	(162	)	$	(197	)	$	(302	)	$	(170	)	$	—	$	513		$	(156	)
Net Assets (Liabilities) at end of period	$	1,217		$	529		$	9		$	32	$	4		$	1,791		$	1,069		$	528		$	(44	)	$	20	$	(17	)	$	1,556
Assets
Current	$	122		$	249		$	104		$	—	$	(336	)	$	139		$	212		$	273		$	96		$	—	$	(461	)	$	120
Noncurrent	1,214			592			46			32		(70		)	1,814			1,054			557			30			20		(69		)	1,592
Total Assets	$	1,336		$	841		$	150		$	32	$	(406	)	$	1,953		$	1,266		$	830		$	126		$	20	$	(530	)	$	1,712
Liabilities
Current	$	(111	)	$	(251	)	$	(72	)	$	—	$	340		$	(94	)	$	(191	)	$	(251	)	$	(76	)	$	—	$	451		$	(67	)
Noncurrent	(8		)	(61		)	(69		)	—		70			(68		)	(6		)	(51		)	(94		)	—		62			(89		)
Total Liabilities	$	(119	)	$	(312	)	$	(141	)	$	—	$	410		$	(162	)	$	(197	)	$	(302	)	$	(170	)	$	—	$	513		$	(156	)
Net Assets (Liabilities) at end of period	$	1,217		$	529		$	9		$	32	$	4		$	1,791		$	1,069		$	528		$	(44	)	$	20	$	(17	)	$	1,556

_______________________________________

(a) See footnotes on following page.

_______________________________________

(b) Amounts represent assets valued at NAV as a practical expedient for fair value.

(c) Amounts represent the impact of master netting agreements that allow DTE Energy to net gain and loss positions and cash collateral held or placed with the same counterparties.

(d) At June 30, 2019, the $26 million consisted of $15 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.

The following table presents assets for DTE Electric measured and recorded at fair value on a recurring basis as of:

	June 30, 2019										December 31, 2018
	Level 1		Level 2		Level 3		Other(a)		Net Balance		Level 1		Level 2		Level 3		Other(a)		Net Balance
	(In millions)
Assets
Cash equivalents(b)	$	11	$	—	$	—	$	—	$	11	$	8	$	2	$	—	$	—	$	10
Nuclear decommissioning trusts
Equity securities	988		—		—		—		988		851		—		—		—		851
Fixed income securities	9		523		—		—		532		12		490		—		—		502
Private equity and other	—		—		—		32		32		—		—		—		20		20
Cash equivalents	9		—		—		—		9		5		—		—		—		5
Other investments
Equity securities	11		—		—		—		11		10		—		—		—		10
Derivative assets — FTRs	—		—		9		—		9		—		—		6		—		6
Total	$	1,028	$	523	$	9	$	32	$	1,592	$	886	$	492	$	6	$	20	$	1,404
Assets
Current	$	11	$	—	$	9	$	—	$	20	$	8	$	2	$	6	$	—	$	16
Noncurrent	1,017		523		—		32		1,572		878		490		—		20		1,388
Total Assets	$	1,028	$	523	$	9	$	32	$	1,592	$	886	$	492	$	6	$	20	$	1,404

_______________________________________

(a) Amounts represent assets valued at NAV as a practical expedient for fair value.

(b) At June 30, 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.

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 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 assets such as private equity investments are classified as NAV assets. 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.

Derivative Assets and Liabilities

Derivative assets and liabilities are comprised of physical and financial derivative contracts, including futures, forwards, options, and swaps that are both exchange-traded and over-the-counter traded contracts. Various inputs are used to value derivatives depending on the type of contract and availability of market data. Exchange-traded derivative contracts are valued using quoted prices in active markets. The Registrants consider the following criteria in determining whether a market is considered active: frequency in which pricing information is updated, variability in pricing between sources or over time, and the availability of public information. Other derivative contracts are valued based upon a variety of inputs including commodity market prices, broker quotes, interest rates, credit ratings, default rates, market-based seasonality, and basis differential factors. The Registrants monitor the prices that are supplied by brokers and pricing services and may use a supplemental price source or change the primary price source of an index if prices become unavailable or another price source is determined to be more representative of fair value. The Registrants have obtained an understanding of how these prices are derived. Additionally, the Registrants selectively corroborate the fair value of their transactions by comparison of market-based price sources. Mathematical valuation models are used for derivatives for which external market data is not readily observable, such as contracts which extend beyond the actively traded reporting period. The Registrants have established a Risk Management Committee whose responsibilities include directly or indirectly ensuring all valuation methods are applied in accordance with predefined policies. The development and maintenance of the Registrants' forward price curves has been assigned to DTE Energy's Risk Management Department, which is separate and distinct from the trading functions within DTE Energy.

The following table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for DTE Energy:

	Three Months Ended June 30, 2019												Three Months Ended June 30, 2018
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of March 31	$	(10	)	$	(25	)	$	2		$	(33	)	$	(10	)	$	(13	)	$	4		$	(19	)
Transfers into Level 3 from Level 2	1			—			—			1			—			—			—			—
Transfers from Level 3 into Level 2	—			—			—			—			—			—			—			—
Total gains (losses)
Included in earnings	(1		)	41			—			40			(28		)	18			1			(9		)
Recorded in Regulatory liabilities	—			—			9			9			—			—			15			15
Purchases, issuances, and settlements
Settlements	—			(6		)	(2		)	(8		)	13			(18		)	(5		)	(10		)
Net Assets (Liabilities) as of June 30	$	(10	)	$	10		$	9		$	9		$	(25	)	$	(13	)	$	15		$	(23	)
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 June 30, 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	)	$	38		$	(4	)	$	33		$	(20	)	$	4		$	(2	)	$	(18	)

	Six Months Ended June 30, 2019												Six Months Ended June 30, 2018
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of December 31	$	(49	)	$	(2	)	$	7		$	(44	)	$	(29	)	$	12		$	8		$	(9	)
Transfers into Level 3 from Level 2	—			—			—			—			—			—			—			—
Transfers from Level 3 into Level 2	—			—			—			—			(3		)	—			—			(3		)
Total gains (losses)
Included in earnings	31			10			(1		)	40			(98		)	4			1			(93		)
Recorded in Regulatory liabilities	—			—			7			7			—			—			15			15
Purchases, issuances, and settlements
Settlements	8			2			(4		)	6			105			(29		)	(9		)	67
Net Assets (Liabilities) as of June 30	$	(10	)	$	10		$	9		$	9		$	(25	)	$	(13	)	$	15		$	(23	)
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 June 30, 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	$	16		$	17		$	(5	)	$	28		$	(78	)	$	(6	)	$	(2	)	$	(86	)

The following table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for DTE Electric:

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Net Assets as of beginning of period	$	2		$	5		$	6		$	9
Change in fair value recorded in Regulatory liabilities	9			15			7			15
Purchases, issuances, and settlements
Settlements	(2		)	(5		)	(4		)	(9		)
Net Assets as of June 30	$	9		$	15		$	9		$	15
The amount of total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets held at June 30, 2019 and 2018 and reflected in DTE Electric's Consolidated Statements of Financial Position	$	9		$	15		$	9		$	15

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 three and six months ended June 30, 2019 and 2018, and there were no transfers from or into Level 3 for DTE Electric during the same periods.

The following tables present the unobservable inputs related to DTE Energy's Level 3 assets and liabilities:

	June 30, 2019
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	60	$	(70	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.33	)	—	$	5.95	/MMBtu	$	(0.08	)/MMBtu
Electricity	$	81	$	(71	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(13	)	—	$	7	/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

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 inputs listed above would have 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 result 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:

	June 30, 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(a), excluding lessor finance leases	$	153	$	—	$	—	$	153	$	40	$	—	$	—	$	40
Dividends payable	$	346	$	346	$	—	$	—	$	172	$	172	$	—	$	—
Short-term borrowings	$	3	$	—	$	3	$	—	$	609	$	—	$	609	$	—
Notes payable — Other(b), excluding lessee finance leases	$	29	$	—	$	—	$	29	$	41	$	—	$	—	$	41
Long-term debt(c)	$	15,058	$	1,989	$	12,915	$	1,385	$	13,622	$	1,796	$	10,712	$	1,317

_______________________________________

(a) Current portion included in Current Assets — Other on DTE Energy's Consolidated Statements of Financial Position.

(b) Included in Current Liabilities — Other and Other Liabilities — Other on DTE Energy's Consolidated Statements of Financial Position.

(c) Includes debt due within one year, unamortized debt discounts, and issuance costs. Excludes finance lease obligations.

The following table presents the carrying amount and fair value of financial instruments for DTE Electric:

	June 30, 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	$	10	$	—	$	—	$	10	$	6	$	—	$	—	$	6
Short-term borrowings — affiliates	$	295	$	—	$	—	$	295	$	101	$	—	$	—	$	101
Short-term borrowings — other	$	—	$	—	$	—	$	—	$	149	$	—	$	149	$	—
Notes payable — Other(b), excluding lessee finance leases	$	23	$	—	$	—	$	23	$	21	$	—	$	—	$	21
Long-term debt(c)	$	7,178	$	—	$	7,749	$	167	$	6,538	$	—	$	6,552	$	161

_______________________________________

(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.

For further fair value information on financial and derivative instruments, see Note 8 to the Consolidated Financial Statements, "Financial and Other Derivative Instruments."

Nuclear Decommissioning Trust Funds

DTE Electric has a legal obligation to decommission its nuclear power plants following the expiration of its operating licenses. This obligation is reflected as an Asset retirement obligation on DTE Electric's Consolidated Statements of Financial Position. Rates approved by the MPSC provide for the recovery of decommissioning costs of Fermi 2 and the disposal of low-level radioactive waste.

The following table summarizes DTE Electric's fair value of the nuclear decommissioning trust fund assets:

	June 30, 2019		December 31, 2018
	(In millions)
Fermi 2	$	1,553	$	1,372
Fermi 1	3		3
Low-level radioactive waste	5		3
	$	1,561	$	1,378

The costs of securities sold are determined on the basis of specific identification. The following table sets forth DTE Electric's gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds:

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Realized gains	$	17		$	19		$	28		$	42
Realized losses	$	(10	)	$	(6	)	$	(17	)	$	(15	)
Proceeds from sale of securities	$	220		$	280		$	396		$	616

Realized gains and losses from the sale of securities and unrealized gains and losses incurred by the Fermi 2 trust are recorded to the Regulatory asset and Nuclear decommissioning liability. Realized gains and losses from the sale of securities and unrealized gains and losses on the low-level radioactive waste funds are recorded to the Nuclear decommissioning liability.

The following table sets forth DTE Electric's fair value and unrealized gains and losses for the nuclear decommissioning trust funds:

	June 30, 2019							December 31, 2018
	Fair Value		Unrealized Gains		Unrealized Losses			Fair Value		Unrealized Gains		Unrealized Losses
	(In millions)
Equity securities	$	988	$	335	$	(49	)	$	851	$	235	$	(79	)
Fixed income securities	532		21		(1		)	502		7		(8		)
Private equity and other	32		—		—			20		—		—
Cash equivalents	9		—		—			5		—		—
	$	1,561	$	356	$	(50	)	$	1,378	$	242	$	(87	)

The following table summarizes the fair value of the fixed income securities held in nuclear decommissioning trust funds by contractual maturity:

	June 30, 2019
	(In millions)
Due within one year	$	17
Due after one through five years	103
Due after five through ten years	110
Due after ten years	302
	$	532

Other Securities

At June 30, 2019 and December 31, 2018, the Registrants' securities, included in Other investments on the Consolidated Statements of Financial Position, were comprised primarily of money market and equity securities. For the three months ended June 30, 2019 and 2018, gains related to equity securities were $7 million and $1 million, respectively. For the six months ended June 30, 2019, gains related to equity securities were $24 million and losses related to equity securities held at June 30, 2018 were $1 million for the Registrants. Gains or losses related to the Rabbi Trust assets are allocated from DTE Energy to DTE Electric.

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Financial and Other Derivative Instruments

6 Months Ended

Jun. 30, 2019

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Financial and Other Derivative Instruments

FINANCIAL AND OTHER DERIVATIVE INSTRUMENTS

The Registrants recognize all derivatives at their fair value as Derivative assets or liabilities on their respective Consolidated Statements of Financial Position unless they qualify for certain scope exceptions, including the normal purchases and normal sales exception. Further, derivatives that qualify and are designated for hedge accounting are classified as either hedges of a forecasted transaction or the variability of cash flows to be received or paid related to a recognized asset or liability (cash flow hedge); or as hedges of the fair value of a recognized asset or liability or of an unrecognized firm commitment (fair value hedge). For cash flow hedges, the portion of the derivative gain or loss that is effective in offsetting the change in the value of the underlying exposure is deferred in Accumulated other comprehensive income (loss) and later reclassified into earnings when the underlying transaction occurs. Gains or losses from the ineffective portion of cash flow hedges are recognized in earnings immediately. 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 coal forwards, futures, options, swaps, and foreign currency exchange contracts. Items not classified as derivatives include natural gas inventory, pipeline transportation contracts, renewable energy credits, and natural gas storage assets.

DTE Electric — DTE Electric generates, purchases, distributes, and sells electricity. DTE Electric uses forward contracts to manage changes in the price of electricity and fuel. Substantially all of these contracts meet the normal purchases and normal sales exception and are therefore accounted for under the accrual method. Other derivative contracts are MTM and recoverable through the PSCR mechanism when settled. This results in the deferral of unrealized gains and losses as Regulatory assets or liabilities until realized.

DTE Gas — DTE Gas purchases, stores, transports, distributes, and sells natural gas and sells storage and transportation capacity. DTE Gas has fixed-priced contracts for portions of its expected natural gas supply requirements through March 2022. 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.

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 June 30, 2019 provision for credit losses, DTE Energy’s exposure to counterparty nonperformance is not expected to have a material adverse effect on DTE Energy's Consolidated Financial Statements.

Derivative Activities

DTE Energy manages its MTM risk on a portfolio basis based upon the delivery period of its contracts and the individual components of the risks within each contract. Accordingly, it records and manages the energy purchase and sale obligations under its contracts in separate components based on the commodity (e.g. electricity or natural gas), the product (e.g. electricity for delivery during peak or off-peak hours), the delivery location (e.g. by region), the risk profile (e.g. forward or option), and the delivery period (e.g. by month and year). The following describes the categories of activities represented by their operating characteristics and key risks:

• Asset Optimization — Represents derivative activity associated with assets owned and contracted by DTE Energy, including forward natural gas purchases and sales, natural gas transportation, and storage capacity. Changes in the value of derivatives in this category typically economically offset changes in the value of underlying non-derivative positions, which do not qualify for fair value accounting. The difference in accounting treatment of derivatives in this category and the underlying non-derivative positions can result in significant earnings volatility.

• Marketing and Origination — Represents derivative activity transacted by originating substantially hedged positions with wholesale energy marketers, producers, end-users, utilities, retail aggregators, and alternative energy suppliers.

• Fundamentals Based Trading — Represents derivative activity transacted with the intent of taking a view, capturing market price changes, or putting capital at risk. This activity is speculative in nature as opposed to hedging an existing exposure.

• Other — Includes derivative activity at DTE Electric related to FTRs. Changes in the value of derivative contracts at DTE Electric are recorded as Derivative assets or liabilities, with an offset to Regulatory assets or liabilities as the settlement value of these contracts will be included in the PSCR mechanism when realized.

The following table presents the fair value of derivative instruments for DTE Energy:

	June 30, 2019					December 31, 2018
	Derivative Assets		Derivative Liabilities			Derivative Assets		Derivative Liabilities
	(In millions)
Derivatives designated as hedging instruments
Interest rate contracts	$	—	$	(15	)	$	—	$	(3	)
Derivatives not designated as hedging instruments
Commodity contracts
Natural gas	$	235	$	(236	)	$	349	$	(380	)
Electricity	320		(321		)	303		(285		)
Other	9		—			7		(1		)
Foreign currency exchange contracts	1		—			4		—
Total derivatives not designated as hedging instruments	$	565	$	(557	)	$	663	$	(666	)
Current	$	449	$	(434	)	$	563	$	(518	)
Noncurrent	116		(138		)	100		(151		)
Total derivatives	$	565	$	(572	)	$	663	$	(669	)

The following table presents the fair value of derivative instruments for DTE Electric:

	June 30, 2019		December 31, 2018
	(In millions)
FTRs — Other current assets	$	9	$	6
Total derivatives not designated as hedging instruments	$	9	$	6

Certain of DTE Energy's derivative positions are subject to netting arrangements which provide for offsetting of asset and liability positions as well as related cash collateral. Such netting arrangements generally do not have restrictions. Under such netting arrangements, DTE Energy offsets the fair value of derivative instruments with cash collateral received or paid for those contracts executed with the same counterparty, which reduces DTE Energy's Total Assets and Liabilities. Cash collateral is allocated between the fair value of derivative instruments and customer accounts receivable and payable with the same counterparty on a pro-rata basis to the extent there is exposure. Any cash collateral remaining, after the exposure is netted to zero, is reflected in Accounts receivable and Accounts payable as collateral paid or received, respectively.

DTE Energy also provides and receives collateral in the form of letters of credit which can be offset against net Derivative assets and liabilities as well as Accounts receivable and payable. DTE Energy had issued letters of credit of $5 million and $4 million outstanding at June 30, 2019 and December 31, 2018, respectively, which could be used to offset net Derivative liabilities. Letters of credit received from third parties which could be used to offset net Derivative assets were $2 million and $8 million at June 30, 2019 and December 31, 2018, 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:

	June 30, 2019			December 31, 2018
	(In millions)
Cash collateral netted against Derivative assets	$	—		$	(17	)
Cash collateral netted against Derivative liabilities	4			—
Cash collateral recorded in Accounts receivable(a)	12			10
Cash collateral recorded in Accounts payable(a)	(3		)	(6		)
Total net cash collateral posted (received)	$	13		$	(13	)

_______________________________________

(a) Amounts are recorded net by counterparty.

The following table presents the netting offsets of Derivative assets and liabilities for DTE Energy:

	June 30, 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	$	235		$	(170	)	$	65		$	349		$	(277	)	$	72
Electricity	320			(236		)	84			303			(252		)	51
Other	9			—			9			7			(1		)	6
Foreign currency exchange contracts	1			—			1			4			—			4
Total derivative assets	$	565		$	(406	)	$	159		$	663		$	(530	)	$	133
Derivative liabilities
Commodity contracts
Natural gas	$	(236	)	$	170		$	(66	)	$	(380	)	$	272		$	(108	)
Electricity	(321		)	240			(81		)	(285		)	240			(45		)
Other	—			—			—			(1		)	1			—
Interest rate contracts	(15		)	—			(15		)	(3		)	—			(3		)
Total derivative liabilities	$	(572	)	$	410		$	(162	)	$	(669	)	$	513		$	(156	)

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:

	June 30, 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	$	449		$	116		$	(434	)	$	(138	)	$	563		$	100		$	(518	)	$	(151	)
Counterparty netting	(336		)	(70		)	336			70			(451		)	(62		)	451			62
Collateral adjustment	—			—			4			—			(10		)	(7		)	—			—
Total derivatives as reported	$	113		$	46		$	(94	)	$	(68	)	$	102		$	31		$	(67	)	$	(89	)

The effect of derivatives not designated as hedging instruments on DTE Energy's Consolidated Statements of Operations is as follows:

	Location of Gain (Loss) Recognized in Income on Derivatives	Gain (Loss) Recognized in Income on Derivatives for the Three Months Ended June 30,						Gain (Loss) Recognized in Income on Derivatives for the Six Months Ended June 30,
		2019			2018			2019			2018
		(In millions)
Commodity contracts
Natural gas	Operating Revenues — Non-utility operations	$	24		$	(48	)	$	9		$	(158	)
Natural gas	Fuel, purchased power, and gas — non-utility	(30		)	16			40			68
Electricity	Operating Revenues — Non-utility operations	16			28			(33		)	11
Other	Operating Revenues — Non-utility operations	(1		)	2			—			1
Foreign currency exchange contracts	Operating Revenues — Non-utility operations	(2		)	2			(3		)	4
Total		$	7		$	—		$	13		$	(74	)

Revenues and energy costs related to trading contracts are presented on a net basis in DTE Energy's Consolidated Statements of Operations. Commodity derivatives used for trading purposes, and financial non-trading commodity derivatives, are accounted for using the MTM method with unrealized and realized gains and losses recorded in Operating Revenues — Non-utility operations. Non-trading physical commodity sale and purchase derivative contracts are generally accounted for using the MTM method with unrealized and realized gains and losses for sales recorded in Operating Revenues — Non-utility operations and purchases recorded in Fuel, purchased power, and gas — non-utility.

The following represents the cumulative gross volume of DTE Energy's derivative contracts outstanding as of June 30, 2019:

Commodity	Number of Units
Natural gas (MMBtu)	1,986,388,951
Electricity (MWh)	33,786,455
Foreign currency exchange (CAD)	91,380,922

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, and coal) and the provisions and maturities of the underlying transactions. As of June 30, 2019, 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 $541 million.

As of June 30, 2019, DTE Energy had $493 million of derivatives in net liability positions, for which hard triggers exist. There is $4 million of collateral that has been posted against such liabilities, including cash and letters of credit. Associated derivative net asset positions for which contractual offset exists were $395 million. The net remaining amount of $94 million is derived from the $541 million noted above.

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Long-Term Debt

6 Months Ended

Jun. 30, 2019

Debt Disclosure [Abstract]

Long-Term Debt

LONG-TERM DEBT

Debt Issuances

In 2019, 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
					$	1,450

_______________________________________

(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.

In June 2019, DTE Gas agreed to issue $140 million of 2.95% First Mortgage Bonds due October 1, 2029 and $140 million of 3.72% First Mortgage Bonds due October 1, 2049 to a group of institutional investors in a private placement transaction. The bond issuances are expected to occur in October 2019. Proceeds will be used for the repayment of short-term borrowings and for general corporate purposes.

XML

Short-Term Credit Arrangements and Borrowings

6 Months Ended

Jun. 30, 2019

Short-term Debt [Abstract]

Short-Term Credit Arrangements and Borrowings

SHORT-TERM CREDIT ARRANGEMENTS AND BORROWINGS

DTE Energy, DTE Electric, and DTE Gas have unsecured revolving credit agreements that can be used for general corporate borrowings, but are intended to provide liquidity support for each of the companies’ commercial paper programs. Borrowings under the revolvers are available at prevailing short-term interest rates. Additionally, DTE Energy has other facilities to support letter of credit issuance.

The 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 capital 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 June 30, 2019, the total funded debt to total capitalization ratios for DTE Energy, DTE Electric, and DTE Gas were 0.57 to 1, 0.51 to 1, and 0.47 to 1, respectively, and were in compliance with this financial covenant.

The availability under the facilities in place at June 30, 2019 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 September 2019	70		—		—		70
Unsecured revolving credit facility, expiring April 2024	1,500		500		300		2,300
	1,720		500		300		2,520
Amounts outstanding at June 30, 2019
Commercial paper issuances	—		—		3		3
Letters of credit	179		—		—		179
	179		—		3		182
Net availability at June 30, 2019	$	1,541	$	500	$	297	$	2,338

DTE Energy has $9 million of other outstanding letters of credit which are used for various corporate purposes and are not included in the facilities described above.

In conjunction with maintaining certain exchange traded risk management positions, DTE Energy may be required to post collateral with its clearing agent. DTE Energy has a demand financing agreement for up to $100 million with its clearing agent. The 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 allows the right of setoff with posted collateral. At June 30, 2019, the capacity under this facility was $150 million. The amount outstanding under this agreement was $107 million and $93 million at June 30, 2019 and December 31, 2018, respectively, and was fully offset by the posted collateral.

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Leases

6 Months Ended

Jun. 30, 2019

Leases [Abstract]

Leases

LEASES

Disclosures related to the six months ended June 30, 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. Prior period disclosures under Topic 840 have been provided on an annual basis. As a result, the disclosures presented under Topic 842 and Topic 840 will not be fully comparable in specific disclosure requirements or time period.

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.

The components of lease cost for DTE Energy were as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2019		2019
	(In millions)
Operating lease cost	$	10	$	21
Finance lease cost:
Amortization of right-of-use assets	2		3
Interest of lease liabilities	—		—
Total finance lease cost	2		3
Variable lease cost	1		6
Short-term lease cost	3		5
	$	16	$	35

The components of lease cost for DTE Electric were as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2019		2019
	(In millions)
Operating lease cost	$	4	$	8
Finance lease cost:
Amortization of right-of-use assets	2		3
Interest of lease liabilities	—		—
Total finance lease cost	2		3
Variable lease cost	—		—
Short-term lease cost	—		1
	$	6	$	12

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.

Other information related to leases for the six months ended June 30, 2019 were as follows:

	DTE Energy		DTE Electric
	2019		2019
	(In millions)
Supplemental Cash Flows Information
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows from finance leases	$	3	$	3
Operating cash flows from operating leases	$	19	$	7
Right-of-use assets obtained in exchange for lease obligations:
Operating leases	$	22	$	1
Weighted Average Remaining Lease Term
Operating leases	9.9 years		10.4 years
Finance leases	2.5 years		2.5 years
Weighted Average Discount Rate
Operating leases	3.8%		3.7%
Finance leases	3.1%		3.1%

The Registrants' future minimum lease payments under leases for remaining periods as of June 30, 2019 were as follows:

	DTE Energy					DTE Electric
	Operating Leases			Finance Leases		Operating Leases			Finance Leases
	(In millions)
2019	$	21		$	2	$	9		$	2
2020	32			4		12			4
2021	23			3		11			3
2022	16			—		7			—
2023	13			—		6			—
2024 and thereafter	61			—		30			—
Total future minimum lease payments	166			9		75			9
Imputed interest	(30		)	—		(14		)	—
	$	136		$	9	$	61		$	9

Finance leases reported on the Consolidated Statement of Financial Position were as follows:

	DTE Energy		DTE Electric
	June 30, 2019
	(In millions)
Right-of-use assets, within Property, plant, and equipment, net	$	9	$	9
Current lease liabilities, within Current Liabilities — Other	$	3	$	3

Topic 840 — The following disclosures are presented under Topic 840 for the year ended December 31, 2018.

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 and DTE Electric, respectively.

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

Lessor

Topic 842 — DTE Energy leases a portion of its pipeline system to the Vector Pipeline through a 20-year finance lease contract that expires in 2020, with renewal options extending for five years each. DTE Energy owns a 40% interest in the Vector Pipeline. In addition, DTE Energy has an energy services agreement that expires in 2026, of which a portion is accounted for as a finance lease.

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 3 to 24 years. Generally, the operating leases do not have renewal provisions or options to purchase the assets at the end of the lease. The operating leases generally do not have termination for convenience provisions. Termination may be allowed under specific circumstances stated in the lease contract, such as under an event of default.

Certain of the finance and operating leases have lease terms that extend to the end of the estimated economic life of the leased assets, thereby resulting in no residual value. Any remaining residual values under the finance and operating leases are expected to be recovered through rates, renewals or new lease contracts. Residual values have been determined using the estimated economic life of the leased assets. The finance and operating leases do not contain residual value guarantees.

Certain of the operating leases have both lease and non-lease components. The lease and non-lease components are allocated based upon estimated relative standalone selling prices.

A lease is deemed to exist when the Registrants have provided other parties with the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration received. The right to control is deemed to occur when the Registrants have provided other parties with the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.

DTE Energy’s lease income associated with operating leases was as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2019		2019
	(In millions)
Fixed payments	$	17	$	34
Variable payments	25		52
	$	42	$	86

DTE Energy’s minimum future rental revenues under operating leases for remaining periods as of June 30, 2019 were:

	DTE Energy
	(In millions)
2019	$	33
2020	66
2021	64
2022	22
2023	22
2024 and thereafter	216
	$	423

Depreciation expense associated with DTE Energy's property under operating leases was $5 million and $13 million for the three and six months ended June 30, 2019, respectively.

Property under operating leases for DTE Energy was as follows:

	DTE Energy
	June 30, 2019
	(In millions)
Gross property under operating leases	$	443
Accumulated amortization of property under operating leases	$	160

The components of DTE Energy’s net investment in finance leases for remaining periods were as follows:

	DTE Energy
	June 30, 2019
	(In millions)
2019	$	5
2020	9
2021	—
2022	—
2023	—
2024 and thereafter	1
Total minimum future lease receipts	15
Residual value of leased pipeline	40
Less unearned income	7
Net investment in finance lease	48
Less current portion	5
	$	43

Interest income recognized under finance leases was $1 million and $2 million for the three and six months ended June 30, 2019, respectively.

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:

	DTE Energy
	(In millions)
2019	$	66
2020	66
2021	64
2022	20
2023	20
2024 and thereafter	196
	$	432

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 expires in 2020, with renewal options extending for five years. DTE Energy owns a 40% interest in the Vector Pipeline. In addition, DTE Energy has two energy services agreements, for which a portion of are accounted for as capital leases. These agreements expire in 2019 and 2026.

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

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

Leases

LEASES

Disclosures related to the six months ended June 30, 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. Prior period disclosures under Topic 840 have been provided on an annual basis. As a result, the disclosures presented under Topic 842 and Topic 840 will not be fully comparable in specific disclosure requirements or time period.

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.

The components of lease cost for DTE Energy were as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2019		2019
	(In millions)
Operating lease cost	$	10	$	21
Finance lease cost:
Amortization of right-of-use assets	2		3
Interest of lease liabilities	—		—
Total finance lease cost	2		3
Variable lease cost	1		6
Short-term lease cost	3		5
	$	16	$	35

The components of lease cost for DTE Electric were as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2019		2019
	(In millions)
Operating lease cost	$	4	$	8
Finance lease cost:
Amortization of right-of-use assets	2		3
Interest of lease liabilities	—		—
Total finance lease cost	2		3
Variable lease cost	—		—
Short-term lease cost	—		1
	$	6	$	12

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.

Other information related to leases for the six months ended June 30, 2019 were as follows:

	DTE Energy		DTE Electric
	2019		2019
	(In millions)
Supplemental Cash Flows Information
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows from finance leases	$	3	$	3
Operating cash flows from operating leases	$	19	$	7
Right-of-use assets obtained in exchange for lease obligations:
Operating leases	$	22	$	1
Weighted Average Remaining Lease Term
Operating leases	9.9 years		10.4 years
Finance leases	2.5 years		2.5 years
Weighted Average Discount Rate
Operating leases	3.8%		3.7%
Finance leases	3.1%		3.1%

The Registrants' future minimum lease payments under leases for remaining periods as of June 30, 2019 were as follows:

	DTE Energy					DTE Electric
	Operating Leases			Finance Leases		Operating Leases			Finance Leases
	(In millions)
2019	$	21		$	2	$	9		$	2
2020	32			4		12			4
2021	23			3		11			3
2022	16			—		7			—
2023	13			—		6			—
2024 and thereafter	61			—		30			—
Total future minimum lease payments	166			9		75			9
Imputed interest	(30		)	—		(14		)	—
	$	136		$	9	$	61		$	9

Finance leases reported on the Consolidated Statement of Financial Position were as follows:

	DTE Energy		DTE Electric
	June 30, 2019
	(In millions)
Right-of-use assets, within Property, plant, and equipment, net	$	9	$	9
Current lease liabilities, within Current Liabilities — Other	$	3	$	3

Topic 840 — The following disclosures are presented under Topic 840 for the year ended December 31, 2018.

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 and DTE Electric, respectively.

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

Lessor

Topic 842 — DTE Energy leases a portion of its pipeline system to the Vector Pipeline through a 20-year finance lease contract that expires in 2020, with renewal options extending for five years each. DTE Energy owns a 40% interest in the Vector Pipeline. In addition, DTE Energy has an energy services agreement that expires in 2026, of which a portion is accounted for as a finance lease.

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 3 to 24 years. Generally, the operating leases do not have renewal provisions or options to purchase the assets at the end of the lease. The operating leases generally do not have termination for convenience provisions. Termination may be allowed under specific circumstances stated in the lease contract, such as under an event of default.

Certain of the finance and operating leases have lease terms that extend to the end of the estimated economic life of the leased assets, thereby resulting in no residual value. Any remaining residual values under the finance and operating leases are expected to be recovered through rates, renewals or new lease contracts. Residual values have been determined using the estimated economic life of the leased assets. The finance and operating leases do not contain residual value guarantees.

Certain of the operating leases have both lease and non-lease components. The lease and non-lease components are allocated based upon estimated relative standalone selling prices.

A lease is deemed to exist when the Registrants have provided other parties with the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration received. The right to control is deemed to occur when the Registrants have provided other parties with the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.

DTE Energy’s lease income associated with operating leases was as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2019		2019
	(In millions)
Fixed payments	$	17	$	34
Variable payments	25		52
	$	42	$	86

DTE Energy’s minimum future rental revenues under operating leases for remaining periods as of June 30, 2019 were:

	DTE Energy
	(In millions)
2019	$	33
2020	66
2021	64
2022	22
2023	22
2024 and thereafter	216
	$	423

Depreciation expense associated with DTE Energy's property under operating leases was $5 million and $13 million for the three and six months ended June 30, 2019, respectively.

Property under operating leases for DTE Energy was as follows:

	DTE Energy
	June 30, 2019
	(In millions)
Gross property under operating leases	$	443
Accumulated amortization of property under operating leases	$	160

The components of DTE Energy’s net investment in finance leases for remaining periods were as follows:

	DTE Energy
	June 30, 2019
	(In millions)
2019	$	5
2020	9
2021	—
2022	—
2023	—
2024 and thereafter	1
Total minimum future lease receipts	15
Residual value of leased pipeline	40
Less unearned income	7
Net investment in finance lease	48
Less current portion	5
	$	43

Interest income recognized under finance leases was $1 million and $2 million for the three and six months ended June 30, 2019, respectively.

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:

	DTE Energy
	(In millions)
2019	$	66
2020	66
2021	64
2022	20
2023	20
2024 and thereafter	196
	$	432

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 expires in 2020, with renewal options extending for five years. DTE Energy owns a 40% interest in the Vector Pipeline. In addition, DTE Energy has two energy services agreements, for which a portion of are accounted for as capital leases. These agreements expire in 2019 and 2026.

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

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

Leases

LEASES

Disclosures related to the six months ended June 30, 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. Prior period disclosures under Topic 840 have been provided on an annual basis. As a result, the disclosures presented under Topic 842 and Topic 840 will not be fully comparable in specific disclosure requirements or time period.

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.

The components of lease cost for DTE Energy were as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2019		2019
	(In millions)
Operating lease cost	$	10	$	21
Finance lease cost:
Amortization of right-of-use assets	2		3
Interest of lease liabilities	—		—
Total finance lease cost	2		3
Variable lease cost	1		6
Short-term lease cost	3		5
	$	16	$	35

The components of lease cost for DTE Electric were as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2019		2019
	(In millions)
Operating lease cost	$	4	$	8
Finance lease cost:
Amortization of right-of-use assets	2		3
Interest of lease liabilities	—		—
Total finance lease cost	2		3
Variable lease cost	—		—
Short-term lease cost	—		1
	$	6	$	12

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.

Other information related to leases for the six months ended June 30, 2019 were as follows:

	DTE Energy		DTE Electric
	2019		2019
	(In millions)
Supplemental Cash Flows Information
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows from finance leases	$	3	$	3
Operating cash flows from operating leases	$	19	$	7
Right-of-use assets obtained in exchange for lease obligations:
Operating leases	$	22	$	1
Weighted Average Remaining Lease Term
Operating leases	9.9 years		10.4 years
Finance leases	2.5 years		2.5 years
Weighted Average Discount Rate
Operating leases	3.8%		3.7%
Finance leases	3.1%		3.1%

The Registrants' future minimum lease payments under leases for remaining periods as of June 30, 2019 were as follows:

	DTE Energy					DTE Electric
	Operating Leases			Finance Leases		Operating Leases			Finance Leases
	(In millions)
2019	$	21		$	2	$	9		$	2
2020	32			4		12			4
2021	23			3		11			3
2022	16			—		7			—
2023	13			—		6			—
2024 and thereafter	61			—		30			—
Total future minimum lease payments	166			9		75			9
Imputed interest	(30		)	—		(14		)	—
	$	136		$	9	$	61		$	9

Finance leases reported on the Consolidated Statement of Financial Position were as follows:

	DTE Energy		DTE Electric
	June 30, 2019
	(In millions)
Right-of-use assets, within Property, plant, and equipment, net	$	9	$	9
Current lease liabilities, within Current Liabilities — Other	$	3	$	3

Topic 840 — The following disclosures are presented under Topic 840 for the year ended December 31, 2018.

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 and DTE Electric, respectively.

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

Lessor

Topic 842 — DTE Energy leases a portion of its pipeline system to the Vector Pipeline through a 20-year finance lease contract that expires in 2020, with renewal options extending for five years each. DTE Energy owns a 40% interest in the Vector Pipeline. In addition, DTE Energy has an energy services agreement that expires in 2026, of which a portion is accounted for as a finance lease.

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 3 to 24 years. Generally, the operating leases do not have renewal provisions or options to purchase the assets at the end of the lease. The operating leases generally do not have termination for convenience provisions. Termination may be allowed under specific circumstances stated in the lease contract, such as under an event of default.

Certain of the finance and operating leases have lease terms that extend to the end of the estimated economic life of the leased assets, thereby resulting in no residual value. Any remaining residual values under the finance and operating leases are expected to be recovered through rates, renewals or new lease contracts. Residual values have been determined using the estimated economic life of the leased assets. The finance and operating leases do not contain residual value guarantees.

Certain of the operating leases have both lease and non-lease components. The lease and non-lease components are allocated based upon estimated relative standalone selling prices.

A lease is deemed to exist when the Registrants have provided other parties with the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration received. The right to control is deemed to occur when the Registrants have provided other parties with the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.

DTE Energy’s lease income associated with operating leases was as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2019		2019
	(In millions)
Fixed payments	$	17	$	34
Variable payments	25		52
	$	42	$	86

DTE Energy’s minimum future rental revenues under operating leases for remaining periods as of June 30, 2019 were:

	DTE Energy
	(In millions)
2019	$	33
2020	66
2021	64
2022	22
2023	22
2024 and thereafter	216
	$	423

Depreciation expense associated with DTE Energy's property under operating leases was $5 million and $13 million for the three and six months ended June 30, 2019, respectively.

Property under operating leases for DTE Energy was as follows:

	DTE Energy
	June 30, 2019
	(In millions)
Gross property under operating leases	$	443
Accumulated amortization of property under operating leases	$	160

The components of DTE Energy’s net investment in finance leases for remaining periods were as follows:

	DTE Energy
	June 30, 2019
	(In millions)
2019	$	5
2020	9
2021	—
2022	—
2023	—
2024 and thereafter	1
Total minimum future lease receipts	15
Residual value of leased pipeline	40
Less unearned income	7
Net investment in finance lease	48
Less current portion	5
	$	43

Interest income recognized under finance leases was $1 million and $2 million for the three and six months ended June 30, 2019, respectively.

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:

	DTE Energy
	(In millions)
2019	$	66
2020	66
2021	64
2022	20
2023	20
2024 and thereafter	196
	$	432

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 expires in 2020, with renewal options extending for five years. DTE Energy owns a 40% interest in the Vector Pipeline. In addition, DTE Energy has two energy services agreements, for which a portion of are accounted for as capital leases. These agreements expire in 2019 and 2026.

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

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

Leases

LEASES

Disclosures related to the six months ended June 30, 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. Prior period disclosures under Topic 840 have been provided on an annual basis. As a result, the disclosures presented under Topic 842 and Topic 840 will not be fully comparable in specific disclosure requirements or time period.

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.

The components of lease cost for DTE Energy were as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2019		2019
	(In millions)
Operating lease cost	$	10	$	21
Finance lease cost:
Amortization of right-of-use assets	2		3
Interest of lease liabilities	—		—
Total finance lease cost	2		3
Variable lease cost	1		6
Short-term lease cost	3		5
	$	16	$	35

The components of lease cost for DTE Electric were as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2019		2019
	(In millions)
Operating lease cost	$	4	$	8
Finance lease cost:
Amortization of right-of-use assets	2		3
Interest of lease liabilities	—		—
Total finance lease cost	2		3
Variable lease cost	—		—
Short-term lease cost	—		1
	$	6	$	12

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.

Other information related to leases for the six months ended June 30, 2019 were as follows:

	DTE Energy		DTE Electric
	2019		2019
	(In millions)
Supplemental Cash Flows Information
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows from finance leases	$	3	$	3
Operating cash flows from operating leases	$	19	$	7
Right-of-use assets obtained in exchange for lease obligations:
Operating leases	$	22	$	1
Weighted Average Remaining Lease Term
Operating leases	9.9 years		10.4 years
Finance leases	2.5 years		2.5 years
Weighted Average Discount Rate
Operating leases	3.8%		3.7%
Finance leases	3.1%		3.1%

The Registrants' future minimum lease payments under leases for remaining periods as of June 30, 2019 were as follows:

	DTE Energy					DTE Electric
	Operating Leases			Finance Leases		Operating Leases			Finance Leases
	(In millions)
2019	$	21		$	2	$	9		$	2
2020	32			4		12			4
2021	23			3		11			3
2022	16			—		7			—
2023	13			—		6			—
2024 and thereafter	61			—		30			—
Total future minimum lease payments	166			9		75			9
Imputed interest	(30		)	—		(14		)	—
	$	136		$	9	$	61		$	9

Finance leases reported on the Consolidated Statement of Financial Position were as follows:

	DTE Energy		DTE Electric
	June 30, 2019
	(In millions)
Right-of-use assets, within Property, plant, and equipment, net	$	9	$	9
Current lease liabilities, within Current Liabilities — Other	$	3	$	3

Topic 840 — The following disclosures are presented under Topic 840 for the year ended December 31, 2018.

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 and DTE Electric, respectively.

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

Lessor

Topic 842 — DTE Energy leases a portion of its pipeline system to the Vector Pipeline through a 20-year finance lease contract that expires in 2020, with renewal options extending for five years each. DTE Energy owns a 40% interest in the Vector Pipeline. In addition, DTE Energy has an energy services agreement that expires in 2026, of which a portion is accounted for as a finance lease.

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 3 to 24 years. Generally, the operating leases do not have renewal provisions or options to purchase the assets at the end of the lease. The operating leases generally do not have termination for convenience provisions. Termination may be allowed under specific circumstances stated in the lease contract, such as under an event of default.

Certain of the finance and operating leases have lease terms that extend to the end of the estimated economic life of the leased assets, thereby resulting in no residual value. Any remaining residual values under the finance and operating leases are expected to be recovered through rates, renewals or new lease contracts. Residual values have been determined using the estimated economic life of the leased assets. The finance and operating leases do not contain residual value guarantees.

Certain of the operating leases have both lease and non-lease components. The lease and non-lease components are allocated based upon estimated relative standalone selling prices.

A lease is deemed to exist when the Registrants have provided other parties with the right to control the use of identified property, plant or equipment, as conveyed through a contract, for a certain period of time and consideration received. The right to control is deemed to occur when the Registrants have provided other parties with the right to obtain substantially all of the economic benefits of the identified assets and the right to direct the use of such assets.

DTE Energy’s lease income associated with operating leases was as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2019		2019
	(In millions)
Fixed payments	$	17	$	34
Variable payments	25		52
	$	42	$	86

DTE Energy’s minimum future rental revenues under operating leases for remaining periods as of June 30, 2019 were:

	DTE Energy
	(In millions)
2019	$	33
2020	66
2021	64
2022	22
2023	22
2024 and thereafter	216
	$	423

Depreciation expense associated with DTE Energy's property under operating leases was $5 million and $13 million for the three and six months ended June 30, 2019, respectively.

Property under operating leases for DTE Energy was as follows:

	DTE Energy
	June 30, 2019
	(In millions)
Gross property under operating leases	$	443
Accumulated amortization of property under operating leases	$	160

The components of DTE Energy’s net investment in finance leases for remaining periods were as follows:

	DTE Energy
	June 30, 2019
	(In millions)
2019	$	5
2020	9
2021	—
2022	—
2023	—
2024 and thereafter	1
Total minimum future lease receipts	15
Residual value of leased pipeline	40
Less unearned income	7
Net investment in finance lease	48
Less current portion	5
	$	43

Interest income recognized under finance leases was $1 million and $2 million for the three and six months ended June 30, 2019, respectively.

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:

	DTE Energy
	(In millions)
2019	$	66
2020	66
2021	64
2022	20
2023	20
2024 and thereafter	196
	$	432

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 expires in 2020, with renewal options extending for five years. DTE Energy owns a 40% interest in the Vector Pipeline. In addition, DTE Energy has two energy services agreements, for which a portion of are accounted for as capital leases. These agreements expire in 2019 and 2026.

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

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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Commitments and Contingencies

6 Months Ended

Jun. 30, 2019

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

COMMITMENTS AND CONTINGENCIES

Environmental

DTE Electric

Air — DTE Electric is subject to the EPA ozone and fine particulate transport and acid rain regulations that limit power plant emissions of SO₂ and NO_X. The EPA and the State of Michigan have also issued emission reduction regulations relating to ozone, fine particulate, regional haze, mercury, and other air pollution. These rules have led to controls on fossil-fueled power plants to reduce SO₂, NO_X, mercury, and other emissions. Additional rulemakings may occur over the next few years which could require additional controls for SO₂, NO_X, and other hazardous air pollutants.

The EPA proposed revised air quality standards for ground level ozone in November 2014 and specifically requested comments on the form and level of the ozone standards. The standards were finalized in October 2015. The State of Michigan recommended to the EPA in October 2016 which areas of the state are not attaining the new standard. On April 30, 2018, the EPA finalized the State of Michigan's recommended marginal non-attainment designation for southeast Michigan. The State is required to develop and implement a plan to address the southeast Michigan ozone non-attainment area by 2021. The Registrants cannot predict the financial impact of the State's plan to address the ozone non-attainment area at this time.

In July 2009, the Registrants received a NOV/FOV from the EPA alleging, among other things, that five DTE Electric power plants violated New Source Performance standards, Prevention of Significant Deterioration requirements, and operating permit requirements under the Clean Air Act. In June 2010, the EPA issued a NOV/FOV making similar allegations related to a project and outage at Unit 2 of the Monroe Power Plant. In March 2013, DTE Energy received a supplemental NOV from the EPA relating to the July 2009 NOV/FOV. The supplemental NOV alleged additional violations relating to the New Source Review provisions under the Clean Air Act, among other things.

In August 2010, the U.S. Department of Justice, at the request of the EPA, brought a civil suit in the U.S. District Court for the Eastern District of Michigan against DTE Energy and DTE Electric, related to the June 2010 NOV/FOV and the outage work performed at Unit 2 of the Monroe Power Plant. In August 2011, the U.S. District Court judge granted DTE Energy's motion for summary judgment in the civil case, dismissing the case and entering judgment in favor of DTE Energy and DTE Electric. In October 2011, the EPA filed a Notice of Appeal to the Court of Appeals for the Sixth Circuit. In March 2013, the Court of Appeals remanded the case to the U.S. District Court for review of the procedural component of the New Source Review notification requirements. In September 2013, the EPA filed a motion seeking leave to amend their complaint regarding the June 2010 NOV/FOV adding additional claims related to outage work performed at the Trenton Channel and Belle River Power Plants as well as additional claims related to work performed at the Monroe Power Plant. In March 2014, the U.S. District Court judge again granted DTE Energy's motion for summary judgment dismissing the civil case related to Monroe Unit 2. In April 2014, the U.S. District Court judge granted motions filed by the EPA and the Sierra Club to amend their New Source Review complaint adding additional claims for Monroe Units 1, 2, and 3, Belle River Units 1 and 2, and Trenton Channel Unit 9. In October 2014, the EPA and the U.S. Department of Justice filed a notice of appeal of the U.S. District Court judge's dismissal of the Monroe Unit 2 case. The amended New Source Review claims were all stayed pending resolution of the appeal by the Court of Appeals for the Sixth Circuit. On January 10, 2017, a divided panel of the Court reversed the decision of the U.S. District Court. On May 8, 2017, DTE Energy and DTE Electric filed a motion to stay the mandate pending filing of a petition for writ of certiorari with the U.S. Supreme Court. The Sixth Circuit granted the motion on May 16, 2017, staying the claims in the U.S. District Court until the U.S. Supreme Court disposes of the case. DTE Electric and DTE Energy filed a petition for writ of certiorari on July 31, 2017. On December 11, 2017, the U.S. Supreme Court denied certiorari. As a result of the Supreme Court electing not to review the matter, the case was sent back to the U.S. District Court for further proceedings and on June 14, 2018 the case was stayed pending settlement negotiations. The proceedings at the District Court remain stayed while the parties discuss potential resolution of the matter.

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 two NOVs/FOVs, DTE Electric could be required to install additional pollution control equipment at some or all of the power plants in question, implement early retirement of facilities where control equipment is not economical, engage in supplemental environmental programs, and/or pay fines. The Registrants do not expect the outcome for this matter to have a material impact on their Consolidated Financial Statements.

The EPA has implemented regulatory actions under the Clean Air Act to address emissions of GHGs from the utility sector and other sectors of the economy. Among these actions, in 2015 the EPA finalized performance standards for emissions of carbon dioxide from new and existing fossil-fuel fired EGUs. The performance standards for existing EGUs, known as the EPA Clean Power Plan, were challenged by petitioners and stayed by the U.S. Supreme Court in February 2016 pending final review by the courts. On October 10, 2017, the EPA, under a new administration, proposed to rescind the Clean Power Plan, and in August 2018, the EPA proposed revised emission guidelines for GHGs from existing EGUs. On June 19, 2019, the EPA Administrator officially repealed the Clean Power Plan and finalized its replacement, named the Affordable Clean Energy (ACE) rule. These final rules do not impact DTE Energy's revised goal to reduce carbon emissions 32% by the early 2020s, 50% by 2030, and 80% by 2040 from the 2005 carbon emissions levels.

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 spent approximately $2.4 billion through 2018. DTE Electric does not anticipate additional capital expenditures for air pollution requirements through 2025.

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) permit application process to determine the type of technology needed to reduce impacts to fish. DTE Electric has initiated the process of completing the required studies. Final compliance for the installation of any required technology will be determined by the state on a case by case, site specific basis. DTE Electric is currently evaluating the compliance options and working with the State of Michigan on evaluating whether any controls are needed. These evaluations/studies may require modifications to some existing intake structures. It is not possible to quantify the impact of this rulemaking at this time.

Contaminated and Other Sites — Prior to the construction of major interstate natural gas pipelines, gas for heating and other uses was manufactured locally from processes involving coal, coke, or oil. The facilities, which produced gas, have been designated as MGP sites. DTE Electric conducted remedial investigations at contaminated sites, including three former MGP sites. 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 June 30, 2019 and December 31, 2018, DTE Electric had $8 million and $7 million, respectively, accrued for remediation. Any change in assumptions, such as remediation techniques, nature and extent of contamination, and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect DTE Electric’s financial position and cash flows. DTE Electric believes the likelihood of a material change to the accrued amount is remote based on current knowledge of the conditions at each site.

Coal Combustion Residuals and Effluent Limitations Guidelines — A final EPA rule for the disposal of coal combustion residuals, commonly known as coal ash, became effective in October 2015, and was revised in October 2016 and July 2018. Additionally, D.C. District Court Decisions on August 21, 2018 and March 19, 2019 may affect the timing of closure of coal ash impoundments that are not lined with an engineered liner system. In 2019, the EPA is expected to affirmatively undertake rulemaking to implement the D.C. District Court's decisions that will 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. The bill provides for a CCR program to be regulated in Michigan once approval is requested and received from the EPA.

DTE Electric owns and operates three permitted engineered coal ash storage facilities to dispose of coal ash from coal-fired power plants and operates a number of smaller impoundments at its power plants. CCR obligations vary based on plant life, but include the installation of monitoring wells, compliance with groundwater standards, and the closure of landfills and basins at the end of the useful life of the associated power plant or as a basin becomes inactive. Under the current CCR rules and uncertainty regarding the D.C. District Court decision, capital costs and timing associated with the building of new CCR facilities or retirement of existing CCR facilities are being evaluated.

In November 2015, the EPA finalized the ELG Rule for the steam electric power generating industry which requires additional controls to be installed between 2018 and 2023. Compliance schedules for individual facilities and individual waste streams are determined through issuance of new National Pollutant Discharge Elimination System (NPDES) permits by the State of Michigan. The State of Michigan has issued a NPDES permit for the Belle River Power Plant establishing a compliance deadline of December 31, 2021. No new permits that would require ELG compliance have been issued for other facilities, consequently no compliance timelines have been established.

On April 12, 2017, the EPA granted a petition for reconsideration of the ELG Rule. The EPA also signed an administrative stay of the ELG Rule’s compliance deadlines for fly ash transport water, bottom ash transport water, and flue gas desulfurization (FGD) wastewater, among others. On June 6, 2017, the EPA published in the Federal Register a proposed rule (Postponement Rule) to postpone certain applicable deadlines within the 2015 ELG rule. The Postponement Rule was published on September 18, 2017. The Postponement Rule nullified the administrative stay but also extended the earliest compliance deadlines for only FGD wastewater and bottom ash transport water until November 1, 2020 in order for the EPA to propose and finalize a new ruling. The ELG compliance requirements and final deadlines for bottom ash transport water and FGD wastewater, and total ELG related compliance costs will not be known until the EPA completes its reconsideration of the ELG Rule expected by the end of 2019.

DTE Gas

Contaminated and Other Sites — DTE Gas owns or previously owned, 14 former MGP sites. Investigations have revealed contamination related to the by-products of gas manufacturing at each site. Cleanup of seven of the MGP sites is complete, and the sites are closed. DTE Gas has also completed partial closure of seven 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 June 30, 2019 and December 31, 2018, DTE Gas had $27 million and $25 million, respectively, accrued for remediation. 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 environmental costs from having a material adverse impact on DTE Gas' results of operations.

Non-utility

DTE Energy's non-utility businesses are subject to a number of environmental laws and regulations dealing with the protection of the environment from various pollutants.

In March 2019, the EPA issued a finding of violation to EES Coke, the Michigan coke battery facility that is a wholly-owned subsidiary of DTE Energy, alleging that the 2008 and 2014 permits issued by the Michigan Department of Environment, Great Lakes, and Energy (formerly known as the Michigan Department of Environmental Quality) did not comply with the Clean Air Act. DTE Energy is currently evaluating the alleged violations and cannot predict the financial impact or outcome of this matter.

Other

In 2010, the EPA finalized a new one-hour SO₂ ambient air quality standard that requires states to submit plans and associated timelines for non-attainment areas that demonstrate attainment with the new SO₂ standard in phases. Phase 1 addresses non-attainment areas designated based on ambient monitoring data. Phase 2 addresses non-attainment areas with large sources of SO₂ and modeled concentrations exceeding the National Ambient Air Quality Standards for SO₂. Phase 3 addresses smaller sources of SO₂ with modeled or monitored exceedances of the new SO₂ standard.

Michigan's Phase 1 non-attainment area includes DTE Energy facilities in southwest Detroit and areas of Wayne County. Modeling runs by the MDEQ 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 process, DTE Energy has worked with the MDEQ 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 at this time.

Michigan's Phase 2 non-attainment area includes DTE Electric facilities in St. Clair County. State implementation plan (SIP) submittal and EPA approval describing 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 the end of 2019. DTE Energy is currently working with the MDEQ to develop the required SIP. DTE Energy is unable to determine the full impact of the SIP strategy.

Synthetic Fuel Guarantees

DTE Energy discontinued the operations of its synthetic fuel production facilities throughout the United States as of December 31, 2007. DTE Energy provided certain guarantees and indemnities in conjunction with the sales of interests in its synfuel facilities. The guarantees cover potential commercial, environmental, oil price, and tax-related obligations that will survive until 90 days after expiration of all applicable statutes of limitations. DTE Energy estimates that its maximum potential liability under these guarantees at June 30, 2019 was approximately $400 million. Payment under these guarantees are 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 June 30, 2019 was $476 million. Payments under these guarantees are considered remote.

NEXUS Guarantees

NEXUS entered into certain 15-year capacity agreements for the transportation of natural gas with DTE Gas and Texas Eastern Transmission, LP, an unrelated third party. Pursuant to the terms of those agreements, in December 2016, DTE Energy executed separate guarantee agreements with DTE Gas and Texas Eastern Transmission, LP, with maximum potential payments totaling $242 million and $377 million at June 30, 2019, 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.

NEXUS also entered into 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 June 30, 2019, 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.

In conjunction with the execution of an agreement under which NEXUS agreed to purchase Generation Pipeline, LLC, in January 2019, DTE Energy executed a guarantee agreement with the sellers of Generation Pipeline. The maximum potential payment, which represents a portion of the purchase price due and payable by NEXUS at the completion of the closing of the acquisition, totals $15 million at June 30, 2019. The guarantee terminates upon any of the following events: (i) all NEXUS obligations under the purchase agreement have been paid in full; (ii) the completion of the closing, or (iii) the termination of the purchase agreement by NEXUS in accordance with its terms.

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 million at June 30, 2019. Payments under these guarantees are considered remote.

DTE Energy is 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 June 30, 2019, DTE Energy had $77 million of performance bonds outstanding. In the event that such bonds are called for nonperformance, DTE Energy would be obligated to reimburse the issuer of the performance bond. DTE Energy is 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

On July 5, 2019, DTE Energy, as lender, entered into a revolving term credit facility with Vector, as borrower, in the amount of C$70 million CAD. 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. As the agreement was entered into subsequent to June 30, 2019, there is no maximum potential liability under the line of credit at June 30, 2019. The funding of a loan under the terms of the credit facility is considered remote.

Labor Contracts

There are several bargaining units for DTE Energy subsidiaries' approximate 5,200 represented employees, including DTE Electric's approximate 2,800 represented employees. The majority of the represented employees are under contracts that expire in 2020 and 2021.

Purchase Commitments

Utility capital expenditures, expenditures for non-utility businesses, and contributions to equity method investees will be approximately $3.9 billion and $2.2 billion in 2019 for DTE Energy and DTE Electric, respectively. The Registrants have made certain commitments in connection with the estimated 2019 annual capital expenditures and contributions to equity method investees.

Bankruptcies

DTE Energy's Power and Industrial Projects segment holds ownership interests in, and operates, five generating plants that sell electric output from renewable sources under long-term power purchase agreements with PG&E. PG&E filed for Chapter 11 bankruptcy protection on January 29, 2019. As of June 30, 2019, PG&E's account is substantially current and outstanding accounts receivable from PG&E are not material. Therefore, DTE Energy determined no reserve was necessary.

As of June 30, 2019, the book value of long-lived assets used in producing electric output for sale to PG&E was approximately $103 million. The Power and Industrial Projects segment also has equity investments, including a note receivable, of approximately $73 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. There were no other new events occurring during the six months ended June 30, 2019, that would negatively impact the assumptions made within the December 31, 2018 impairment analysis. Therefore, no triggering events were identified. 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.

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 5 and 8 to the Consolidated Financial Statements, "Regulatory Matters" and "Financial and Other Derivative Instruments," respectively.

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Retirement Benefits and Trusteed Assets

6 Months Ended

Jun. 30, 2019

Defined Benefit Plan [Abstract]

Retirement Benefits and Trusteed Assets

RETIREMENT BENEFITS AND TRUSTEED ASSETS

The following tables detail the components of net periodic benefit costs (credits) for pension benefits and other postretirement benefits for DTE Energy:

	Pension Benefits						Other Postretirement Benefits
	Three Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Service cost	$	21		$	25		$	6		$	7
Interest cost	54			50			17			17
Expected return on plan assets	(81		)	(83		)	(31		)	(35		)
Amortization of:
Net actuarial loss	34			45			3			2
Prior service credit	—			—			(2		)	—
Net periodic benefit cost (credit)	$	28		$	37		$	(7	)	$	(9	)

	Pension Benefits						Other Postretirement Benefits
	Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Service cost	$	42		$	50		$	11		$	14
Interest cost	109			100			35			34
Expected return on plan assets	(162		)	(165		)	(62		)	(71		)
Amortization of:
Net actuarial loss	66			89			6			5
Prior service credit	—			—			(4		)	—
Net periodic benefit cost (credit)	$	55		$	74		$	(14	)	$	(18	)

DTE Electric participates in various plans that provide pension and other postretirement benefits for DTE Energy and its affiliates. The plans are sponsored by DTE Energy's subsidiary, DTE Energy Corporate Services, LLC. DTE Electric accounts for its participation in DTE Energy's qualified and nonqualified pension plans by applying multiemployer accounting. DTE Electric accounts for its participation in other postretirement benefit plans by applying multiple-employer accounting. Within multiemployer and multiple-employer plans, participants pool plan assets for investment purposes and to reduce the cost of plan administration. The primary difference between plan types is assets contributed in multiemployer plans can be used to provide benefits for all participating employers, while assets contributed within a multiple-employer plan are restricted for use by the contributing employer. As a result of multiemployer accounting treatment, capitalized costs associated with these plans are reflected in Property, plant, and equipment in DTE Electric's Consolidated Statements of Financial Position. The same capitalized costs are reflected as Regulatory assets and liabilities in DTE Energy's Consolidated Statements of Financial Position. In addition, the service cost and non-service cost components are presented in Operation and maintenance in DTE Electric's Consolidated Statements of Operations. The same non-service cost components are presented in Other (Income) and Deductions — Non-operating retirement benefits, net in DTE Energy's Consolidated Statements of Operations. Plan participants of all plans are solely DTE Energy and affiliate participants.

DTE Energy's subsidiaries are responsible for their share of qualified and nonqualified pension benefit costs. DTE Electric's allocated portion of pension benefit costs included in capital expenditures and operating and maintenance expense were $22 million and $30 million for the three months ended June 30, 2019 and 2018, respectively, and $45 million and $60 million for the six months ended June 30, 2019 and 2018, respectively. These amounts include recognized contractual termination benefit charges, curtailment gains, and settlement charges.

The following tables detail the components of net periodic benefit costs (credits) for other postretirement benefits for DTE Electric:

	Other Postretirement Benefits
	Three Months Ended June 30,
	2019			2018
	(In millions)
Service cost	$	4		$	5
Interest cost	14			14
Expected return on plan assets	(21		)	(25		)
Amortization of:
Net actuarial loss	1			2
Prior service credit	(3		)	—
Net periodic benefit credit	$	(5	)	$	(4	)

	Other Postretirement Benefits
	Six Months Ended June 30,
	2019			2018
	(In millions)
Service cost	$	8		$	10
Interest cost	27			27
Expected return on plan assets	(42		)	(49		)
Amortization of:
Net actuarial loss	2			4
Prior service credit	(4		)	—
Net periodic benefit credit	$	(9	)	$	(8	)

Pension and Other Postretirement Contributions

During 2019, DTE Energy contributed the following amounts of DTE Energy common stock to the DTE Energy Company Affiliates Employee Benefit Plans Master Trust:

Date	Number of Shares	Price per Share	Amount
			(In millions)
March 5, 2019	814,597	$122.76	$	100

The above contribution was made on behalf of DTE Electric, for which DTE Electric paid DTE Energy cash consideration of $100 million in March 2019. At the discretion of management and depending upon financial market conditions, DTE Energy anticipates making up to an additional $50 million in contributions to the qualified pension plans in 2019. DTE Energy does not anticipate making any contributions to the other postretirement benefit plans in 2019.

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Segment and Related Information

6 Months Ended

Jun. 30, 2019

Segment Reporting [Abstract]

Segment and Related Information

SEGMENT AND RELATED INFORMATION

DTE Energy sets strategic goals, allocates resources, and evaluates performance based on the following structure:

Electric segment consists principally of DTE Electric, which is engaged in the generation, purchase, distribution, and sale of electricity to approximately 2.2 million residential, commercial, and industrial customers in southeastern Michigan.

Gas segment consists principally of DTE Gas, which is engaged in the purchase, storage, transportation, distribution, and sale of natural gas to approximately 1.3 million residential, commercial, and industrial customers throughout Michigan and the sale of storage and transportation capacity.

Gas Storage and Pipelines is primarily engaged in services related to the gathering, transportation, and storage of natural gas.

Power and Industrial Projects is comprised primarily of projects that deliver energy and utility-type products and services to industrial, commercial, and institutional customers, produce reduced emissions fuel, and sell electricity and pipeline-quality gas from renewable energy projects.

Energy Trading consists of energy marketing and trading operations.

Corporate and Other includes various holding company activities, holds certain non-utility debt, and holds energy-related investments.

The federal income tax provisions or benefits of DTE Energy’s subsidiaries are determined on an individual company basis and recognize the tax benefit of tax credits and net operating losses, if applicable. The state and local income tax provisions of the utility subsidiaries are determined on an individual company basis and recognize the tax benefit of various tax credits and net operating losses, if applicable. The subsidiaries record federal, state, and local income taxes payable to or receivable from DTE Energy based on the federal, state, and local tax provisions of each company.

Inter-segment billing for goods and services exchanged between segments is based upon tariffed or market-based prices of the provider and primarily consists of the sale of reduced emissions fuel, power sales, and natural gas sales in the following segments:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions)
Electric	$	13	$	13	$	27	$	26
Gas	3		4		5		6
Gas Storage and Pipelines	3		14		6		22
Power and Industrial Projects	157		162		302		317
Energy Trading	5		5		12		12
Corporate and Other	—		—		1		1
	$	181	$	198	$	353	$	384

Financial data of DTE Energy's business segments follows:

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Operating Revenues — Utility operations
Electric	$	1,190		$	1,276		$	2,425		$	2,481
Gas	243			255			888			805
Operating Revenues — Non-utility operations
Gas Storage and Pipelines	121			122			237			241
Power and Industrial Projects	402			538			790			1,105
Energy Trading	1,113			1,164			2,414			2,662
Corporate and Other	—			2			1			2
Reconciliation and Eliminations	(181		)	(198		)	(353		)	(384		)
Total	$	2,888		$	3,159		$	6,402		$	6,912

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	133		$	163		$	280		$	303
Gas	8			14			159			118
Gas Storage and Pipelines	50			60			98			122
Power and Industrial Projects	29			43			55			88
Energy Trading	(6		)	(5		)	26			26
Corporate and Other	(32		)	(41		)	(35		)	(62		)
Net Income Attributable to DTE Energy Company	$	182		$	234		$	583		$	595

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Significant Accounting Policies (Policies)

6 Months Ended

Jun. 30, 2019

Accounting Policies [Abstract]

Basis of Presentation

Basis of Presentation

The Consolidated Financial Statements should be read in conjunction with the Combined Notes to Consolidated Financial Statements included in the combined DTE Energy and DTE Electric 2018 Annual Report on Form 10-K.

The accompanying Consolidated Financial Statements of the Registrants are prepared using accounting principles generally accepted in the United States of America. These accounting principles require management to use estimates and assumptions that impact reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results may differ from the Registrants' estimates.

The Consolidated Financial Statements are unaudited but, in the Registrants' opinions, include all adjustments necessary to present a fair statement of the results for the interim periods. All adjustments are of a normal recurring nature, except as otherwise disclosed in these Consolidated Financial Statements and Combined Notes to Consolidated Financial Statements. Financial results for this interim period are not necessarily indicative of results that may be expected for any other interim period or for the fiscal year ending December 31, 2019.

The information in these combined notes relates to each of the Registrants as noted in the Index of Combined Notes to Consolidated Financial Statements. However, DTE Electric does not make any representation as to information related solely to DTE Energy or the subsidiaries of DTE Energy other than itself.

Reclassification

Certain prior year balances for the Registrants were reclassified to match the current year's Consolidated Financial Statements presentation.

Principles of Consolidation

Principles of Consolidation

The Registrants consolidate all majority-owned subsidiaries and investments in entities in which they have controlling influence. Non-majority owned investments are accounted for using the equity method when the Registrants are able to significantly influence the operating policies of the investee. When the Registrants do not influence the operating policies of an investee, the cost method is used. These Consolidated Financial Statements also reflect the Registrants' proportionate interests in certain jointly-owned utility plants. The Registrants eliminate all intercompany balances and transactions.

The Registrants evaluate whether an entity is a VIE whenever reconsideration events occur. The Registrants consolidate VIEs for which they are the primary beneficiary. If a Registrant is not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, a Registrant considers all relevant facts and circumstances, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. The Registrants perform ongoing reassessments of all VIEs to determine if the primary beneficiary status has changed.

Legal entities within DTE Energy's Power and Industrial Projects segment enter into long-term contractual arrangements with customers to supply energy-related products or services. The entities are generally designed to pass-through the commodity risk associated with these contracts to the customers, with DTE Energy retaining operational and customer default risk. These entities generally are VIEs and consolidated when DTE Energy is the primary beneficiary. In addition, DTE Energy has interests in certain VIEs through which control of all significant activities is shared with partners, and therefore are generally accounted for under the equity method.

DTE Energy currently owns an 85% interest in SGG, which owns and operates midstream natural gas assets. SGG has contracts through which certain construction risk is designed to pass-through to the customers, with DTE Energy retaining operational and customer default risk. SGG is a VIE with DTE Energy as the primary beneficiary.

The Registrants have variable interests in NEXUS, which include DTE Energy's 50% ownership interest and DTE Electric's transportation services contract. NEXUS is a joint venture which owns a 256-mile pipeline to transport Utica and Marcellus shale gas to Ohio, Michigan, and Ontario market centers. NEXUS 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 as, an operational business providing energy-related products. These entities are generally VIEs as a result of certain characteristics of the limited partnership voting rights. The ownership interests are accounted for under the equity method as the Registrants are not the primary beneficiaries.

DTE Energy has variable interests in VIEs through certain of its long-term purchase and sale contracts. DTE Electric has variable interests in VIEs through certain of its long-term purchase contracts. As of June 30, 2019, 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 June 30, 2019, the carrying amount of assets and liabilities in DTE Electric's Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase contracts are predominantly related to working capital accounts and generally represent the amounts owed by DTE Electric for the deliveries associated with the current billing cycle under the contracts. The Registrants have not provided any significant form of financial support associated with these long-term contracts. There is no significant potential exposure to loss as a result of DTE Energy's variable interests through these long-term purchase and sale contracts. In addition, there is no significant 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 12 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 12 to the Consolidated Financial Statements, "Commitments and Contingencies," for further discussion of the NEXUS guarantee arrangements.

Changes in Accumulated Other Comprehensive Income (Loss)

Changes in Accumulated Other Comprehensive Income (Loss)

Comprehensive income (loss) is the change in common shareholders' equity during a period from transactions and events from non-owner sources, including Net Income. The amounts recorded to Accumulated other comprehensive income (loss) for DTE Energy include changes in benefit obligations, consisting of deferred actuarial losses and prior service costs, unrealized gains and losses from derivatives accounted for as cash flow hedges, 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 three and six months ended June 30, 2019 and 2018, reclassifications out of Accumulated other comprehensive income (loss) not relating to the adoption of new accounting pronouncements for DTE Energy were not material.

Cash, Cash Equivalents, and Restricted Cash

Cash, Cash Equivalents, and Restricted Cash

Cash and cash equivalents include cash on hand, cash in banks, and temporary investments purchased with remaining maturities of three months or less. Restricted cash consists of funds held to satisfy requirements of certain debt and DTE Energy partnership operating agreements. Restricted cash designated for interest and principal payments within one year is classified as a Current Asset.

Recently Adopted and Recently Issued 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-of-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 11 to the Consolidated Financial Statements, "Leases."

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 from 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 replace the 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 current generally accepted accounting principles. Entities will 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 ASU is effective for the Registrants beginning after December 15, 2019, and interim periods therein. 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.

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 ASU is effective for the Registrants for fiscal years beginning after December 15, 2019, and interim periods therein. Early adoption is permitted. 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 — Changes to the Disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. The amendments in this update modify the disclosure requirements for employers that sponsor defined benefit pension or other postretirement plans. The ASU is effective for the Registrants for fiscal years ending after December 15, 2020. Early adoption is permitted. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements.

In August 2018, the FASB issued ASU No. 2018-15, Intangibles — Goodwill and Other — Internal-Use Software (Subtopic 350-40): Customer's Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That is a Service Contract. The amendments in this update align the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software (and hosting arrangements that include an internal use software license). The ASU is effective for the Registrants for fiscal years beginning after December 15, 2019, and interim periods therein. Early adoption is permitted. The Registrants anticipate adopting the ASU on its effective date. The ASU may be applied using either a retrospective or prospective approach. The Registrants are currently evaluating the transition methods and assessing the impact of this standard on their Consolidated Financial Statements.

In October 2018, the FASB issued ASU No. 2018-17, Consolidation (Topic 810): Targeted Improvements to Related Party Guidance for Variable Interest Entities. The amendments in this update modify the requirements for determining whether a decision-making fee is a variable interest 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. Early adoption is permitted. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements.

Fair Value Measurement

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable inputs. The Registrants make certain assumptions they believe that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. Credit risk of the Registrants and their counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at June 30, 2019 and December 31, 2018. The Registrants believe they use valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.

A fair value hierarchy has been established that prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. All assets and liabilities are required to be classified in their entirety based on the lowest level of input that is significant to the fair value measurement in its entirety. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. The Registrants classify fair value balances based on the fair value hierarchy defined as follows:

• Level 1 — Consists of unadjusted quoted prices in active markets for identical assets or liabilities that the Registrants have the ability to access as of the reporting date.

• Level 2 — Consists of inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.

•

Level 3 — Consists of unobservable inputs for assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost-benefit constraints.

Nuclear Decommissioning Trusts and Other Investments

Nuclear Decommissioning Trusts and Other Investments

The nuclear decommissioning trusts and other investments hold debt and equity securities directly and indirectly through commingled funds. Exchange-traded debt and equity securities held directly 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 assets such as private equity investments are classified as NAV assets. 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.

Derivative Assets and Liabilities

Derivative Assets and Liabilities

Derivative assets and liabilities are comprised of physical and financial derivative contracts, including futures, forwards, options, and swaps that are both exchange-traded and over-the-counter traded contracts. Various inputs are used to value derivatives depending on the type of contract and availability of market data. Exchange-traded derivative contracts are valued using quoted prices in active markets. The Registrants consider the following criteria in determining whether a market is considered active: frequency in which pricing information is updated, variability in pricing between sources or over time, and the availability of public information. Other derivative contracts are valued based upon a variety of inputs including commodity market prices, broker quotes, interest rates, credit ratings, default rates, market-based seasonality, and basis differential factors. The Registrants monitor the prices that are supplied by brokers and pricing services and may use a supplemental price source or change the primary price source of an index if prices become unavailable or another price source is determined to be more representative of fair value. The Registrants have obtained an understanding of how these prices are derived. Additionally, the Registrants selectively corroborate the fair value of their transactions by comparison of market-based price sources. Mathematical valuation models are used for derivatives for which external market data is not readily observable, such as contracts which extend beyond the actively traded reporting period. The Registrants have established a Risk Management Committee whose responsibilities include directly or indirectly ensuring all valuation methods are applied in accordance with predefined policies. The development and maintenance of the Registrants' forward price curves has been assigned to DTE Energy's Risk Management Department, which is separate and distinct from the trading functions within DTE Energy.

Fair Value Transfer

Derivatives are transferred between levels primarily due to changes in the source data used to construct price curves as a result of changes in market liquidity. Transfers in and transfers out are reflected as if they had occurred at the beginning of the period.

Derivatives

The Registrants recognize all derivatives at their fair value as Derivative assets or liabilities on their respective Consolidated Statements of Financial Position unless they qualify for certain scope exceptions, including the normal purchases and normal sales exception. Further, derivatives that qualify and are designated for hedge accounting are classified as either hedges of a forecasted transaction or the variability of cash flows to be received or paid related to a recognized asset or liability (cash flow hedge); or as hedges of the fair value of a recognized asset or liability or of an unrecognized firm commitment (fair value hedge). For cash flow hedges, the portion of the derivative gain or loss that is effective in offsetting the change in the value of the underlying exposure is deferred in Accumulated other comprehensive income (loss) and later reclassified into earnings when the underlying transaction occurs. Gains or losses from the ineffective portion of cash flow hedges are recognized in earnings immediately. 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 coal forwards, futures, options, swaps, and foreign currency exchange contracts. Items not classified as derivatives include natural gas inventory, pipeline transportation contracts, renewable energy credits, and natural gas storage assets.

DTE Electric — DTE Electric generates, purchases, distributes, and sells electricity. DTE Electric uses forward contracts to manage changes in the price of electricity and fuel. Substantially all of these contracts meet the normal purchases and normal sales exception and are therefore accounted for under the accrual method. Other derivative contracts are MTM and recoverable through the PSCR mechanism when settled. This results in the deferral of unrealized gains and losses as Regulatory assets or liabilities until realized.

DTE Gas — DTE Gas purchases, stores, transports, distributes, and sells natural gas and sells storage and transportation capacity. DTE Gas has fixed-priced contracts for portions of its expected natural gas supply requirements through March 2022. 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.

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 June 30, 2019 provision for credit losses, DTE Energy’s exposure to counterparty nonperformance is not expected to have a material adverse effect on DTE Energy's Consolidated Financial Statements.

Derivatives, Offsetting Fair Value Amounts

Certain of DTE Energy's derivative positions are subject to netting arrangements which provide for offsetting of asset and liability positions as well as related cash collateral. Such netting arrangements generally do not have restrictions. Under such netting arrangements, DTE Energy offsets the fair value of derivative instruments with cash collateral received or paid for those contracts executed with the same counterparty, which reduces DTE Energy's Total Assets and Liabilities. Cash collateral is allocated between the fair value of derivative instruments and customer accounts receivable and payable with the same counterparty on a pro-rata basis to the extent there is exposure. Any cash collateral remaining, after the exposure is netted to zero, is reflected in Accounts receivable and Accounts payable as collateral paid or received, respectively.

DTE Energy also provides and receives collateral in the form of letters of credit which can be offset against net Derivative assets and liabilities as well as Accounts receivable and payable. DTE Energy had issued letters of credit of $5 million and $4 million outstanding at June 30, 2019 and December 31, 2018, respectively, which could be used to offset net Derivative liabilities. Letters of credit received from third parties which could be used to offset net Derivative assets were $2 million and $8 million at June 30, 2019 and December 31, 2018, respectively. Such balances of letters of credit are excluded from the tables below and are not netted with the recognized assets and liabilities in DTE Energy's Consolidated Statements of Financial Position.

For contracts with certain clearing agents, the fair value of derivative instruments is netted against realized positions with the net balance reflected as either 1) a Derivative asset or liability or 2) an Account receivable or payable. Other than certain clearing agents, Accounts receivable and Accounts payable that are subject to netting arrangements have not been offset against the fair value of Derivative assets and liabilities.

Derivatives, Methods of Accounting, Derivatives Not Designated or Qualifying as Hedges

Revenues and energy costs related to trading contracts are presented on a net basis in DTE Energy's Consolidated Statements of Operations. Commodity derivatives used for trading purposes, and financial non-trading commodity derivatives, are accounted for using the MTM method with unrealized and realized gains and losses recorded in Operating Revenues — Non-utility operations. Non-trading physical commodity sale and purchase derivative contracts are generally accounted for using the MTM method with unrealized and realized gains and losses for sales recorded in Operating Revenues — Non-utility operations and purchases recorded in Fuel, purchased power, and gas — non-utility.

Income Tax

The federal income tax provisions or benefits of DTE Energy’s subsidiaries are determined on an individual company basis and recognize the tax benefit of tax credits and net operating losses, if applicable. The state and local income tax provisions of the utility subsidiaries are determined on an individual company basis and recognize the tax benefit of various tax credits and net operating losses, if applicable. The subsidiaries record federal, state, and local income taxes payable to or receivable from DTE Energy based on the federal, state, and local tax provisions of each company.

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Organization and Basis of Presentation (Tables)

6 Months Ended

Jun. 30, 2019

Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]

Schedule of Variable Interest Entities

The following table summarizes the major Consolidated Statements of Financial Position items for consolidated VIEs as of June 30, 2019 and December 31, 2018. 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:

	June 30, 2019						December 31, 2018
	SGG(a)		Other		Total		SGG(a)		Other		Total
	(In millions)
ASSETS
Cash and cash equivalents	$	18	$	14	$	32	$	25	$	14	$	39
Restricted cash	—		—		—		—		5		5
Accounts receivable	10		38		48		9		37		46
Inventories	—		84		84		1		92		93
Property, plant, and equipment, net	400		40		440		395		46		441
Goodwill	25		—		25		25		—		25
Intangible assets	550		—		550		557		—		557
Other current and long-term assets	2		1		3		3		—		3
	$	1,005	$	177	$	1,182	$	1,015	$	194	$	1,209
LIABILITIES
Accounts payable and accrued current liabilities	$	5	$	25	$	30	$	3	$	31	$	34
Other current and long-term liabilities	9		9		18		9		10		19
	$	14	$	34	$	48	$	12	$	41	$	53

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(a)Amounts shown are 100% of SGG's assets and liabilities, of which DTE Energy owns 85% at June 30, 2019 and 55% at December 31, 2018.

Summary of Amounts for Non-Consolidated Variable Interest Entities

Amounts for DTE Energy's non-consolidated VIEs are as follows:

	June 30, 2019		December 31, 2018
	(In millions)
Investments in equity method investees	$	1,402	$	1,425
Notes receivable	$	26	$	15
Future funding commitments	$	51	$	55

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Significant Accounting Policies (Tables)

6 Months Ended

Jun. 30, 2019

Accounting Policies [Abstract]

Schedule of Other Income

The following is a summary of DTE Energy's Other income:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions)
Income from REF entities	$	29	$	25	$	56	$	48
Equity earnings of equity method investees	20		32		43		53
Gains from equity securities	7		1		24		1
Contract services	6		12		14		32
Allowance for equity funds used during construction	6		6		13		13
Other	5		6		11		16
	$	73	$	82	$	161	$	163

The following is a summary of DTE Electric's Other income:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions)
Gains from equity securities allocated from DTE Energy	$	7	$	1	$	24	$	1
Contract services	8		13		16		33
Allowance for equity funds used during construction	6		4		12		9
Other	4		4		6		6
	$	25	$	22	$	58	$	49

Schedule of Effective Tax Rate

The interim effective tax rate of the Registrants are as follows:

	Effective Tax Rate
	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
DTE Energy	11	%	7	%	11	%	13	%
DTE Electric	16	%	21	%	16	%	23	%

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Revenue (Tables)

6 Months Ended

Jun. 30, 2019

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

The following is a summary of revenues disaggregated by segment for DTE Energy:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions)
Electric(a)
Residential	$	494	$	584	$	1,047	$	1,170
Commercial	423		446		843		875
Industrial	158		178		322		354
Other(b)	115		68		213		82
Total Electric operating revenues(c)	$	1,190	$	1,276	$	2,425	$	2,481
Gas
Gas sales	$	163	$	180	$	640	$	637
End User Transportation	42		49		122		134
Intermediate Transportation	15		11		41		29
Other(b)	23		15		85		5
Total Gas operating revenues(d)	$	243	$	255	$	888	$	805
Other segment operating revenues
Gas Storage and Pipelines(e)	$	121	$	122	$	237	$	241
Power and Industrial Projects(f)	$	402	$	538	$	790	$	1,105
Energy Trading(g)	$	1,113	$	1,164	$	2,414	$	2,662

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(a) Revenues under the Electric segment generally represent those of DTE Electric.

(b) Includes revenue adjustments related to various regulatory mechanisms.

(c) Includes $5 million and $4 million of other revenues outside the scope of Topic 606 for the three months ended June 30, 2019 and 2018, respectively, and $8 million and $9 million for the six months ended June 30, 2019 and 2018, respectively.

(d) Includes $1 million and $4 million under Alternative Revenue Programs for the three and six months ended June 30, 2018, respectively, and $2 million of other revenues for the three months ended June 30, 2019 and 2018 and $4 million for the six months ended June 30, 2019 and 2018, which are both outside the scope of Topic 606.

(e) Includes revenues outside the scope of Topic 606 primarily related to $2 million and $4 million of contracts accounted for as leases for the three and six months ended June 30, 2019, respectively.

(f) Includes revenues outside the scope of Topic 606 primarily related to $30 million and $28 million of contracts accounted for as leases for the three months ended June 30, 2019 and 2018, respectively, and $61 million and $56 million for the six months ended June 30, 2019 and 2018, respectively.

(g)

Includes revenues outside the scope of Topic 606 primarily related to $879 million and $937 million of derivatives for the three months ended June 30, 2019 and 2018, respectively, and $1.8 billion and $2.1 billion of derivatives for the six months ended June 30, 2019 and 2018, respectively.

Summary of Deferred Revenue Activity

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	35
Revenue recognized that was included in the deferred revenue balance at the beginning of the period	(26		)
Ending Balance, June 30, 2019	$	83

Deferred Revenue Amounts Expected to be Recognized as Revenue in Future Periods

The following table represents deferred revenue amounts for DTE Energy that are expected to be recognized as revenue in future periods:

	DTE Energy
	(In millions)
2019	$	48
2020	5
2021	5
2022	7
2023	3
2024 and thereafter	15
	$	83

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)
2019	$	111	$	5
2020	305		—
2021	249		—
2022	191		—
2023	133		—
2024 and thereafter	645		—
	$	1,634	$	5

Schedule of Expenses Recognized for Estimated Uncollectible Accounts Receivable

The following table represents expenses recognized for estimated uncollectible accounts receivable:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions)
DTE Energy	$	24	$	31	$	53	$	56
DTE Electric	$	14	$	17	$	30	$	31

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Earnings Per Share (Tables)

6 Months Ended

Jun. 30, 2019

Earnings Per Share [Abstract]

Schedule of Earnings Per Share, Basic and Diluted

The following is a reconciliation of DTE Energy's basic and diluted income per share calculation:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions, except per share amounts)
Basic Earnings per Share
Net Income Attributable to DTE Energy Company	$	182	$	234	$	583	$	595
Less: Allocation of earnings to net restricted stock awards	—		—		1		1
Net income available to common shareholders — basic	$	182	$	234	$	582	$	594
Average number of common shares outstanding — basic	183		181		183		180
Basic Earnings per Common Share	$	0.99	$	1.29	$	3.19	$	3.29
Diluted Earnings per Share
Net Income Attributable to DTE Energy Company	$	182	$	234	$	583	$	595
Less: Allocation of earnings to net restricted stock awards	—		—		1		1
Net income available to common shareholders — diluted	$	182	$	234	$	582	$	594
Average number of common shares outstanding — basic	183		181		183		180
Incremental shares attributable to:
Average dilutive equity units, performance share awards, and stock options	1		—		—		—
Average number of common shares outstanding — diluted	184		181		183		180
Diluted Earnings per Common Share(a)	$	0.99	$	1.29	$	3.18	$	3.29

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(a)

The 2016 Equity Units excluded from the calculation of diluted EPS were approximately 6.6 million for the three and six months ended June 30, 2018 as the dilutive stock price threshold was not met.

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Fair Value (Tables)

6 Months Ended

Jun. 30, 2019

Fair Value Disclosures [Abstract]

Assets and Liabilities Measured and Recorded at Fair Value on a Recurring Basis

The following table presents assets and liabilities for DTE Energy measured and recorded at fair value on a recurring basis^(a):

	June 30, 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)	$	26		$	—		$	—		$	—	$	—		$	26		$	16		$	2		$	—		$	—	$	—		$	18
Nuclear decommissioning trusts
Equity securities	988			—			—			—		—			988			851			—			—			—		—			851
Fixed income securities	9			523			—			—		—			532			12			490			—			—		—			502
Private equity and other	—			—			—			32		—			32			—			—			—			20		—			20
Cash equivalents	9			—			—			—		—			9			5			—			—			—		—			5
Other investments(e)
Equity securities	128			—			—			—		—			128			110			—			—			—		—			110
Fixed income securities	75			—			—			—		—			75			69			—			—			—		—			69
Cash equivalents	4			—			—			—		—			4			4			—			—			—		—			4
Derivative assets
Commodity contracts
Natural gas	97			78			60			—		(170		)	65			199			87			63			—		(277		)	72
Electricity	—			239			81			—		(236		)	84			—			247			56			—		(252		)	51
Other	—			—			9			—		—			9			—			—			7			—		(1		)	6
Foreign currency exchange contracts	—			1			—			—		—			1			—			4			—			—		—			4
Total derivative assets	97			318			150			—		(406		)	159			199			338			126			—		(530		)	133
Total	$	1,336		$	841		$	150		$	32	$	(406	)	$	1,953		$	1,266		$	830		$	126		$	20	$	(530	)	$	1,712
Liabilities
Derivative liabilities
Commodity contracts
Natural gas	$	(119	)	$	(47	)	$	(70	)	$	—	$	170		$	(66	)	$	(197	)	$	(71	)	$	(112	)	$	—	$	272		$	(108	)
Electricity	—			(250		)	(71		)	—		240			(81		)	—			(227		)	(58		)	—		240			(45		)
Other	—			—			—			—		—			—			—			(1		)	—			—		1			—
Interest rate contracts	—			(15		)	—			—		—			(15		)	—			(3		)	—			—		—			(3		)
Total derivative liabilities	(119		)	(312		)	(141		)	—		410			(162		)	(197		)	(302		)	(170		)	—		513			(156		)
Total	$	(119	)	$	(312	)	$	(141	)	$	—	$	410		$	(162	)	$	(197	)	$	(302	)	$	(170	)	$	—	$	513		$	(156	)
Net Assets (Liabilities) at end of period	$	1,217		$	529		$	9		$	32	$	4		$	1,791		$	1,069		$	528		$	(44	)	$	20	$	(17	)	$	1,556
Assets
Current	$	122		$	249		$	104		$	—	$	(336	)	$	139		$	212		$	273		$	96		$	—	$	(461	)	$	120
Noncurrent	1,214			592			46			32		(70		)	1,814			1,054			557			30			20		(69		)	1,592
Total Assets	$	1,336		$	841		$	150		$	32	$	(406	)	$	1,953		$	1,266		$	830		$	126		$	20	$	(530	)	$	1,712
Liabilities
Current	$	(111	)	$	(251	)	$	(72	)	$	—	$	340		$	(94	)	$	(191	)	$	(251	)	$	(76	)	$	—	$	451		$	(67	)
Noncurrent	(8		)	(61		)	(69		)	—		70			(68		)	(6		)	(51		)	(94		)	—		62			(89		)
Total Liabilities	$	(119	)	$	(312	)	$	(141	)	$	—	$	410		$	(162	)	$	(197	)	$	(302	)	$	(170	)	$	—	$	513		$	(156	)
Net Assets (Liabilities) at end of period	$	1,217		$	529		$	9		$	32	$	4		$	1,791		$	1,069		$	528		$	(44	)	$	20	$	(17	)	$	1,556

_______________________________________

(a) See footnotes on following page.

_______________________________________

(b) Amounts represent assets valued at NAV as a practical expedient for fair value.

(c) Amounts represent the impact of master netting agreements that allow DTE Energy to net gain and loss positions and cash collateral held or placed with the same counterparties.

(d) At June 30, 2019, the $26 million consisted of $15 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.

The following table presents assets for DTE Electric measured and recorded at fair value on a recurring basis as of:

	June 30, 2019										December 31, 2018
	Level 1		Level 2		Level 3		Other(a)		Net Balance		Level 1		Level 2		Level 3		Other(a)		Net Balance
	(In millions)
Assets
Cash equivalents(b)	$	11	$	—	$	—	$	—	$	11	$	8	$	2	$	—	$	—	$	10
Nuclear decommissioning trusts
Equity securities	988		—		—		—		988		851		—		—		—		851
Fixed income securities	9		523		—		—		532		12		490		—		—		502
Private equity and other	—		—		—		32		32		—		—		—		20		20
Cash equivalents	9		—		—		—		9		5		—		—		—		5
Other investments
Equity securities	11		—		—		—		11		10		—		—		—		10
Derivative assets — FTRs	—		—		9		—		9		—		—		6		—		6
Total	$	1,028	$	523	$	9	$	32	$	1,592	$	886	$	492	$	6	$	20	$	1,404
Assets
Current	$	11	$	—	$	9	$	—	$	20	$	8	$	2	$	6	$	—	$	16
Noncurrent	1,017		523		—		32		1,572		878		490		—		20		1,388
Total Assets	$	1,028	$	523	$	9	$	32	$	1,592	$	886	$	492	$	6	$	20	$	1,404

_______________________________________

(a) Amounts represent assets valued at NAV as a practical expedient for fair value.

(b)

At June 30, 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.

Reconciliation of Level 3 Assets and Liabilities Measured at Fair Value on a Recurring Basis

The following table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for DTE Energy:

	Three Months Ended June 30, 2019												Three Months Ended June 30, 2018
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of March 31	$	(10	)	$	(25	)	$	2		$	(33	)	$	(10	)	$	(13	)	$	4		$	(19	)
Transfers into Level 3 from Level 2	1			—			—			1			—			—			—			—
Transfers from Level 3 into Level 2	—			—			—			—			—			—			—			—
Total gains (losses)
Included in earnings	(1		)	41			—			40			(28		)	18			1			(9		)
Recorded in Regulatory liabilities	—			—			9			9			—			—			15			15
Purchases, issuances, and settlements
Settlements	—			(6		)	(2		)	(8		)	13			(18		)	(5		)	(10		)
Net Assets (Liabilities) as of June 30	$	(10	)	$	10		$	9		$	9		$	(25	)	$	(13	)	$	15		$	(23	)
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 June 30, 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	)	$	38		$	(4	)	$	33		$	(20	)	$	4		$	(2	)	$	(18	)

	Six Months Ended June 30, 2019												Six Months Ended June 30, 2018
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of December 31	$	(49	)	$	(2	)	$	7		$	(44	)	$	(29	)	$	12		$	8		$	(9	)
Transfers into Level 3 from Level 2	—			—			—			—			—			—			—			—
Transfers from Level 3 into Level 2	—			—			—			—			(3		)	—			—			(3		)
Total gains (losses)
Included in earnings	31			10			(1		)	40			(98		)	4			1			(93		)
Recorded in Regulatory liabilities	—			—			7			7			—			—			15			15
Purchases, issuances, and settlements
Settlements	8			2			(4		)	6			105			(29		)	(9		)	67
Net Assets (Liabilities) as of June 30	$	(10	)	$	10		$	9		$	9		$	(25	)	$	(13	)	$	15		$	(23	)
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 June 30, 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	$	16		$	17		$	(5	)	$	28		$	(78	)	$	(6	)	$	(2	)	$	(86	)

The following table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for DTE Electric:

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Net Assets as of beginning of period	$	2		$	5		$	6		$	9
Change in fair value recorded in Regulatory liabilities	9			15			7			15
Purchases, issuances, and settlements
Settlements	(2		)	(5		)	(4		)	(9		)
Net Assets as of June 30	$	9		$	15		$	9		$	15
The amount of total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets held at June 30, 2019 and 2018 and reflected in DTE Electric's Consolidated Statements of Financial Position	$	9		$	15		$	9		$	15

Unobservable Inputs Related to Level 3 Assets and Liabilities

The following tables present the unobservable inputs related to DTE Energy's Level 3 assets and liabilities:

	June 30, 2019
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	60	$	(70	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.33	)	—	$	5.95	/MMBtu	$	(0.08	)/MMBtu
Electricity	$	81	$	(71	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(13	)	—	$	7	/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

Carrying Amount of Fair Value of Financial Instruments

The following table presents the carrying amount and fair value of financial instruments for DTE Energy:

	June 30, 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(a), excluding lessor finance leases	$	153	$	—	$	—	$	153	$	40	$	—	$	—	$	40
Dividends payable	$	346	$	346	$	—	$	—	$	172	$	172	$	—	$	—
Short-term borrowings	$	3	$	—	$	3	$	—	$	609	$	—	$	609	$	—
Notes payable — Other(b), excluding lessee finance leases	$	29	$	—	$	—	$	29	$	41	$	—	$	—	$	41
Long-term debt(c)	$	15,058	$	1,989	$	12,915	$	1,385	$	13,622	$	1,796	$	10,712	$	1,317

_______________________________________

(a) Current portion included in Current Assets — Other on DTE Energy's Consolidated Statements of Financial Position.

(b) Included in Current Liabilities — Other and Other Liabilities — Other on DTE Energy's Consolidated Statements of Financial Position.

(c) Includes debt due within one year, unamortized debt discounts, and issuance costs. Excludes finance lease obligations.

The following table presents the carrying amount and fair value of financial instruments for DTE Electric:

	June 30, 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	$	10	$	—	$	—	$	10	$	6	$	—	$	—	$	6
Short-term borrowings — affiliates	$	295	$	—	$	—	$	295	$	101	$	—	$	—	$	101
Short-term borrowings — other	$	—	$	—	$	—	$	—	$	149	$	—	$	149	$	—
Notes payable — Other(b), excluding lessee finance leases	$	23	$	—	$	—	$	23	$	21	$	—	$	—	$	21
Long-term debt(c)	$	7,178	$	—	$	7,749	$	167	$	6,538	$	—	$	6,552	$	161

_______________________________________

(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.

Fair Value of Nuclear Decommissioning Trust Fund Assets

The following table summarizes DTE Electric's fair value of the nuclear decommissioning trust fund assets:

	June 30, 2019		December 31, 2018
	(In millions)
Fermi 2	$	1,553	$	1,372
Fermi 1	3		3
Low-level radioactive waste	5		3
	$	1,561	$	1,378

Schedule of Realized Gains and Losses and Proceeds from Sale of Securities by Nuclear Decommissioning Trust Funds

The following table sets forth DTE Electric's gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds:

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Realized gains	$	17		$	19		$	28		$	42
Realized losses	$	(10	)	$	(6	)	$	(17	)	$	(15	)
Proceeds from sale of securities	$	220		$	280		$	396		$	616

Fair Value and Unrealized Gains and Losses for Nuclear Decommissioning Trust Funds

The following table sets forth DTE Electric's fair value and unrealized gains and losses for the nuclear decommissioning trust funds:

	June 30, 2019							December 31, 2018
	Fair Value		Unrealized Gains		Unrealized Losses			Fair Value		Unrealized Gains		Unrealized Losses
	(In millions)
Equity securities	$	988	$	335	$	(49	)	$	851	$	235	$	(79	)
Fixed income securities	532		21		(1		)	502		7		(8		)
Private equity and other	32		—		—			20		—		—
Cash equivalents	9		—		—			5		—		—
	$	1,561	$	356	$	(50	)	$	1,378	$	242	$	(87	)

Fair Value of the Fixed Income Securities Held in Nuclear Decommissioning Trust Funds

The following table summarizes the fair value of the fixed income securities held in nuclear decommissioning trust funds by contractual maturity:

	June 30, 2019
	(In millions)
Due within one year	$	17
Due after one through five years	103
Due after five through ten years	110
Due after ten years	302
	$	532

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Financial and Other Derivative Instruments (Tables)

6 Months Ended

Jun. 30, 2019

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair Value of Derivative Instruments

The following table presents the fair value of derivative instruments for DTE Energy:

	June 30, 2019					December 31, 2018
	Derivative Assets		Derivative Liabilities			Derivative Assets		Derivative Liabilities
	(In millions)
Derivatives designated as hedging instruments
Interest rate contracts	$	—	$	(15	)	$	—	$	(3	)
Derivatives not designated as hedging instruments
Commodity contracts
Natural gas	$	235	$	(236	)	$	349	$	(380	)
Electricity	320		(321		)	303		(285		)
Other	9		—			7		(1		)
Foreign currency exchange contracts	1		—			4		—
Total derivatives not designated as hedging instruments	$	565	$	(557	)	$	663	$	(666	)
Current	$	449	$	(434	)	$	563	$	(518	)
Noncurrent	116		(138		)	100		(151		)
Total derivatives	$	565	$	(572	)	$	663	$	(669	)

The following table presents the fair value of derivative instruments for DTE Electric:

	June 30, 2019		December 31, 2018
	(In millions)
FTRs — Other current assets	$	9	$	6
Total derivatives not designated as hedging instruments	$	9	$	6

Netting Offsets of Derivative Assets

The following table presents net cash collateral offsetting arrangements for DTE Energy:

	June 30, 2019			December 31, 2018
	(In millions)
Cash collateral netted against Derivative assets	$	—		$	(17	)
Cash collateral netted against Derivative liabilities	4			—
Cash collateral recorded in Accounts receivable(a)	12			10
Cash collateral recorded in Accounts payable(a)	(3		)	(6		)
Total net cash collateral posted (received)	$	13		$	(13	)

_______________________________________

(a) Amounts are recorded net by counterparty.

The following table presents the netting offsets of Derivative assets and liabilities for DTE Energy:

	June 30, 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	$	235		$	(170	)	$	65		$	349		$	(277	)	$	72
Electricity	320			(236		)	84			303			(252		)	51
Other	9			—			9			7			(1		)	6
Foreign currency exchange contracts	1			—			1			4			—			4
Total derivative assets	$	565		$	(406	)	$	159		$	663		$	(530	)	$	133
Derivative liabilities
Commodity contracts
Natural gas	$	(236	)	$	170		$	(66	)	$	(380	)	$	272		$	(108	)
Electricity	(321		)	240			(81		)	(285		)	240			(45		)
Other	—			—			—			(1		)	1			—
Interest rate contracts	(15		)	—			(15		)	(3		)	—			(3		)
Total derivative liabilities	$	(572	)	$	410		$	(162	)	$	(669	)	$	513		$	(156	)

Netting Offsets of Derivative Liabilities

The following table presents net cash collateral offsetting arrangements for DTE Energy:

	June 30, 2019			December 31, 2018
	(In millions)
Cash collateral netted against Derivative assets	$	—		$	(17	)
Cash collateral netted against Derivative liabilities	4			—
Cash collateral recorded in Accounts receivable(a)	12			10
Cash collateral recorded in Accounts payable(a)	(3		)	(6		)
Total net cash collateral posted (received)	$	13		$	(13	)

_______________________________________

(a) Amounts are recorded net by counterparty.

The following table presents the netting offsets of Derivative assets and liabilities for DTE Energy:

	June 30, 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	$	235		$	(170	)	$	65		$	349		$	(277	)	$	72
Electricity	320			(236		)	84			303			(252		)	51
Other	9			—			9			7			(1		)	6
Foreign currency exchange contracts	1			—			1			4			—			4
Total derivative assets	$	565		$	(406	)	$	159		$	663		$	(530	)	$	133
Derivative liabilities
Commodity contracts
Natural gas	$	(236	)	$	170		$	(66	)	$	(380	)	$	272		$	(108	)
Electricity	(321		)	240			(81		)	(285		)	240			(45		)
Other	—			—			—			(1		)	1			—
Interest rate contracts	(15		)	—			(15		)	(3		)	—			(3		)
Total derivative liabilities	$	(572	)	$	410		$	(162	)	$	(669	)	$	513		$	(156	)

Netting Offsets of Derivative Assets and Liabilities Reconciliation to the Statements of Financial Position

The following table presents the netting offsets of Derivative assets and liabilities showing the reconciliation of derivative instruments to DTE Energy's Consolidated Statements of Financial Position:

	June 30, 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	$	449		$	116		$	(434	)	$	(138	)	$	563		$	100		$	(518	)	$	(151	)
Counterparty netting	(336		)	(70		)	336			70			(451		)	(62		)	451			62
Collateral adjustment	—			—			4			—			(10		)	(7		)	—			—
Total derivatives as reported	$	113		$	46		$	(94	)	$	(68	)	$	102		$	31		$	(67	)	$	(89	)

Gain (Loss) Recognized in Income on Derivatives

The effect of derivatives not designated as hedging instruments on DTE Energy's Consolidated Statements of Operations is as follows:

	Location of Gain (Loss) Recognized in Income on Derivatives	Gain (Loss) Recognized in Income on Derivatives for the Three Months Ended June 30,						Gain (Loss) Recognized in Income on Derivatives for the Six Months Ended June 30,
		2019			2018			2019			2018
		(In millions)
Commodity contracts
Natural gas	Operating Revenues — Non-utility operations	$	24		$	(48	)	$	9		$	(158	)
Natural gas	Fuel, purchased power, and gas — non-utility	(30		)	16			40			68
Electricity	Operating Revenues — Non-utility operations	16			28			(33		)	11
Other	Operating Revenues — Non-utility operations	(1		)	2			—			1
Foreign currency exchange contracts	Operating Revenues — Non-utility operations	(2		)	2			(3		)	4
Total		$	7		$	—		$	13		$	(74	)

Volume of Commodity Contracts

The following represents the cumulative gross volume of DTE Energy's derivative contracts outstanding as of June 30, 2019:

Commodity	Number of Units
Natural gas (MMBtu)	1,986,388,951
Electricity (MWh)	33,786,455
Foreign currency exchange (CAD)	91,380,922

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Long-Term Debt (Tables)

6 Months Ended

Jun. 30, 2019

Debt Disclosure [Abstract]

Schedule of Issued Debt

In 2019, 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
					$	1,450

_______________________________________

(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.

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Short-Term Credit Arrangements and Borrowings (Tables)

6 Months Ended

Jun. 30, 2019

Short-term Debt [Abstract]

Schedule of Line of Credit Facilities

The availability under the facilities in place at June 30, 2019 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 September 2019	70		—		—		70
Unsecured revolving credit facility, expiring April 2024	1,500		500		300		2,300
	1,720		500		300		2,520
Amounts outstanding at June 30, 2019
Commercial paper issuances	—		—		3		3
Letters of credit	179		—		—		179
	179		—		3		182
Net availability at June 30, 2019	$	1,541	$	500	$	297	$	2,338

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Leases (Tables)

6 Months Ended

Jun. 30, 2019

Leases [Abstract]

Components of Lease Cost and Other Information Related to Leases

The components of lease cost for DTE Energy were as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2019		2019
	(In millions)
Operating lease cost	$	10	$	21
Finance lease cost:
Amortization of right-of-use assets	2		3
Interest of lease liabilities	—		—
Total finance lease cost	2		3
Variable lease cost	1		6
Short-term lease cost	3		5
	$	16	$	35

The components of lease cost for DTE Electric were as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2019		2019
	(In millions)
Operating lease cost	$	4	$	8
Finance lease cost:
Amortization of right-of-use assets	2		3
Interest of lease liabilities	—		—
Total finance lease cost	2		3
Variable lease cost	—		—
Short-term lease cost	—		1
	$	6	$	12

Other information related to leases for the six months ended June 30, 2019 were as follows:

	DTE Energy		DTE Electric
	2019		2019
	(In millions)
Supplemental Cash Flows Information
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows from finance leases	$	3	$	3
Operating cash flows from operating leases	$	19	$	7
Right-of-use assets obtained in exchange for lease obligations:
Operating leases	$	22	$	1
Weighted Average Remaining Lease Term
Operating leases	9.9 years		10.4 years
Finance leases	2.5 years		2.5 years
Weighted Average Discount Rate
Operating leases	3.8%		3.7%
Finance leases	3.1%		3.1%

Schedule of Maturities of Operating Leases

The Registrants' future minimum lease payments under leases for remaining periods as of June 30, 2019 were as follows:

	DTE Energy					DTE Electric
	Operating Leases			Finance Leases		Operating Leases			Finance Leases
	(In millions)
2019	$	21		$	2	$	9		$	2
2020	32			4		12			4
2021	23			3		11			3
2022	16			—		7			—
2023	13			—		6			—
2024 and thereafter	61			—		30			—
Total future minimum lease payments	166			9		75			9
Imputed interest	(30		)	—		(14		)	—
	$	136		$	9	$	61		$	9

Schedule of Maturities of Finance Leases

The Registrants' future minimum lease payments under leases for remaining periods as of June 30, 2019 were as follows:

	DTE Energy					DTE Electric
	Operating Leases			Finance Leases		Operating Leases			Finance Leases
	(In millions)
2019	$	21		$	2	$	9		$	2
2020	32			4		12			4
2021	23			3		11			3
2022	16			—		7			—
2023	13			—		6			—
2024 and thereafter	61			—		30			—
Total future minimum lease payments	166			9		75			9
Imputed interest	(30		)	—		(14		)	—
	$	136		$	9	$	61		$	9

Schedule of Finance Leases Reported on Consolidated Statement of Financial Position

Finance leases reported on the Consolidated Statement of Financial Position were as follows:

	DTE Energy		DTE Electric
	June 30, 2019
	(In millions)
Right-of-use assets, within Property, plant, and equipment, net	$	9	$	9
Current lease liabilities, within Current Liabilities — Other	$	3	$	3

Schedule of Future Minimum Lease Payments and Rental Revenues for Operating Leases

DTE Energy’s minimum future rental revenues under non-cancelable operating leases as of December 31, 2018 were:

	DTE Energy
	(In millions)
2019	$	66
2020	66
2021	64
2022	20
2023	20
2024 and thereafter	196
	$	432

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

Schedule of Lease Income Associated with Operating Leases

DTE Energy’s lease income associated with operating leases was as follows:

	Three Months Ended June 30,		Six Months Ended June 30,
	2019		2019
	(In millions)
Fixed payments	$	17	$	34
Variable payments	25		52
	$	42	$	86

Schedule of Minimum Future Rental Revenues under Operating Leases

DTE Energy’s minimum future rental revenues under operating leases for remaining periods as of June 30, 2019 were:

	DTE Energy
	(In millions)
2019	$	33
2020	66
2021	64
2022	22
2023	22
2024 and thereafter	216
	$	423

Schedule of Property under Operating Leases - Topic 842

Property under operating leases for DTE Energy was as follows:

	DTE Energy
	June 30, 2019
	(In millions)
Gross property under operating leases	$	443
Accumulated amortization of property under operating leases	$	160

Components of Net Investment in Finance Leases

The components of DTE Energy’s net investment in finance leases for remaining periods were as follows:

	DTE Energy
	June 30, 2019
	(In millions)
2019	$	5
2020	9
2021	—
2022	—
2023	—
2024 and thereafter	1
Total minimum future lease receipts	15
Residual value of leased pipeline	40
Less unearned income	7
Net investment in finance lease	48
Less current portion	5
	$	43

Components of Net Investment in Capital Leases

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

Schedule of Property under Operating Leases - Topic 840

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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Retirement Benefits and Trusteed Assets (Tables)

6 Months Ended

Jun. 30, 2019

Defined Benefit Plan [Abstract]

Schedule of Net Periodic Benefit Costs (Credits)

The following tables detail the components of net periodic benefit costs (credits) for pension benefits and other postretirement benefits for DTE Energy:

	Pension Benefits						Other Postretirement Benefits
	Three Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Service cost	$	21		$	25		$	6		$	7
Interest cost	54			50			17			17
Expected return on plan assets	(81		)	(83		)	(31		)	(35		)
Amortization of:
Net actuarial loss	34			45			3			2
Prior service credit	—			—			(2		)	—
Net periodic benefit cost (credit)	$	28		$	37		$	(7	)	$	(9	)

	Pension Benefits						Other Postretirement Benefits
	Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Service cost	$	42		$	50		$	11		$	14
Interest cost	109			100			35			34
Expected return on plan assets	(162		)	(165		)	(62		)	(71		)
Amortization of:
Net actuarial loss	66			89			6			5
Prior service credit	—			—			(4		)	—
Net periodic benefit cost (credit)	$	55		$	74		$	(14	)	$	(18	)

The following tables detail the components of net periodic benefit costs (credits) for other postretirement benefits for DTE Electric:

	Other Postretirement Benefits
	Three Months Ended June 30,
	2019			2018
	(In millions)
Service cost	$	4		$	5
Interest cost	14			14
Expected return on plan assets	(21		)	(25		)
Amortization of:
Net actuarial loss	1			2
Prior service credit	(3		)	—
Net periodic benefit credit	$	(5	)	$	(4	)

	Other Postretirement Benefits
	Six Months Ended June 30,
	2019			2018
	(In millions)
Service cost	$	8		$	10
Interest cost	27			27
Expected return on plan assets	(42		)	(49		)
Amortization of:
Net actuarial loss	2			4
Prior service credit	(4		)	—
Net periodic benefit credit	$	(9	)	$	(8	)

Schedule of Defined Benefit Plans Disclosures

During 2019, DTE Energy contributed the following amounts of DTE Energy common stock to the DTE Energy Company Affiliates Employee Benefit Plans Master Trust:

Date	Number of Shares	Price per Share	Amount
			(In millions)
March 5, 2019	814,597	$122.76	$	100

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Segment and Related Information (Tables)

6 Months Ended

Jun. 30, 2019

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment

Inter-segment billing for goods and services exchanged between segments is based upon tariffed or market-based prices of the provider and primarily consists of the sale of reduced emissions fuel, power sales, and natural gas sales in the following segments:

	Three Months Ended June 30,				Six Months Ended June 30,
	2019		2018		2019		2018
	(In millions)
Electric	$	13	$	13	$	27	$	26
Gas	3		4		5		6
Gas Storage and Pipelines	3		14		6		22
Power and Industrial Projects	157		162		302		317
Energy Trading	5		5		12		12
Corporate and Other	—		—		1		1
	$	181	$	198	$	353	$	384

Financial data of DTE Energy's business segments follows:

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Operating Revenues — Utility operations
Electric	$	1,190		$	1,276		$	2,425		$	2,481
Gas	243			255			888			805
Operating Revenues — Non-utility operations
Gas Storage and Pipelines	121			122			237			241
Power and Industrial Projects	402			538			790			1,105
Energy Trading	1,113			1,164			2,414			2,662
Corporate and Other	—			2			1			2
Reconciliation and Eliminations	(181		)	(198		)	(353		)	(384		)
Total	$	2,888		$	3,159		$	6,402		$	6,912

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
	(In millions)
Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	133		$	163		$	280		$	303
Gas	8			14			159			118
Gas Storage and Pipelines	50			60			98			122
Power and Industrial Projects	29			43			55			88
Energy Trading	(6		)	(5		)	26			26
Corporate and Other	(32		)	(41		)	(35		)	(62		)
Net Income Attributable to DTE Energy Company	$	182		$	234		$	583		$	595

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Organization and Basis of Presentation (Details Textuals) customer in Millions	Jun. 30, 2019 USD ($) customer
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Number of electric utility customers | customer	2.2
Number of gas utility customers | customer	1.3
Significant potential exposure | $	$ 0
DTE Electric
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Significant potential exposure | $	$ 0
NEXUS pipeline
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Ownership interest	50.00%
SGG | Midstream Natural Gas Assets
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Percent of assets acquired	85.00%

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Organization and Basis of Presentation (Consolidated Variable Interest Entities) (Details) - USD ($) $ in Millions	2 Months Ended	6 Months Ended	12 Months Ended
	Jun. 30, 2019	Jun. 30, 2019	Dec. 31, 2018
ASSETS
Cash and cash equivalents	$ 62	$ 62	$ 71
Restricted cash	0	0	5
Accounts receivable	1,436	1,436	1,789
Property, plant, and equipment, net	22,297	22,297	21,650
Goodwill	2,293	2,293	2,293
Intangible assets	837	837	849
Total Assets	36,851	36,851	36,288
Variable interest entity, primary beneficiary, restricted
ASSETS
Cash and cash equivalents	32	32	39
Restricted cash	0	0	5
Accounts receivable	48	48	46
Inventories	84	84	93
Property, plant, and equipment, net	440	440	441
Goodwill	25	25	25
Intangible assets	550	550	557
Other current and long-term assets	3	3	3
Total Assets	1,182	1,182	1,209
LIABILITIES
Accounts payable and accrued current liabilities	30	30	34
Other current and long-term liabilities	18	18	19
Total liabilities	48	48	53
SGG
ASSETS
Cash and cash equivalents	18	18	25
Restricted cash	0	0	0
Accounts receivable	10	10	9
Inventories	0	0	1
Property, plant, and equipment, net	400	400	395
Goodwill	25	25	25
Intangible assets	550	550	557
Other current and long-term assets	2	2	3
Total Assets	1,005	1,005	1,015
LIABILITIES
Accounts payable and accrued current liabilities	5	5	3
Other current and long-term liabilities	9	9	9
Total liabilities	$ 14	$ 14	$ 12
VIE ownership and non-ownership percentage		100.00%
VIE ownership percentage	85.00%		55.00%
Other
ASSETS
Cash and cash equivalents	$ 14	$ 14	$ 14
Restricted cash	0	0	5
Accounts receivable	38	38	37
Inventories	84	84	92
Property, plant, and equipment, net	40	40	46
Goodwill	0	0	0
Intangible assets	0	0	0
Other current and long-term assets	1	1	0
Total Assets	177	177	194
LIABILITIES
Accounts payable and accrued current liabilities	25	25	31
Other current and long-term liabilities	9	9	10
Total liabilities	$ 34	$ 34	$ 41

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Organization and Basis of Presentation (Non-Consolidated Variable Interest Entities) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Variable Interest Entity [Line Items]
Investments in equity method investees	$ 1,758	$ 1,771
Notes receivable	168	64
Variable interest entity, non-consolidated
Variable Interest Entity [Line Items]
Investments in equity method investees	1,402	1,425
Notes receivable	26	15
Future funding commitments	$ 51	$ 55

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Significant Accounting Policies (Other Income) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Schedule of Other Nonoperating Income, by Component [Line Items]
Income from REF entities	$ 29	$ 25	$ 56	$ 48
Equity earnings of equity method investees	20	32	43	53
Gains from equity securities	7	1	24	1
Contract services	6	12	14	32
Allowance for equity funds used during construction	6	6	13	13
Other	5	6	11	16
Total other income	73	82	161	163
DTE Electric
Schedule of Other Nonoperating Income, by Component [Line Items]
Gains from equity securities	7	1	24	1
Contract services	8	13	16	33
Allowance for equity funds used during construction	6	4	12	9
Other	4	4	6	6
Total other income	$ 25	$ 22	$ 58	$ 49

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Significant Accounting Policies (Details Textuals) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018	Dec. 31, 2019	Dec. 31, 2018
Significant Accounting Policies [Line Items]
Estimated annual effective tax rates	11.00%	7.00%	11.00%	13.00%
Effective tax rate increase (decrease)	4.00%		(2.00%)
Annual production tax credits	7.00%		4.00%
Amortization of TCJA regulatory liability	3.00%		3.00%
Remeasurement of deferred taxes			$ 21
Measurement period impact to effective tax rate			3.00%
Unrecognized tax benefits	$ 8		$ 8
Unrecognized compensation cost	$ 104		$ 104
Recognition period (in years)			1 year 6 months 14 days
DTE Electric
Significant Accounting Policies [Line Items]
Estimated annual effective tax rates	16.00%	21.00%	16.00%	23.00%
Effective tax rate increase (decrease)	(5.00%)		(7.00%)
Annual production tax credits			1.00%
Amortization of TCJA regulatory liability			4.00%
Remeasurement of deferred taxes			$ 8
Measurement period impact to effective tax rate			2.00%
Unrecognized tax benefits	$ 10		$ 10
DTE Electric | DTE Energy
Significant Accounting Policies [Line Items]
Income tax receivable	9		9			$ 8
Allocated costs	$ 11	$ 8	$ 24	$ 17
Forecast
Significant Accounting Policies [Line Items]
Estimated annual effective tax rates					12.00%
Forecast | DTE Electric
Significant Accounting Policies [Line Items]
Estimated annual effective tax rates					16.00%

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Significant Accounting Policies (Income Taxes) (Details)	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Schedule of Income Taxes [Line Items]
Effective Tax Rate	11.00%	7.00%	11.00%	13.00%
DTE Electric
Schedule of Income Taxes [Line Items]
Effective Tax Rate	16.00%	21.00%	16.00%	23.00%

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New Accounting Pronouncements (Details) - USD ($) $ in Millions	Jun. 30, 2019	Jan. 01, 2019	Jan. 01, 2018
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right-of-use assets for certain operating leases	$ 142
Lease liabilities for certain operating leases	136
Reclassification of income tax effects		$ 0	$ 0
DTE Electric
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right-of-use assets for certain operating leases	67
Lease liabilities for certain operating leases	$ 61
Accumulated Other Comprehensive Income (Loss)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Reclassification of income tax effects		(25)	(5)
Accumulated Other Comprehensive Income (Loss) | DTE Electric
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Reclassification of income tax effects			(3)
Retained Earnings
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Reclassification of income tax effects		25	5
Retained Earnings | DTE Electric
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Reclassification of income tax effects			$ 3
Accounting Standards Update 2016-02
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right-of-use assets for certain operating leases		137
Lease liabilities for certain operating leases		130
Prepaid lease costs reclassified from Other assets, current and noncurrent		9
Deferred lease costs reclassified from Other liabilities, current and noncurrent		2
Accounting Standards Update 2016-02 | DTE Electric
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right-of-use assets for certain operating leases		74
Lease liabilities for certain operating leases		67
Accounting Standards Update 2018-02 | Accumulated Other Comprehensive Income (Loss)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Reclassification of income tax effects		(25)
Accounting Standards Update 2018-02 | Retained Earnings
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Reclassification of income tax effects		$ 25

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Revenue - Disaggregation of Revenue (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Disaggregation of Revenue [Line Items]
Revenues	$ 2,888	$ 3,159	$ 6,402	$ 6,912
Electric
Disaggregation of Revenue [Line Items]
Revenues	1,190	1,276	2,425	2,481
Electric | Other
Disaggregation of Revenue [Line Items]
Revenues	5	4	8	9
Electric | Residential
Disaggregation of Revenue [Line Items]
Revenues	494	584	1,047	1,170
Electric | Commercial
Disaggregation of Revenue [Line Items]
Revenues	423	446	843	875
Electric | Industrial
Disaggregation of Revenue [Line Items]
Revenues	158	178	322	354
Electric | Other
Disaggregation of Revenue [Line Items]
Revenues	115	68	213	82
Gas
Disaggregation of Revenue [Line Items]
Revenues	243	255	888	805
Gas | Alternative Revenue Programs
Disaggregation of Revenue [Line Items]
Revenues		1		4
Gas | Other
Disaggregation of Revenue [Line Items]
Revenues	2	2	4	4
Gas | Other
Disaggregation of Revenue [Line Items]
Revenues	23	15	85	5
Gas | Gas sales
Disaggregation of Revenue [Line Items]
Revenues	163	180	640	637
Gas | End User Transportation
Disaggregation of Revenue [Line Items]
Revenues	42	49	122	134
Gas | Intermediate Transportation
Disaggregation of Revenue [Line Items]
Revenues	15	11	41	29
Gas Storage and Pipelines
Disaggregation of Revenue [Line Items]
Revenues	121	122	237	241
Lease revenue outside scope of Topic 606	2		4
Power and Industrial Projects
Disaggregation of Revenue [Line Items]
Revenues	402	538	790	1,105
Lease revenue outside scope of Topic 606	30	28	61	56
Energy Trading
Disaggregation of Revenue [Line Items]
Revenues	1,113	1,164	2,414	2,662
Gain (loss) on derivative outside scope of Topic 606	$ 879	$ 937	$ 1,800	$ 2,100

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Revenue - Deferred Revenue (Details) $ in Millions	6 Months Ended
	Jun. 30, 2019 USD ($)
Contract Liability [Roll Forward]
Beginning Balance	$ 74
Increases due to cash received or receivable, excluding amounts recognized as revenue during the period	35
Revenue recognized that was included in the deferred revenue balance at the beginning of the period	(26)
Ending Balance	$ 83

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Revenue - Expected Recognition of Deferred Revenue (Details) $ in Millions	Jun. 30, 2019 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 48
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 5
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 5
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 7
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 3
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 15
Remaining performance obligation, expected timing of satisfaction
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 83

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Revenue - Expected Timing of Performance Obligation Satisfaction (Details) $ in Millions	Jun. 30, 2019 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 48
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 5
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 5
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 7
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 3
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 15
Remaining performance obligation, expected timing of satisfaction
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 83
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 111
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | DTE Electric
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 5
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 305
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | DTE Electric
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 0
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 249
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | DTE Electric
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 0
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 191
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | DTE Electric
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 0
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 133
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | DTE Electric
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 0
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 645
Remaining performance obligation, expected timing of satisfaction
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | DTE Electric
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 0
Remaining performance obligation, expected timing of satisfaction
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 1,634
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | DTE Electric
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 5

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Revenue - Expenses Recognized for Estimated Uncollectible Accounts Receivable (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Revenue from External Customer [Line Items]
Allowance for doubtful accounts receivable write-offs	$ 24	$ 31	$ 53	$ 56
DTE Electric
Revenue from External Customer [Line Items]
Allowance for doubtful accounts receivable write-offs	$ 14	$ 17	$ 30	$ 31

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Regulatory Matters (Details Textuals) - USD ($) $ in Millions	Jul. 08, 2019	May 02, 2019	Feb. 01, 2019	Dec. 06, 2018	Dec. 05, 2018	Nov. 16, 2018	Jul. 06, 2018
DTE Electric | MPSC | Electric Rate Case Filing 2018
Public Utilities, General Disclosures [Line Items]
Requested rate increase			$ 248.6				$ 328.0
Return on equity percent		10.00%					10.00%
Return on equity requested percent							10.50%
Approved rate increase		$ 125.0
DTE Electric | MPSC | 2016 DTE Electric Depreciation Case Filing
Public Utilities, General Disclosures [Line Items]
Approved composite depreciation rate increase				3.72%	3.06%
DTE Gas
Public Utilities, General Disclosures [Line Items]
Calculation C, reduction of revenue due to Tax Cuts and Jobs Act, requested						$ 12.0
Subsequent event | DTE Electric | MPSC | Electric Rate Case Filing 2019
Public Utilities, General Disclosures [Line Items]
Requested rate increase	$ 351.0
Return on equity percent	10.00%
Return on equity requested percent	10.50%

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Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Basic Earnings per Share
Net Income Attributable to DTE Energy Company	$ 182	$ 234	$ 583	$ 595
Less: Allocation of earnings to net restricted stock awards	0	0	1	1
Net income available to common shareholders — basic	$ 182	$ 234	$ 582	$ 594
Average number of common shares outstanding — basic (in shares)	183.0	181.0	183.0	180.0
Basic Earnings per Common Share (in dollars per share)	$ 0.99	$ 1.29	$ 3.19	$ 3.29
Diluted Earnings per Share
Net Income Attributable to DTE Energy Company	$ 182	$ 234	$ 583	$ 595
Less: Allocation of earnings to net restricted stock awards	0	0	1	1
Net income available to common shareholders — diluted	$ 182	$ 234	$ 582	$ 594
Average number of common shares outstanding — basic (in shares)	183.0	181.0	183.0	180.0
Incremental shares attributable to:
Average dilutive equity units, performance share awards, and stock options (in shares)	1.0	0.0	0.0	0.0
Average number of common shares outstanding — diluted (in shares)	184.0	181.0	183.0	180.0
Diluted Earnings per Common Share (in dollars per share)	$ 0.99	$ 1.29	$ 3.18	$ 3.29
Antidilutive securities excluded from computation of earnings per share (in shares)		6.6		6.6

XML

Fair Value (Assets and Liabilities Recorded at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Derivative assets
Derivative assets, gross	$ 565	$ 663
Derivative asset, netting	(406)	(530)
Derivative assets, net	159	133
Derivative liabilities
Derivative liabilities, gross	(572)	(669)
Derivative liability, netting	410	513
Derivative liabilities, net	(162)	(156)
Current liabilities
Derivative liabilities
Derivative liabilities, gross	(434)	(518)
Noncurrent liabilities
Derivative liabilities
Derivative liabilities, gross	(138)	(151)
Natural gas
Derivative assets
Derivative assets, gross	235	349
Derivative asset, netting	(170)	(277)
Derivative assets, net	65	72
Derivative liabilities
Derivative liabilities, gross	(236)	(380)
Derivative liability, netting	170	272
Derivative liabilities, net	(66)	(108)
Electricity
Derivative assets
Derivative assets, gross	320	303
Derivative asset, netting	(236)	(252)
Derivative assets, net	84	51
Derivative liabilities
Derivative liabilities, gross	(321)	(285)
Derivative liability, netting	240	240
Derivative liabilities, net	(81)	(45)
Other
Derivative assets
Derivative assets, gross	9	7
Derivative asset, netting	0	(1)
Derivative assets, net	9	6
Derivative liabilities
Derivative liabilities, gross	0	(1)
Derivative liability, netting	0	1
Derivative liabilities, net	0	0
Interest rate contracts
Derivative liabilities
Derivative liabilities, gross	(15)	(3)
Derivative liability, netting	0	0
Derivative liabilities, net	(15)	(3)
Foreign currency exchange contracts
Derivative assets
Derivative assets, gross	1	4
Derivative asset, netting	0	0
Derivative assets, net	1	4
Recurring
Assets
Cash equivalents	26	18
Derivative assets
Derivative asset, netting	(406)	(530)
Derivative assets, net	159	133
Total assets	1,953	1,712
Derivative liabilities
Derivative liability, netting	410	513
Derivative liabilities, net	(162)	(156)
Net Assets (Liabilities) at end of period	1,791	1,556
Net Assets (Liabilities) at end of period, netting	4	(17)
Recurring | DTE Electric
Assets
Cash equivalents	11	10
Derivative assets
Total assets	1,592	1,404
Recurring | Current assets
Derivative assets
Derivative asset, netting	(336)	(461)
Total assets	139	120
Recurring | Current assets | DTE Electric
Derivative assets
Total assets	20	16
Recurring | Noncurrent assets
Derivative assets
Derivative asset, netting	(70)	(69)
Total assets	1,814	1,592
Recurring | Noncurrent assets | DTE Electric
Derivative assets
Total assets	1,572	1,388
Recurring | Current liabilities
Derivative liabilities
Derivative liability, netting	340	451
Derivative liabilities, net	(94)	(67)
Recurring | Noncurrent liabilities
Derivative liabilities
Derivative liability, netting	70	62
Derivative liabilities, net	(68)	(89)
Recurring | Cash and cash equivalents
Assets
Cash equivalents	15	3
Recurring | Restricted cash
Assets
Cash equivalents		5
Recurring | Other
Assets
Cash equivalents	11	10
Recurring | Other | DTE Electric
Assets
Cash equivalents	11	10
Recurring | Natural gas
Derivative assets
Derivative asset, netting	(170)	(277)
Derivative assets, net	65	72
Derivative liabilities
Derivative liability, netting	170	272
Derivative liabilities, net	(66)	(108)
Recurring | Electricity
Derivative assets
Derivative asset, netting	(236)	(252)
Derivative assets, net	84	51
Derivative liabilities
Derivative liability, netting	240	240
Derivative liabilities, net	(81)	(45)
Recurring | Other
Derivative assets
Derivative asset, netting	0	(1)
Derivative assets, net	9	6
Derivative liabilities
Derivative liability, netting	0	1
Derivative liabilities, net	0	0
Recurring | Interest rate contracts
Derivative liabilities
Derivative liability, netting	0	0
Derivative liabilities, net	(15)	(3)
Recurring | Foreign currency exchange contracts
Derivative assets
Derivative asset, netting	0	0
Derivative assets, net	1	4
Recurring | Derivative assets — FTRs | DTE Electric
Derivative assets
Derivative assets, net	9	6
Recurring | Cash equivalents
Assets
Nuclear decommissioning trusts	9	5
Other investments	4	4
Recurring | Cash equivalents | DTE Electric
Assets
Nuclear decommissioning trusts	9	5
Recurring | Private equity and other
Assets
Nuclear decommissioning trusts	32	20
Recurring | Private equity and other | DTE Electric
Assets
Nuclear decommissioning trusts	32	20
Recurring | Equity securities
Assets
Nuclear decommissioning trusts	988	851
Other investments	128	110
Recurring | Equity securities | DTE Electric
Assets
Nuclear decommissioning trusts	988	851
Other investments	11	10
Recurring | Fixed income securities
Assets
Nuclear decommissioning trusts	532	502
Other investments	75	69
Recurring | Fixed income securities | DTE Electric
Assets
Nuclear decommissioning trusts	532	502
Recurring | Level 1
Assets
Cash equivalents	26	16
Derivative assets
Derivative assets, gross	97	199
Total assets	1,336	1,266
Derivative liabilities
Derivative liabilities, gross	(119)	(197)
Net Assets (Liabilities) at end of period	1,217	1,069
Recurring | Level 1 | DTE Electric
Assets
Cash equivalents	11	8
Derivative assets
Total assets	1,028	886
Recurring | Level 1 | Current assets
Derivative assets
Total assets	122	212
Recurring | Level 1 | Current assets | DTE Electric
Derivative assets
Total assets	11	8
Recurring | Level 1 | Noncurrent assets
Derivative assets
Total assets	1,214	1,054
Recurring | Level 1 | Noncurrent assets | DTE Electric
Derivative assets
Total assets	1,017	878
Recurring | Level 1 | Current liabilities
Derivative liabilities
Derivative liabilities, gross	(111)	(191)
Recurring | Level 1 | Noncurrent liabilities
Derivative liabilities
Derivative liabilities, gross	(8)	(6)
Recurring | Level 1 | Natural gas
Derivative assets
Derivative assets, gross	97	199
Derivative liabilities
Derivative liabilities, gross	(119)	(197)
Recurring | Level 1 | Electricity
Derivative assets
Derivative assets, gross	0	0
Derivative liabilities
Derivative liabilities, gross	0	0
Recurring | Level 1 | Other
Derivative assets
Derivative assets, gross	0	0
Derivative liabilities
Derivative liabilities, gross	0	0
Recurring | Level 1 | Interest rate contracts
Derivative liabilities
Derivative liabilities, gross	0	0
Recurring | Level 1 | Foreign currency exchange contracts
Derivative assets
Derivative assets, gross	0	0
Recurring | Level 1 | Derivative assets — FTRs | DTE Electric
Derivative assets
Derivative assets, net	0	0
Recurring | Level 1 | Cash equivalents
Assets
Nuclear decommissioning trusts	9	5
Other investments	4	4
Recurring | Level 1 | Cash equivalents | DTE Electric
Assets
Nuclear decommissioning trusts	9	5
Recurring | Level 1 | Private equity and other
Assets
Nuclear decommissioning trusts	0	0
Recurring | Level 1 | Private equity and other | DTE Electric
Assets
Nuclear decommissioning trusts	0	0
Recurring | Level 1 | Equity securities
Assets
Nuclear decommissioning trusts	988	851
Other investments	128	110
Recurring | Level 1 | Equity securities | DTE Electric
Assets
Nuclear decommissioning trusts	988	851
Other investments	11	10
Recurring | Level 1 | Fixed income securities
Assets
Nuclear decommissioning trusts	9	12
Other investments	75	69
Recurring | Level 1 | Fixed income securities | DTE Electric
Assets
Nuclear decommissioning trusts	9	12
Recurring | Level 2
Assets
Cash equivalents	0	2
Derivative assets
Derivative assets, gross	318	338
Total assets	841	830
Derivative liabilities
Derivative liabilities, gross	(312)	(302)
Net Assets (Liabilities) at end of period	529	528
Recurring | Level 2 | DTE Electric
Assets
Cash equivalents	0	2
Derivative assets
Total assets	523	492
Recurring | Level 2 | Current assets
Derivative assets
Total assets	249	273
Recurring | Level 2 | Current assets | DTE Electric
Derivative assets
Total assets	0	2
Recurring | Level 2 | Noncurrent assets
Derivative assets
Total assets	592	557
Recurring | Level 2 | Noncurrent assets | DTE Electric
Derivative assets
Total assets	523	490
Recurring | Level 2 | Current liabilities
Derivative liabilities
Derivative liabilities, gross	(251)	(251)
Recurring | Level 2 | Noncurrent liabilities
Derivative liabilities
Derivative liabilities, gross	(61)	(51)
Recurring | Level 2 | Natural gas
Derivative assets
Derivative assets, gross	78	87
Derivative liabilities
Derivative liabilities, gross	(47)	(71)
Recurring | Level 2 | Electricity
Derivative assets
Derivative assets, gross	239	247
Derivative liabilities
Derivative liabilities, gross	(250)	(227)
Recurring | Level 2 | Other
Derivative assets
Derivative assets, gross	0	0
Derivative liabilities
Derivative liabilities, gross	0	(1)
Recurring | Level 2 | Interest rate contracts
Derivative liabilities
Derivative liabilities, gross	(15)	(3)
Recurring | Level 2 | Foreign currency exchange contracts
Derivative assets
Derivative assets, gross	1	4
Recurring | Level 2 | Derivative assets — FTRs | DTE Electric
Derivative assets
Derivative assets, net	0	0
Recurring | Level 2 | Cash equivalents
Assets
Nuclear decommissioning trusts	0	0
Other investments	0	0
Recurring | Level 2 | Cash equivalents | DTE Electric
Assets
Nuclear decommissioning trusts	0	0
Recurring | Level 2 | Private equity and other
Assets
Nuclear decommissioning trusts	0	0
Recurring | Level 2 | Private equity and other | DTE Electric
Assets
Nuclear decommissioning trusts	0	0
Recurring | Level 2 | Equity securities
Assets
Nuclear decommissioning trusts	0	0
Other investments	0	0
Recurring | Level 2 | Equity securities | DTE Electric
Assets
Nuclear decommissioning trusts	0	0
Other investments	0	0
Recurring | Level 2 | Fixed income securities
Assets
Nuclear decommissioning trusts	523	490
Other investments	0	0
Recurring | Level 2 | Fixed income securities | DTE Electric
Assets
Nuclear decommissioning trusts	523	490
Recurring | Level 3
Assets
Cash equivalents	0	0
Derivative assets
Derivative assets, gross	150	126
Total assets	150	126
Derivative liabilities
Derivative liabilities, gross	(141)	(170)
Net Assets (Liabilities) at end of period	9	(44)
Recurring | Level 3 | DTE Electric
Assets
Cash equivalents	0	0
Derivative assets
Total assets	9	6
Recurring | Level 3 | Current assets
Derivative assets
Total assets	104	96
Recurring | Level 3 | Current assets | DTE Electric
Derivative assets
Total assets	9	6
Recurring | Level 3 | Noncurrent assets
Derivative assets
Total assets	46	30
Recurring | Level 3 | Noncurrent assets | DTE Electric
Derivative assets
Total assets	0	0
Recurring | Level 3 | Current liabilities
Derivative liabilities
Derivative liabilities, gross	(72)	(76)
Recurring | Level 3 | Noncurrent liabilities
Derivative liabilities
Derivative liabilities, gross	(69)	(94)
Recurring | Level 3 | Natural gas
Derivative assets
Derivative assets, gross	60	63
Derivative liabilities
Derivative liabilities, gross	(70)	(112)
Recurring | Level 3 | Electricity
Derivative assets
Derivative assets, gross	81	56
Derivative liabilities
Derivative liabilities, gross	(71)	(58)
Recurring | Level 3 | Other
Derivative assets
Derivative assets, gross	9	7
Derivative liabilities
Derivative liabilities, gross	0	0
Recurring | Level 3 | Interest rate contracts
Derivative liabilities
Derivative liabilities, gross	0	0
Recurring | Level 3 | Foreign currency exchange contracts
Derivative assets
Derivative assets, gross	0	0
Recurring | Level 3 | Derivative assets — FTRs | DTE Electric
Derivative assets
Derivative assets, net	9	6
Recurring | Level 3 | Cash equivalents
Assets
Nuclear decommissioning trusts	0	0
Other investments	0	0
Recurring | Level 3 | Cash equivalents | DTE Electric
Assets
Nuclear decommissioning trusts	0	0
Recurring | Level 3 | Private equity and other
Assets
Nuclear decommissioning trusts	0	0
Recurring | Level 3 | Private equity and other | DTE Electric
Assets
Nuclear decommissioning trusts	0	0
Recurring | Level 3 | Equity securities
Assets
Nuclear decommissioning trusts	0	0
Other investments	0	0
Recurring | Level 3 | Equity securities | DTE Electric
Assets
Nuclear decommissioning trusts	0	0
Other investments	0	0
Recurring | Level 3 | Fixed income securities
Assets
Nuclear decommissioning trusts	0	0
Other investments	0	0
Recurring | Level 3 | Fixed income securities | DTE Electric
Assets
Nuclear decommissioning trusts	0	0
Recurring | Other
Derivative assets
Total assets	32	20
Derivative liabilities
Net Assets (Liabilities) at end of period	32	20
Recurring | Other | DTE Electric
Derivative assets
Total assets	32	20
Recurring | Other | Noncurrent assets
Derivative assets
Total assets	32	20
Recurring | Other | Noncurrent assets | DTE Electric
Derivative assets
Total assets	32	20
Recurring | Other | Private equity and other
Assets
Nuclear decommissioning trusts	32	20
Recurring | Other | Private equity and other | DTE Electric
Assets
Nuclear decommissioning trusts	$ 32	$ 20

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Fair Value (Reconciliation of Level 3 Assets and Liabilities at Fair Value on a Recurring Basis) (Details) - Recurring - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net Assets (Liabilities) as of beginning of period	$ (33)	$ (19)	$ (44)	$ (9)
Transfers into Level 3 from Level 2	1	0	0	0
Transfers from Level 3 into Level 2	0	0	0	(3)
Total gains (losses):
Included in earnings	40	(9)	40	(93)
Recorded in/Change in fair value recorded in Regulatory liabilities	9	15	7	15
Purchases, issuances, and settlements
Settlements	(8)	(10)	6	67
Net Assets (Liabilities) as of end of period	9	(23)	9	(23)
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 June 30, 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	33	(18)	28	(86)
DTE Electric
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net Assets (Liabilities) as of beginning of period	2	5	6	9
Total gains (losses):
Recorded in/Change in fair value recorded in Regulatory liabilities	9	15	7	15
Purchases, issuances, and settlements
Settlements	(2)	(5)	(4)	(9)
Net Assets (Liabilities) as of end of period	9	15	9	15
The amount of total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets held at June 30, 2019 and 2018 and reflected in DTE Electric's Consolidated Statements of Financial Position	9	15	9	15
Natural gas
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net Assets (Liabilities) as of beginning of period	(10)	(10)	(49)	(29)
Transfers into Level 3 from Level 2	1	0	0	0
Transfers from Level 3 into Level 2	0	0	0	(3)
Total gains (losses):
Included in earnings	(1)	(28)	31	(98)
Recorded in/Change in fair value recorded in Regulatory liabilities	0	0	0	0
Purchases, issuances, and settlements
Settlements	0	13	8	105
Net Assets (Liabilities) as of end of period	(10)	(25)	(10)	(25)
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 June 30, 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)	(20)	16	(78)
Electricity
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net Assets (Liabilities) as of beginning of period	(25)	(13)	(2)	12
Transfers into Level 3 from Level 2	0	0	0	0
Transfers from Level 3 into Level 2	0	0	0	0
Total gains (losses):
Included in earnings	41	18	10	4
Recorded in/Change in fair value recorded in Regulatory liabilities	0	0	0	0
Purchases, issuances, and settlements
Settlements	(6)	(18)	2	(29)
Net Assets (Liabilities) as of end of period	10	(13)	10	(13)
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 June 30, 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	38	4	17	(6)
Other
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net Assets (Liabilities) as of beginning of period	2	4	7	8
Transfers into Level 3 from Level 2	0	0	0	0
Transfers from Level 3 into Level 2	0	0	0	0
Total gains (losses):
Included in earnings	0	1	(1)	1
Recorded in/Change in fair value recorded in Regulatory liabilities	9	15	7	15
Purchases, issuances, and settlements
Settlements	(2)	(5)	(4)	(9)
Net Assets (Liabilities) as of end of period	9	15	9	15
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 June 30, 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	$ (4)	$ (2)	$ (5)	$ (2)

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Fair Value (Unobservable Inputs related to Level 3 Assets and Liabilities) (Details) $ in Millions	Jun. 30, 2019 USD ($) $ / MWh $ / MMBTU	Dec. 31, 2018 USD ($) $ / MWh $ / MMBTU
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets	$ 565	$ 663
Derivative Liabilities	(572)	(669)
Recurring | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets	150	126
Derivative Liabilities	(141)	(170)
Natural gas
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets	235	349
Derivative Liabilities	(236)	(380)
Natural gas | Recurring | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets	60	63
Derivative Liabilities	(70)	(112)
Electricity
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets	320	303
Derivative Liabilities	(321)	(285)
Electricity | Recurring | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets	81	56
Derivative Liabilities	$ (71)	$ (58)
Forward basis price | Natural gas | Minimum | Discounted Cash Flow | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MMBTU	(1.33)	(2.15)
Forward basis price | Natural gas | Maximum | Discounted Cash Flow | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MMBTU	5.95	5.59
Forward basis price | Natural gas | Weighted Average | Discounted Cash Flow | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MMBTU	(0.08)	(0.10)
Forward basis price | Electricity | Minimum | Discounted Cash Flow | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MWh	(13)	(7)
Forward basis price | Electricity | Maximum | Discounted Cash Flow | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MWh	7	9
Forward basis price | Electricity | Weighted Average | Discounted Cash Flow | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MWh	0	1

XML

Fair Value (Fair Value of Financial Instruments) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding lessor finance leases	$ 153	$ 40
Dividends payable	346	172
Short-term borrowings	3	609
Notes payable — Other, excluding lessee finance leases	29	41
Long-term debt	15,058	13,622
Carrying amount | DTE Electric
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding lessor finance leases	10	6
Short-term borrowings	0	149
Notes payable — Other, excluding lessee finance leases	23	21
Long-term debt	7,178	6,538
Carrying amount | DTE Electric | Affiliates
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	295	101
Fair value | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding lessor finance leases	0	0
Dividends payable	346	172
Short-term borrowings	0	0
Notes payable — Other, excluding lessee finance leases	0	0
Long-term debt	1,989	1,796
Fair value | Level 1 | DTE Electric
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding lessor finance leases	0	0
Short-term borrowings	0	0
Notes payable — Other, excluding lessee finance leases	0	0
Long-term debt	0	0
Fair value | Level 1 | DTE Electric | Affiliates
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	0	0
Fair value | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding lessor finance leases	0	0
Dividends payable	0	0
Short-term borrowings	3	609
Notes payable — Other, excluding lessee finance leases	0	0
Long-term debt	12,915	10,712
Fair value | Level 2 | DTE Electric
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding lessor finance leases	0	0
Short-term borrowings	0	149
Notes payable — Other, excluding lessee finance leases	0	0
Long-term debt	7,749	6,552
Fair value | Level 2 | DTE Electric | Affiliates
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	0	0
Fair value | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding lessor finance leases	153	40
Dividends payable	0	0
Short-term borrowings	0	0
Notes payable — Other, excluding lessee finance leases	29	41
Long-term debt	1,385	1,317
Fair value | Level 3 | DTE Electric
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding lessor finance leases	10	6
Short-term borrowings	0	0
Notes payable — Other, excluding lessee finance leases	23	21
Long-term debt	167	161
Fair value | Level 3 | DTE Electric | Affiliates
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	$ 295	$ 101

XML

Fair Value (Fair Value of Nuclear Decommissioning Trust Fund Assets) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Debt Securities, Available-for-sale [Line Items]
Nuclear decommissioning trust funds	$ 1,561	$ 1,378
DTE Electric
Debt Securities, Available-for-sale [Line Items]
Nuclear decommissioning trust funds	1,561	1,378
DTE Electric | Nuclear decommissioning trust fund
Debt Securities, Available-for-sale [Line Items]
Nuclear decommissioning trust funds	1,561	1,378
DTE Electric | Nuclear decommissioning trust fund | Fermi 2
Debt Securities, Available-for-sale [Line Items]
Nuclear decommissioning trust funds	1,553	1,372
DTE Electric | Nuclear decommissioning trust fund | Fermi 1
Debt Securities, Available-for-sale [Line Items]
Nuclear decommissioning trust funds	3	3
DTE Electric | Nuclear decommissioning trust fund | Low-level radioactive waste
Debt Securities, Available-for-sale [Line Items]
Nuclear decommissioning trust funds	$ 5	$ 3

XML

Fair Value (Gains and Losses and Proceeds from the Sale of Securities by the Nuclear Decommissioning Trust Funds) (Details) - DTE Electric - Nuclear decommissioning trust fund - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Debt Securities, Available-for-sale [Line Items]
Realized gains	$ 17	$ 19	$ 28	$ 42
Realized losses	(10)	(6)	(17)	(15)
Proceeds from sale of securities	$ 220	$ 280	$ 396	$ 616

XML

Fair Value (Fair Value and Unrealized Gains and Losses for the Nuclear Decommissioning Trust Funds) (Details) - DTE Electric - Nuclear decommissioning trust fund - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Debt Securities, Available-for-sale [Line Items]
Fair Value	$ 1,561	$ 1,378
Fixed income securities, fair value	532	502
Private equity and other, fair value	32	20
Cash equivalents, fair value	9	5
Unrealized Gains	356	242
Fixed income securities, unrealized gains	21	7
Unrealized Losses	(50)	(87)
Fixed income securities, unrealized losses	(1)	(8)
Equity securities
Debt Securities, Available-for-sale [Line Items]
Fair Value	988	851
Unrealized Gains	335	235
Unrealized Losses	$ (49)	$ (79)

XML

Fair Value Fair Value (Fair Value of Fixed Income Securities Held in Nuclear Decommissioning Trust Funds (Details) - Fixed income securities - Nuclear decommissioning trust fund $ in Millions	Jun. 30, 2019 USD ($)
Debt Securities, Available-for-sale [Line Items]
Due within one year	$ 17
Due after one through five years	103
Due after five through ten years	110
Due after ten years	302
Available-for-sale securities total	$ 532

XML

Fair Value (Details Textuals) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Fair Value Disclosures [Abstract]
Equity securities realized gains	$ 7	$ 1	$ 24
Equity securities realized losses				$ 1

XML

Financial and Other Derivative Instruments (Fair Value of Derivative Instruments) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Derivatives, Fair Value [Line Items]
Derivative Assets	$ 565	$ 663
Derivative Liabilities	(572)	(669)
Current derivative assets
Derivatives, Fair Value [Line Items]
Derivative Assets	449	563
Current derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative Liabilities	(434)	(518)
Noncurrent derivative assets
Derivatives, Fair Value [Line Items]
Derivative Assets	116	100
Noncurrent derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative Liabilities	(138)	(151)
Interest rate contracts
Derivatives, Fair Value [Line Items]
Derivative Liabilities	(15)	(3)
Natural gas
Derivatives, Fair Value [Line Items]
Derivative Assets	235	349
Derivative Liabilities	(236)	(380)
Electricity
Derivatives, Fair Value [Line Items]
Derivative Assets	320	303
Derivative Liabilities	(321)	(285)
Other
Derivatives, Fair Value [Line Items]
Derivative Assets	9	7
Derivative Liabilities	0	(1)
Foreign currency exchange contracts
Derivatives, Fair Value [Line Items]
Derivative Assets	1	4
Derivatives designated as hedging instruments | Interest rate contracts
Derivatives, Fair Value [Line Items]
Derivative Assets	0	0
Derivative Liabilities	(15)	(3)
Derivatives not designated as hedging instruments
Derivatives, Fair Value [Line Items]
Derivative Assets	565	663
Derivative Liabilities	(557)	(666)
Derivatives not designated as hedging instruments | DTE Electric
Derivatives, Fair Value [Line Items]
Derivative Assets	9	6
Derivatives not designated as hedging instruments | Natural gas
Derivatives, Fair Value [Line Items]
Derivative Assets	235	349
Derivative Liabilities	(236)	(380)
Derivatives not designated as hedging instruments | Electricity
Derivatives, Fair Value [Line Items]
Derivative Assets	320	303
Derivative Liabilities	(321)	(285)
Derivatives not designated as hedging instruments | Other
Derivatives, Fair Value [Line Items]
Derivative Assets	9	7
Derivative Liabilities	0	(1)
Derivatives not designated as hedging instruments | Foreign currency exchange contracts
Derivatives, Fair Value [Line Items]
Derivative Assets	1	4
Derivative Liabilities	0	0
Derivatives not designated as hedging instruments | FTRs — Other current assets | DTE Electric
Derivatives, Fair Value [Line Items]
Derivative Assets	$ 9	$ 6

XML

Financial and Other Derivative Instruments (Details Textuals) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Letters of credit that could be used to offset net derivative liabilities	$ 5	$ 4
Letters of credit received that could be used to offset net derivative assets	2	$ 8
Contractual obligation to post collateral in event of downgrade to below investment grade	541
Derivative net liability position aggregate fair value	493
Collateral already posted fair value	4
Derivative net asset position, fair value	395
Remaining amount of offsets to derivative net liability positions for hard and soft trigger provisions	$ 94

XML

Financial and Other Derivative Instruments (Net Cash Collateral Offsetting Arrangements) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Cash collateral netted against Derivative assets	$ 0	$ (17)
Cash collateral netted against Derivative liabilities	4	0
Cash collateral recorded in Accounts receivable	12	10
Cash collateral recorded in Accounts payable	(3)	(6)
Total net cash collateral posted (received)	$ 13	$ (13)

XML

Financial and Other Derivative Instruments (Netting Offsets of Derivative Assets and Liabilities) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Derivative assets
Gross Amounts of Recognized Assets (Liabilities)	$ 565	$ 663
Gross Amounts Offset in the Consolidated Statements of Financial Position	(406)	(530)
Derivative assets, net	159	133
Derivative liabilities
Gross Amounts of Recognized Assets (Liabilities)	(572)	(669)
Gross Amounts Offset in the Consolidated Statements of Financial Position	410	513
Derivative liabilities, net	(162)	(156)
Natural gas
Derivative assets
Gross Amounts of Recognized Assets (Liabilities)	235	349
Gross Amounts Offset in the Consolidated Statements of Financial Position	(170)	(277)
Derivative assets, net	65	72
Derivative liabilities
Gross Amounts of Recognized Assets (Liabilities)	(236)	(380)
Gross Amounts Offset in the Consolidated Statements of Financial Position	170	272
Derivative liabilities, net	(66)	(108)
Electricity
Derivative assets
Gross Amounts of Recognized Assets (Liabilities)	320	303
Gross Amounts Offset in the Consolidated Statements of Financial Position	(236)	(252)
Derivative assets, net	84	51
Derivative liabilities
Gross Amounts of Recognized Assets (Liabilities)	(321)	(285)
Gross Amounts Offset in the Consolidated Statements of Financial Position	240	240
Derivative liabilities, net	(81)	(45)
Other
Derivative assets
Gross Amounts of Recognized Assets (Liabilities)	9	7
Gross Amounts Offset in the Consolidated Statements of Financial Position	0	(1)
Derivative assets, net	9	6
Derivative liabilities
Gross Amounts of Recognized Assets (Liabilities)	0	(1)
Gross Amounts Offset in the Consolidated Statements of Financial Position	0	1
Derivative liabilities, net	0	0
Interest rate contracts
Derivative liabilities
Gross Amounts of Recognized Assets (Liabilities)	(15)	(3)
Gross Amounts Offset in the Consolidated Statements of Financial Position	0	0
Derivative liabilities, net	(15)	(3)
Foreign currency exchange contracts
Derivative assets
Gross Amounts of Recognized Assets (Liabilities)	1	4
Gross Amounts Offset in the Consolidated Statements of Financial Position	0	0
Derivative assets, net	$ 1	$ 4

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Financial and Other Derivative Instruments (Netting Offsets Reconciliation to Balance Sheet) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Derivative Assets
Derivative Assets	$ 565	$ 663
Collateral adjustment	0	(17)
Derivative assets, current	113	102
Derivative assets, noncurrent	46	31
Derivative Liabilities
Derivative Liabilities	(572)	(669)
Collateral adjustment	4	0
Derivative liabilities, current	(94)	(67)
Derivative liabilities, noncurrent	(68)	(89)
Current derivative assets
Derivative Assets
Derivative Assets	449	563
Counterparty netting	(336)	(451)
Collateral adjustment	0	(10)
Derivative assets, current	113	102
Noncurrent derivative assets
Derivative Assets
Derivative Assets	116	100
Counterparty netting	(70)	(62)
Collateral adjustment	0	(7)
Derivative assets, noncurrent	46	31
Current derivative liabilities
Derivative Liabilities
Derivative Liabilities	(434)	(518)
Counterparty netting	336	451
Collateral adjustment	4	0
Derivative liabilities, current	(94)	(67)
Noncurrent derivative liabilities
Derivative Liabilities
Derivative Liabilities	(138)	(151)
Counterparty netting	70	62
Collateral adjustment	0	0
Derivative liabilities, noncurrent	$ (68)	$ (89)

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Financial and Other Derivative Instruments (Effect of Derivatives not Designated as Hedging Instruments on the Consolidated Statement of Operations) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	$ 7	$ 0	$ 13	$ (74)
Natural gas | Operating Revenues — Non-utility operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	24	(48)	9	(158)
Natural gas | Fuel, purchased power, and gas — non-utility
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	(30)	16	40	68
Electricity | Operating Revenues — Non-utility operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	16	28	(33)	11
Other | Operating Revenues — Non-utility operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	(1)	2	0	1
Foreign currency exchange contracts | Operating Revenues — Non-utility operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	$ (2)	$ 2	$ (3)	$ 4

XML

Financial and Other Derivative Instruments (Cumulative Gross Volume of Derivative Contracts Outstanding) (Details)	6 Months Ended
	Jun. 30, 2019 CAD ($) MWh MMBTU
Natural gas (MMBtu)
Derivative [Line Items]
Commodity | MMBTU	1,986,388,951
Electricity (MWh)
Derivative [Line Items]
Commodity | MWh	33,786,455
Foreign currency exchange (CAD)
Derivative [Line Items]
Foreign currency exchange (CAD) | $	$ 91,380,922

XML

Long-Term Debt (Details)	Jun. 30, 2019 USD ($)
Debt Instrument [Line Items]
Debt issued	$ 1,450,000,000
DTE Energy | Senior Notes | June 2019 2.60% Senior Notes Maturing 2022
Debt Instrument [Line Items]
Interest rate	2.60%
Debt issued	$ 300,000,000
DTE Energy | Senior Notes | June 2019 3.40% Senior Notes Maturing 2029
Debt Instrument [Line Items]
Interest rate	3.40%
Debt issued	$ 500,000,000
DTE Electric | Mortgage Bonds | February 2019 3.95% Mortgage Bonds Maturing 2049
Debt Instrument [Line Items]
Interest rate	3.95%
Debt issued	$ 650,000,000
DTE Gas | Mortgage Bonds | June 2019 2.95% First Mortgage Bonds Maturing 2029
Debt Instrument [Line Items]
Interest rate	2.95%
Debt issued	$ 140,000,000
DTE Gas | Mortgage Bonds | June 2019 3.72% First Mortgage Bonds Maturing 2049
Debt Instrument [Line Items]
Interest rate	3.72%
Debt issued	$ 140,000,000

XML

Short-Term Credit Arrangements and Borrowings (Details Textuals)	Jun. 30, 2019 USD ($)	Dec. 31, 2018 USD ($)
Short-term Debt [Line Items]
Other outstanding letters of credit	$ 182,000,000
Letter of credit
Short-term Debt [Line Items]
Other outstanding letters of credit	$ 179,000,000
DTE Electric
Short-term Debt [Line Items]
Ratio of indebtedness to net capital	0.51
Other outstanding letters of credit	$ 0
DTE Electric | Letter of credit
Short-term Debt [Line Items]
Other outstanding letters of credit	$ 0
DTE Gas
Short-term Debt [Line Items]
Ratio of indebtedness to net capital	0.47
Other outstanding letters of credit	$ 3,000,000
DTE Gas | Letter of credit
Short-term Debt [Line Items]
Other outstanding letters of credit	$ 0
DTE Energy
Short-term Debt [Line Items]
Ratio of indebtedness to net capital	0.57
Other outstanding letters of credit	$ 179,000,000
DTE Energy | Letter of credit
Short-term Debt [Line Items]
Other outstanding letters of credit	179,000,000
DTE Energy | Demand financing agreement
Short-term Debt [Line Items]
Maximum borrowing capacity, financing agreement	100,000,000
Maximum additional margin financing	50,000,000
Amount outstanding	107,000,000	$ 93,000,000
DTE Energy | Demand financing agreement plus letter of credit
Short-term Debt [Line Items]
Maximum borrowing capacity, financing agreement	150,000,000
DTE Energy | Other outstanding letters of credit | Letter of credit
Short-term Debt [Line Items]
Other outstanding letters of credit	$ 9,000,000
Maximum
Short-term Debt [Line Items]
Ratio of indebtedness to net capital	0.65

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Short-Term Credit Arrangements and Borrowings (Details)	Jun. 30, 2019 USD ($)
Availability under combined facilities
Maximum borrowing capacity	$ 2,520,000,000
Amounts outstanding	182,000,000
Net availability	2,338,000,000
DTE Electric
Availability under combined facilities
Maximum borrowing capacity	500,000,000
Amounts outstanding	0
Net availability	500,000,000
DTE Gas
Availability under combined facilities
Maximum borrowing capacity	300,000,000
Amounts outstanding	3,000,000
Net availability	297,000,000
DTE Energy
Availability under combined facilities
Maximum borrowing capacity	1,720,000,000
Amounts outstanding	179,000,000
Net availability	1,541,000,000
Letter of credit
Availability under combined facilities
Amounts outstanding	179,000,000
Letter of credit | DTE Electric
Availability under combined facilities
Amounts outstanding	0
Letter of credit | DTE Gas
Availability under combined facilities
Amounts outstanding	0
Letter of credit | DTE Energy
Availability under combined facilities
Amounts outstanding	179,000,000
Letter of credit | Unsecured letter of credit facility, expiring in February 2021
Availability under combined facilities
Maximum borrowing capacity	150,000,000
Letter of credit | Unsecured letter of credit facility, expiring in February 2021 | DTE Electric
Availability under combined facilities
Maximum borrowing capacity	0
Letter of credit | Unsecured letter of credit facility, expiring in February 2021 | DTE Gas
Availability under combined facilities
Maximum borrowing capacity	0
Letter of credit | Unsecured letter of credit facility, expiring in February 2021 | DTE Energy
Availability under combined facilities
Maximum borrowing capacity	150,000,000
Letter of credit | Unsecured letter of credit facility, expiring in September 2019
Availability under combined facilities
Maximum borrowing capacity	70,000,000
Letter of credit | Unsecured letter of credit facility, expiring in September 2019 | DTE Electric
Availability under combined facilities
Maximum borrowing capacity	0
Letter of credit | Unsecured letter of credit facility, expiring in September 2019 | DTE Gas
Availability under combined facilities
Maximum borrowing capacity	0
Letter of credit | Unsecured letter of credit facility, expiring in September 2019 | DTE Energy
Availability under combined facilities
Maximum borrowing capacity	70,000,000
Revolving credit facility | Unsecured revolving credit facility, expiring April 2024
Availability under combined facilities
Maximum borrowing capacity	2,300,000,000
Revolving credit facility | Unsecured revolving credit facility, expiring April 2024 | DTE Electric
Availability under combined facilities
Maximum borrowing capacity	500,000,000
Revolving credit facility | Unsecured revolving credit facility, expiring April 2024 | DTE Gas
Availability under combined facilities
Maximum borrowing capacity	300,000,000
Revolving credit facility | Unsecured revolving credit facility, expiring April 2024 | DTE Energy
Availability under combined facilities
Maximum borrowing capacity	1,500,000,000
Commercial paper issuances
Availability under combined facilities
Amounts outstanding	3,000,000
Commercial paper issuances | DTE Electric
Availability under combined facilities
Amounts outstanding	0
Commercial paper issuances | DTE Gas
Availability under combined facilities
Amounts outstanding	3,000,000
Commercial paper issuances | DTE Energy
Availability under combined facilities
Amounts outstanding	$ 0

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Leases Leases (Details Textuals) $ in Millions	3 Months Ended	6 Months Ended	12 Months Ended
	Jun. 30, 2019 USD ($)	Jun. 30, 2019 USD ($)	Dec. 31, 2018 USD ($) agreement	Dec. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)
Lessee, Lease, Description [Line Items]
Term of finance lease contract	20 years	20 years
Finance lease contract, renewal option extension term	5 years	5 years
Percent ownership interest in Vector Pipeline	40.00%	40.00%
Depreciation expense associated with property under operating leases	$ 5	$ 13
Interest income recognized under finance leases	$ 1	$ 2
Contingent rental revenues			$ 107	$ 91	$ 101
Pipeline System Lease
Lessee, Lease, Description [Line Items]
Percent ownership interest in Vector Pipeline			40.00%
Lessor capital lease renewal terms			5 years
Number of energy services agreements | agreement			2
Minimum
Lessee, Lease, Description [Line Items]
Lease terms		2 years
Term of operating lease contracts	3 years	3 years
Maximum
Lessee, Lease, Description [Line Items]
Lease terms		40 years
Term of operating lease contracts	24 years	24 years
DTE Electric | Minimum
Lessee, Lease, Description [Line Items]
Lease terms		2 years
DTE Electric | Maximum
Lessee, Lease, Description [Line Items]
Lease terms		40 years

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Leases (Components of Lease Cost) (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2019
Lessee, Lease, Description [Line Items]
Operating lease cost	$ 10	$ 21
Finance lease cost:
Amortization of right-of-use assets	2	3
Interest of lease liabilities	0	0
Total finance lease cost	2	3
Variable lease cost	1	6
Short-term lease cost	3	5
Total lease cost	16	35
DTE Electric
Lessee, Lease, Description [Line Items]
Operating lease cost	4	8
Finance lease cost:
Amortization of right-of-use assets	2	3
Interest of lease liabilities	0	0
Total finance lease cost	2	3
Variable lease cost	0	0
Short-term lease cost	0	1
Total lease cost	$ 6	$ 12

XML

Leases (Other Information) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2019 USD ($)
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows from finance leases	$ 3
Operating cash flows from operating leases	19
Right-of-use assets obtained in exchange for lease obligations:
Operating leases	$ 22
Weighted Average Remaining Lease Term
Operating leases	9 years 10 months 24 days
Finance leases	2 years 6 months
Weighted Average Discount Rate
Operating leases	3.80%
Finance leases	3.10%
DTE Electric
Cash paid for amounts included in the measurement of these liabilities:
Operating cash flows from finance leases	$ 3
Operating cash flows from operating leases	7
Right-of-use assets obtained in exchange for lease obligations:
Operating leases	$ 1
Weighted Average Remaining Lease Term
Operating leases	10 years 4 months 24 days
Finance leases	2 years 6 months
Weighted Average Discount Rate
Operating leases	3.70%
Finance leases	3.10%

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Leases (Future Minimum Lease Payments - Topic 842) (Details) $ in Millions	Jun. 30, 2019 USD ($)
Operating Leases
2019	$ 21
2020	32
2021	23
2022	16
2023	13
2024 and thereafter	61
Total future minimum lease payments	166
Imputed interest	(30)
Total	136
Finance Leases
2019	2
2020	4
2021	3
2022	0
2023	0
2024 and thereafter	0
Total future minimum lease payments	9
Imputed interest	0
Total	9
DTE Electric
Operating Leases
2019	9
2020	12
2021	11
2022	7
2023	6
2024 and thereafter	30
Total future minimum lease payments	75
Imputed interest	(14)
Total	61
Finance Leases
2019	2
2020	4
2021	3
2022	0
2023	0
2024 and thereafter	0
Total future minimum lease payments	9
Imputed interest	0
Total	$ 9

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Leases (Finance Leases Reported on Consolidated Statements of Financial Position) (Details) $ in Millions	Jun. 30, 2019 USD ($)
Lessee, Lease, Description [Line Items]
Right-of-use assets, within Property, plant, and equipment, net	$ 9
Current lease liabilities, within Current Liabilities — Other	3
DTE Electric
Lessee, Lease, Description [Line Items]
Right-of-use assets, within Property, plant, and equipment, net	9
Current lease liabilities, within Current Liabilities — Other	$ 3

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Leases (Future Minimum Lease Payments for Operating Leases - Topic 840) (Details) $ in Millions	Dec. 31, 2018 USD ($)
Lessee, Lease, Description [Line Items]
2019	$ 42
2020	30
2021	18
2022	11
2023	8
2024 and thereafter	45
Total future minimum lease payments	154
DTE Electric
Lessee, Lease, Description [Line Items]
2019	17
2020	12
2021	10
2022	7
2023	5
2024 and thereafter	29
Total future minimum lease payments	$ 80

XML

Leases (Lease Income Associated with Operating Leases) (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2019	Jun. 30, 2019
Leases [Abstract]
Fixed payments	$ 17	$ 34
Variable payments	25	52
Total lease income under operating leases	$ 42	$ 86

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Leases (Minimum Future Rental Revenues under Operating Leases) (Details) $ in Millions	Jun. 30, 2019 USD ($)
Leases [Abstract]
2019	$ 33
2020	66
2021	64
2022	22
2023	22
2024 and thereafter	216
Total minimum future rental revenues under operating leases	$ 423

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Leases (Property under Operating Leases - Topic 842) (Details) - USD ($) $ in Millions	Jun. 30, 2019	Dec. 31, 2018
Lessor, Lease, Description [Line Items]
Gross property under operating leases	$ 32,834	$ 31,810
Accumulated amortization of property under operating leases	10,537	$ 10,160
Property Under Operating Leases
Lessor, Lease, Description [Line Items]
Gross property under operating leases	443
Accumulated amortization of property under operating leases	$ 160

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Leases (Components of Net Investment in Finance Leases) (Details) $ in Millions	Jun. 30, 2019 USD ($)
Leases [Abstract]
2019	$ 5
2020	9
2021	0
2022	0
2023	0
2024 and thereafter	1
Total minimum future lease receipts	15
Residual value of leased pipeline	40
Less unearned income	7
Net investment in finance lease	48
Less current portion	5
Net investment in finance lease, noncurrent	$ 43

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Leases (Future Rental Revenues under Operating Leases) (Details) $ in Millions	Dec. 31, 2018 USD ($)
Leases [Abstract]
2019	$ 66
2020	66
2021	64
2022	20
2023	20
2024 and thereafter	196
Total minimum future rental revenues under non-cancelable operating leases	$ 432

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Leases (Net Investment in Capital Leases) (Details) $ in Millions	Dec. 31, 2018 USD ($)
Leases [Abstract]
2019	$ 10
2020	9
2021	0
2022	0
2023	0
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
Capital lease, noncurrent	$ 46

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Leases (Property under Operating Leases - Topic 840) (Details) $ in Millions	Dec. 31, 2018 USD ($)
Leases [Abstract]
Gross property under operating leases	$ 447
Accumulated amortization of property under operating leases	$ 148

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Commitments and Contingencies (Details Textuals)	6 Months Ended	12 Months Ended
	Jun. 30, 2019 USD ($) employee facility NOV plant site	Dec. 31, 2018 USD ($)	Jul. 05, 2019 CAD ($)	Jul. 31, 2009 plant
Loss Contingencies [Line Items]
Unrecorded unconditional purchase obligation	$ 3,900,000,000
Long-lived assets used in producing electric output for sale	$ 22,297,000,000	$ 21,650,000,000
Power and Industrial Projects
Loss Contingencies [Line Items]
Number of generating plants operated with ownership interest held | plant	5
Workforce subject to collective bargaining arrangements | Labor force concentration risk
Loss Contingencies [Line Items]
Number of employees | employee	5,200
Vector | Revolving Term Credit Facility
Loss Contingencies [Line Items]
Maximum potential liability under line of credit	$ 0
Vector | Revolving Term Credit Facility | Subsequent event
Loss Contingencies [Line Items]
Revolving term credit facility amount			$ 70,000,000
Pacific Gas and Electric Corporation | Power and Industrial Projects
Loss Contingencies [Line Items]
Long-lived assets used in producing electric output for sale	103,000,000
Equity investments, including note receivable	$ 73,000,000
Impairment loss		0
Other than temporary decline in equity investments		0
Synthetic fuel
Loss Contingencies [Line Items]
Number of days after expiration of statutes of limitations	90 days
Maximum potential liability	$ 400,000,000
Reduced emissions fuel guarantees
Loss Contingencies [Line Items]
Number of days after expiration of statutes of limitations	90 days
Maximum potential liability	$ 476,000,000
NEXUS pipeline | DTE Gas
Loss Contingencies [Line Items]
Maximum potential liability	$ 242,000,000
Guarantee termination, minimum threshold, period following end of primary term of capacity lease agreements	2 months
NEXUS pipeline | Texas Eastern Transmission, LP
Loss Contingencies [Line Items]
Maximum potential liability	$ 377,000,000
Percentage of payment obligations due	50.00%
Guarantee termination, minimum threshold, period following end of primary term of capacity lease agreements	2 months
NEXUS pipeline | Vector
Loss Contingencies [Line Items]
Maximum potential liability	$ 7,000,000
Percentage of payment obligations due	50.00%
Guarantee termination, minimum threshold, period following end of primary term of capacity lease agreements	15 years
NEXUS pipeline | Generation Pipeline, LLC
Loss Contingencies [Line Items]
Maximum potential liability	$ 15,000,000
Other guarantees
Loss Contingencies [Line Items]
Maximum potential liability	56,000,000
Performance surety bonds
Loss Contingencies [Line Items]
Performance bonds outstanding	$ 77,000,000
Reduction of Carbon Emissions by Early 2020s
Loss Contingencies [Line Items]
Goal to reduce carbon emissions, percentage	32.00%
Reduction of Carbon Emissions by 2030
Loss Contingencies [Line Items]
Goal to reduce carbon emissions, percentage	50.00%
Reduction of Carbon Emissions by 2040
Loss Contingencies [Line Items]
Goal to reduce carbon emissions, percentage	80.00%
DTE Electric
Loss Contingencies [Line Items]
Number of power plants in violation | plant				5
Number of NOVs/FOVs | NOV	2
Environmental capital expenditures through prior year end		2,400,000,000
Number of former MGP sites | site	3
Accrued for remediation	$ 8,000,000	7,000,000
Number of permitted engineered ash storage facilities owned | facility	3
Unrecorded unconditional purchase obligation	$ 2,200,000,000
Long-lived assets used in producing electric output for sale	$ 15,963,000,000	15,437,000,000
DTE Electric | Workforce subject to collective bargaining arrangements | Labor force concentration risk
Loss Contingencies [Line Items]
Number of employees | employee	2,800
DTE Gas
Loss Contingencies [Line Items]
Number of former MGP sites | site	14
Accrued for remediation	$ 27,000,000	$ 25,000,000
Amortization period (in years)	10 years
DTE Gas | NEXUS pipeline | DTE Gas
Loss Contingencies [Line Items]
Percentage of payment obligations due	50.00%
DTE Gas | Clean up completed and site closed
Loss Contingencies [Line Items]
Number of former MGP sites | site	7
DTE Gas | Partial closure complete
Loss Contingencies [Line Items]
Number of former MGP sites | site	7
NEXUS | NEXUS pipeline | DTE Gas
Loss Contingencies [Line Items]
Agreement term	15 years
NEXUS | NEXUS pipeline | Texas Eastern Transmission, LP
Loss Contingencies [Line Items]
Agreement term	15 years
NEXUS | NEXUS pipeline | Vector
Loss Contingencies [Line Items]
Agreement term	15 years

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Retirement Benefits and Trusteed Assets (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 21	$ 25	$ 42	$ 50
Interest cost	54	50	109	100
Expected return on plan assets	(81)	(83)	(162)	(165)
Amortization of net actuarial loss	34	45	66	89
Amortization of prior service credit	0	0	0	0
Net periodic benefit cost (credit)	28	37	55	74
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	6	7	11	14
Interest cost	17	17	35	34
Expected return on plan assets	(31)	(35)	(62)	(71)
Amortization of net actuarial loss	3	2	6	5
Amortization of prior service credit	(2)	0	(4)	0
Net periodic benefit cost (credit)	(7)	(9)	(14)	(18)
Other Postretirement Benefits | DTE Electric
Defined Benefit Plan Disclosure [Line Items]
Service cost	4	5	8	10
Interest cost	14	14	27	27
Expected return on plan assets	(21)	(25)	(42)	(49)
Amortization of net actuarial loss	1	2	2	4
Amortization of prior service credit	(3)	0	(4)	0
Net periodic benefit cost (credit)	$ (5)	$ (4)	$ (9)	$ (8)

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Retirement Benefits and Trusteed Assets (Details Textuals) - USD ($)	1 Months Ended	3 Months Ended		6 Months Ended
	Mar. 31, 2019	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Maximum contribution amount		$ 50,000,000		$ 50,000,000
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Maximum contribution amount		0		0
DTE Electric | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Pension cost	$ 100,000,000	$ 22,000,000	$ 30,000,000	$ 45,000,000	$ 60,000,000

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Retirement Benefits and Trusteed Assets - VEBA Contributions (Details) - USD ($) $ / shares in Units, $ in Millions		3 Months Ended
	Mar. 05, 2019	Mar. 31, 2019	Mar. 31, 2018
Defined Contribution Plan Disclosure [Line Items]
Amount		$ 100	$ 175
Pension Benefits
Defined Contribution Plan Disclosure [Line Items]
Number of Shares (in shares)	814,597
Price per Share (in dollars per share)	$ 122.76
Amount	$ 100

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Segment and Related Information (Details Textuals) customer in Millions	Jun. 30, 2019 customer
Segment Reporting [Abstract]
Number of electric utility customers	2.2
Number of gas utility customers	1.3

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Segment and Related Information (Financial Data - Inter-segment Billing) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Segment Reporting Information [Line Items]
Revenues	$ (2,888)	$ (3,159)	$ (6,402)	$ (6,912)
Electric
Segment Reporting Information [Line Items]
Revenues	(1,190)	(1,276)	(2,425)	(2,481)
Gas
Segment Reporting Information [Line Items]
Revenues	(243)	(255)	(888)	(805)
Gas Storage and Pipelines
Segment Reporting Information [Line Items]
Revenues	(121)	(122)	(237)	(241)
Power and Industrial Projects
Segment Reporting Information [Line Items]
Revenues	(402)	(538)	(790)	(1,105)
Energy Trading
Segment Reporting Information [Line Items]
Revenues	(1,113)	(1,164)	(2,414)	(2,662)
Reconciliation and Eliminations
Segment Reporting Information [Line Items]
Revenues	181	198	353	384
Reconciliation and Eliminations | Electric
Segment Reporting Information [Line Items]
Revenues	13	13	27	26
Reconciliation and Eliminations | Gas
Segment Reporting Information [Line Items]
Revenues	3	4	5	6
Reconciliation and Eliminations | Gas Storage and Pipelines
Segment Reporting Information [Line Items]
Revenues	3	14	6	22
Reconciliation and Eliminations | Power and Industrial Projects
Segment Reporting Information [Line Items]
Revenues	157	162	302	317
Reconciliation and Eliminations | Energy Trading
Segment Reporting Information [Line Items]
Revenues	5	5	12	12
Reconciliation and Eliminations | Corporate and Other
Segment Reporting Information [Line Items]
Revenues	$ 0	$ 0	$ 1	$ 1

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Segment and Related Information (Financial Data - Operating Revenues including Inter-segment Revenues) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues — Utility operations	$ 1,417	$ 1,514	$ 3,281	$ 3,254
Operating Revenues — Non-utility operations	1,471	1,645	3,121	3,658
Operating Revenues	2,888	3,159	6,402	6,912
Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues — Non-utility operations	(181)	(198)	(353)	(384)
Operating Revenues	(181)	(198)	(353)	(384)
Electric
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	1,190	1,276	2,425	2,481
Electric | Operating segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues — Utility operations	1,190	1,276	2,425	2,481
Electric | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	(13)	(13)	(27)	(26)
Gas
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	243	255	888	805
Gas | Operating segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues — Utility operations	243	255	888	805
Gas | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	(3)	(4)	(5)	(6)
Gas Storage and Pipelines
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	121	122	237	241
Gas Storage and Pipelines | Operating segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues — Non-utility operations	121	122	237	241
Gas Storage and Pipelines | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	(3)	(14)	(6)	(22)
Power and Industrial Projects
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	402	538	790	1,105
Power and Industrial Projects | Operating segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues — Non-utility operations	402	538	790	1,105
Power and Industrial Projects | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	(157)	(162)	(302)	(317)
Energy Trading
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	1,113	1,164	2,414	2,662
Energy Trading | Operating segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues — Non-utility operations	1,113	1,164	2,414	2,662
Energy Trading | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	(5)	(5)	(12)	(12)
Corporate and Other | Operating segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues — Non-utility operations	0	2	1	2
Corporate and Other | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	$ 0	$ 0	$ (1)	$ (1)

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Segment and Related Information (Financial Data - Net Income (Loss) Attributable to DTE Energy by Segment) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2019	Jun. 30, 2018	Jun. 30, 2019	Jun. 30, 2018
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income Attributable to DTE Energy Company	$ 182	$ 234	$ 583	$ 595
Electric
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income Attributable to DTE Energy Company	133	163	280	303
Gas
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income Attributable to DTE Energy Company	8	14	159	118
Gas Storage and Pipelines
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income Attributable to DTE Energy Company	50	60	98	122
Power and Industrial Projects
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income Attributable to DTE Energy Company	29	43	55	88
Energy Trading
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income Attributable to DTE Energy Company	(6)	(5)	26	26
Corporate and Other
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income Attributable to DTE Energy Company	$ (32)	$ (41)	$ (35)	$ (62)