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 March 31, 2017

Commission File Number	Registrants; State of Incorporation; Address; and Telephone Number	I.R.S. Employer Identification No.
1-11607	DTE Energy Company (a Michigan corporation) One Energy Plaza Detroit, Michigan 48226-1279 313-235-4000	38-3217752
1-2198	DTE Electric Company (a Michigan corporation) One Energy Plaza Detroit, Michigan 48226-1279 313-235-4000	38-0478650

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 x No oDTE Electric Company (DTE Electric)    Yes x No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files).

DTE Energy                Yes x No oDTE Electric                Yes x No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, 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 x	Accelerated filer o	Non-accelerated filer o	Smaller reporting company o
			(Do not check if a smaller reporting company)	Emerging growth company o
DTE Electric	Large accelerated filer o	Accelerated filer o	Non-accelerated filer x	Smaller reporting company o
			(Do not check if a smaller reporting company)	Emerging growth company o

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. o

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

DTE Energy                Yes o No xDTE Electric                Yes o No x

Number of shares of Common Stock outstanding at March 31, 2017:

Registrant	Description	Shares
DTE Energy	Common Stock, without par value	179,387,424
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 an individual registrant is filed by such registrant solely on its 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.

THIS PAGE INTENTIONALLY LEFT BLANK

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)	11
	Combined Notes to Consolidated Financial Statements (Unaudited)	17
	Note 1 — Organization and Basis of Presentation	17
	Note 2 — Significant Accounting Policies	20
	Note 3 — New Accounting Pronouncements	21
	Note 4 — Acquisition	22
	Note 5 — Regulatory Matters	24
	Note 6 — Earnings Per Share	25
	Note 7 — Fair Value	26
	Note 8 — Financial and Other Derivative Instruments	33
	Note 9 — Long-Term Debt	37
	Note 10 — Short-Term Credit Arrangements and Borrowings	38
	Note 11 — Commitments and Contingencies	39
	Note 12 — Retirement Benefits and Trusteed Assets	43
	Note 13 — Segment and Related Information	44
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	45
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	59
Item 4.	Controls and Procedures	62
PART II - OTHER INFORMATION
Item 1.	Legal Proceedings	63
Item 1A.	Risk Factors	63
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	63
Item 6.	Exhibits	64
	Signatures	65

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
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
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
MDEQ	Michigan Department of Environmental Quality
MPSC	Michigan Public Service Commission
MTM	Mark-to-market
NAV	Net Asset Value
NEXUS	NEXUS Gas Transmission, LLC
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
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.
REF	Reduced Emissions Fuel
Registrants	DTE Energy and DTE Electric

1

DEFINITIONS

Retail access	Michigan legislation provided customers the option of access to alternative suppliers for electricity and natural gas.
SGG	Stonewall Gas Gathering is a midstream natural gas asset located in West Virginia. DTE Energy purchased 55% of SGG in October 2016, and this asset is part of DTE Energy's Gas Storage and Pipelines segment.
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.
SO2	Sulfur Dioxide
VIE	Variable Interest Entity

Units of Measurement
Bcf	Billion cubic feet of natural gas
BTU	Heat value (energy content) of fuel
MMBtu	One million BTU
MWh	Megawatthour 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 of 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 report 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 2016 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,” “projected,” “aspiration,” 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;

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

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

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

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

• 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;

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

• changes in the financial condition of DTE Energy's 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;

3

• 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;

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

• employee relations and the impact of collective bargaining agreements;

• the risk of a major safety incident at an electric distribution or generation facility and, for DTE Energy, a gas storage, transmission, or distribution facility;

• 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;

• implementation of new information systems; 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 March 31,
	2017			2016
	(In millions, except per share amounts)
Operating Revenues
Utility operations	$	1,718		$	1,664
Non-utility operations	1,518			902
	3,236			2,566
Operating Expenses
Fuel, purchased power, and gas — utility	529			565
Fuel, purchased power, and gas — non-utility	1,180			776
Operation and maintenance	600			516
Depreciation and amortization	249			229
Taxes other than income	109			99
	2,667			2,185
Operating Income	569			381
Other (Income) and Deductions
Interest expense	125			113
Interest income	(3		)	(11		)
Other income	(64		)	(52		)
Other expenses	7			8
	65			58
Income Before Income Taxes	504			323
Income Tax Expense	110			83
Net Income	394			240
Less: Net Loss Attributable to Noncontrolling Interests	(6		)	(7		)
Net Income Attributable to DTE Energy Company	$	400		$	247
Basic Earnings per Common Share
Net Income Attributable to DTE Energy Company	$	2.23		$	1.38
Diluted Earnings per Common Share
Net Income Attributable to DTE Energy Company	$	2.23		$	1.37
Weighted Average Common Shares Outstanding
Basic	179			179
Diluted	179			180
Dividends Declared per Common Share	$	0.825		$	0.73

See Combined Notes to Consolidated Financial Statements (Unaudited)

5

DTE Energy Company

Consolidated Statements of Comprehensive Income (Unaudited)

	Three Months Ended March 31,
	2017			2016
	(In millions)
Net Income	$	394		$	240
Other comprehensive income, net of tax:
Benefit obligations, net of taxes of $2, for both periods	4			3
Foreign currency translation	—			2
Other comprehensive income	4			5
Comprehensive income	398			245
Less comprehensive loss attributable to noncontrolling interests	(6		)	(7		)
Comprehensive Income Attributable to DTE Energy Company	$	404		$	252

See Combined Notes to Consolidated Financial Statements (Unaudited)

6

DTE Energy Company

Consolidated Statements of Financial Position (Unaudited)

	March 31,			December 31,
	2017			2016
	(In millions)
ASSETS
Current Assets
Cash and cash equivalents	$	82		$	92
Restricted cash	20			21
Accounts receivable (less allowance for doubtful accounts of $32 and $41, respectively)
Customer	1,408			1,522
Other	101			71
Inventories
Fuel and gas	286			416
Materials and supplies	354			356
Derivative assets	68			47
Regulatory assets	26			42
Other	222			195
	2,567			2,762
Investments
Nuclear decommissioning trust funds	1,364			1,320
Investments in equity method investees	868			752
Other	210			201
	2,442			2,273
Property
Property, plant, and equipment	30,287			30,029
Accumulated depreciation and amortization	(10,421		)	(10,299		)
	19,866			19,730
Other Assets
Goodwill	2,292			2,286
Regulatory assets	3,833			3,871
Intangible assets	837			842
Notes receivable	71			73
Derivative assets	73			34
Other	168			170
	7,274			7,276
Total Assets	$	32,149		$	32,041

See Combined Notes to Consolidated Financial Statements (Unaudited)

7

DTE Energy Company

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

	March 31,			December 31,
	2017			2016
	(In millions, except shares)
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	910		$	1,079
Accrued interest	131			96
Dividends payable	148			148
Short-term borrowings	59			499
Current portion long-term debt, including capital leases	13			14
Derivative liabilities	33			69
Gas inventory equalization	86			—
Regulatory liabilities	37			34
Other	417			498
	1,834			2,437
Long-Term Debt (net of current portion)
Mortgage bonds, notes, and other	10,999			10,506
Junior subordinated debentures	756			756
Capital lease obligations	3			7
	11,758			11,269
Other Liabilities
Deferred income taxes	4,270			4,162
Regulatory liabilities	563			555
Asset retirement obligations	2,229			2,197
Unamortized investment tax credit	91			93
Derivative liabilities	93			98
Accrued pension liability	1,022			1,152
Accrued postretirement liability	63			36
Nuclear decommissioning	203			194
Other	335			349
	8,869			8,836
Commitments and Contingencies (Notes 5 and 11)
Equity
Common stock, without par value, 400,000,000 shares authorized, and 179,387,424 and 179,432,581 shares issued and outstanding, respectively	3,958			4,030
Retained earnings	5,365			5,114
Accumulated other comprehensive loss	(129		)	(133		)
Total DTE Energy Company Equity	9,194			9,011
Noncontrolling interests	494			488
Total Equity	9,688			9,499
Total Liabilities and Equity	$	32,149		$	32,041

See Combined Notes to Consolidated Financial Statements (Unaudited)

8

DTE Energy Company

Consolidated Statements of Cash Flows (Unaudited)

	Three Months Ended March 31,
	2017			2016
	(In millions)
Operating Activities
Net Income	$	394		$	240
Adjustments to reconcile Net Income to net cash from operating activities:
Depreciation and amortization	249			229
Nuclear fuel amortization	12			15
Allowance for equity funds used during construction	(7		)	(5		)
Deferred income taxes	100			80
Equity earnings of equity method investees	(26		)	(15		)
Dividends from equity method investees	18			18
Changes in assets and liabilities:
Accounts receivable, net	84			97
Inventories	135			143
Accounts payable	(33		)	(93		)
Gas inventory equalization	86			87
Accrued pension liability	(130		)	(3		)
Accrued postretirement liability	27			(29		)
Derivative assets and liabilities	(100		)	40
Regulatory assets and liabilities	128			34
Other current and noncurrent assets and liabilities	(150		)	(93		)
Net cash from operating activities	787			745
Investing Activities
Plant and equipment expenditures — utility	(533		)	(394		)
Plant and equipment expenditures — non-utility	(22		)	(30		)
Proceeds from sale of nuclear decommissioning trust fund assets	394			260
Investment in nuclear decommissioning trust funds	(378		)	(262		)
Distributions from equity method investees	6			3
Contributions to equity method investees	(112		)	(26		)
Other	4			12
Net cash used for investing activities	(641		)	(437		)
Financing Activities
Issuance of long-term debt, net of issuance costs	496			—
Redemption of long-term debt	(5		)	(11		)
Short-term borrowings, net	(440		)	(134		)
Repurchase of common stock	(51		)	(33		)
Dividends on common stock	(148		)	(131		)
Other	(8		)	(1		)
Net cash used for financing activities	(156		)	(310		)
Net Decrease in Cash and Cash Equivalents	(10		)	(2		)
Cash and Cash Equivalents at Beginning of Period	92			37
Cash and Cash Equivalents at End of Period	$	82		$	35
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	$	196		$	134

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, 2016	179,433		$	4,030		$	5,114		$	(133	)	$	488		$	9,499
Net Income (Loss)	—		—			400			—			(6		)	394
Dividends declared on common stock	—		—			(148		)	—			—			(148		)
Repurchase of common stock	(524	)	(51		)	—			—			—			(51		)
Benefit obligations, net of tax	—		—			—			4			—			4
Stock-based compensation, net contributions from noncontrolling interests, and other	478		(21		)	(1		)	—			12			(10		)
Balance, March 31, 2017	179,387		$	3,958		$	5,365		$	(129	)	$	494		$	9,688

See Combined Notes to Consolidated Financial Statements (Unaudited)

10

DTE Electric Company

Consolidated Statements of Operations (Unaudited)

	Three Months Ended March 31,
	2017			2016
	(In millions)
Operating Revenues — Utility operations	$	1,175		$	1,153
Operating Expenses
Fuel and purchased power — utility	314			335
Operation and maintenance	383			324
Depreciation and amortization	181			176
Taxes other than income	80			73
	958			908
Operating Income	217			245
Other (Income) and Deductions
Interest expense	66			65
Interest income	—			(8		)
Other income	(19		)	(16		)
Other expenses	7			7
	54			48
Income Before Income Taxes	163			197
Income Tax Expense	57			70
Net Income	$	106		$	127

See Combined Notes to Consolidated Financial Statements (Unaudited)

11

DTE Electric Company

Consolidated Statements of Comprehensive Income (Unaudited)

	Three Months Ended March 31,
	2017		2016
	(In millions)
Net Income	$	106	$	127
Other comprehensive income	—		—
Comprehensive Income	$	106	$	127

See Combined Notes to Consolidated Financial Statements (Unaudited)

12

DTE Electric Company

Consolidated Statements of Financial Position (Unaudited)

	March 31,			December 31,
	2017			2016
	(In millions)
ASSETS
Current Assets
Cash and cash equivalents	$	11		$	13
Accounts receivable (less allowance for doubtful accounts of $19 and $25, respectively)
Customer	654			728
Affiliates	19			12
Other	38			29
Inventories
Fuel	178			225
Materials and supplies	276			271
Regulatory assets	11			36
Prepaid property tax	89			45
Other	16			18
	1,292			1,377
Investments
Nuclear decommissioning trust funds	1,364			1,320
Other	34			36
	1,398			1,356
Property
Property, plant, and equipment	22,276			22,094
Accumulated depreciation and amortization	(7,812		)	(7,721		)
	14,464			14,373
Other Assets
Regulatory assets	3,090			3,113
Intangible assets	32			31
Prepaid postretirement costs — affiliates	114			114
Other	125			125
	3,361			3,383
Total Assets	$	20,515		$	20,489

See Combined Notes to Consolidated Financial Statements (Unaudited)

13

DTE Electric Company

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

	March 31,		December 31,
	2017		2016
	(In millions, except shares)
LIABILITIES AND SHAREHOLDER’S EQUITY
Current Liabilities
Accounts payable
Affiliates	$	55	$	58
Other	384		452
Accrued interest	72		65
Current portion long-term debt, including capital leases	5		6
Regulatory liabilities	33		27
Short-term borrowings
Affiliates	205		117
Other	59		62
Other	149		146
	962		933
Long-Term Debt (net of current portion)
Mortgage bonds, notes, and other	5,879		5,878
Capital lease obligations	3		7
	5,882		5,885
Other Liabilities
Deferred income taxes	3,850		3,793
Regulatory liabilities	241		229
Asset retirement obligations	2,041		2,012
Unamortized investment tax credit	88		90
Nuclear decommissioning	203		194
Accrued pension liability — affiliates	885		1,008
Accrued postretirement liability — affiliates	290		269
Other	79		81
	7,677		7,676
Commitments and Contingencies (Notes 5 and 11)
Shareholder’s Equity
Common stock, $10 par value, 400,000,000 shares authorized, and 138,632,324 shares issued and outstanding	4,206		4,206
Retained earnings	1,786		1,787
Accumulated other comprehensive income	2		2
Total Shareholder’s Equity	5,994		5,995
Total Liabilities and Shareholder’s Equity	$	20,515	$	20,489

See Combined Notes to Consolidated Financial Statements (Unaudited)

14

DTE Electric Company

Consolidated Statements of Cash Flows (Unaudited)

	Three Months Ended March 31,
	2017			2016
	(In millions)
Operating Activities
Net Income	$	106		$	127
Adjustments to reconcile Net Income to net cash from operating activities:
Depreciation and amortization	181			176
Nuclear fuel amortization	12			15
Allowance for equity funds used during construction	(6		)	(4		)
Deferred income taxes	57			70
Changes in assets and liabilities:
Accounts receivable, net	58			57
Inventories	44			31
Accounts payable	26			25
Accrued pension liability — affiliates	(123		)	3
Accrued postretirement liability — affiliates	21			(19		)
Regulatory assets and liabilities	122			40
Other current and noncurrent assets and liabilities	(87		)	(68		)
Net cash from operating activities	411			453
Investing Activities
Plant and equipment expenditures	(408		)	(315		)
Proceeds from sale of assets	—			6
Proceeds from sale of nuclear decommissioning trust fund assets	394			260
Investment in nuclear decommissioning trust funds	(378		)	(262		)
Other	5			14
Net cash used for investing activities	(387		)	(297		)
Financing Activities
Redemption of long-term debt	—			(10		)
Short-term borrowings, net — affiliate	88			22
Short-term borrowings, net — other	(3		)	(61		)
Dividends on common stock	(108		)	(105		)
Other	(3		)	—
Net cash used for financing activities	(26		)	(154		)
Net Increase (Decrease) in Cash and Cash Equivalents	(2		)	2
Cash and Cash Equivalents at Beginning of Period	13			15
Cash and Cash Equivalents at End of Period	$	11		$	17
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	$	134		$	100

See Combined Notes to Consolidated Financial Statements (Unaudited)

15

DTE Electric Company

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

				Additional Paid-in Capital		Retained Earnings			Accumulated Other Comprehensive Income
	Common Stock
	Shares	Amount									Total
	(Dollars in millions, shares in thousands)
Balance, December 31, 2016	138,632	$	1,386	$	2,820	$	1,787		$	2	$	5,995
Net Income	—	—		—		106			—		106
Dividends declared on common stock	—	—		—		(108		)	—		(108		)
Other	—	—		—		1			—		1
Balance, March 31, 2017	138,632	$	1,386	$	2,820	$	1,786		$	2	$	5,994

See Combined Notes to Consolidated Financial Statements (Unaudited)

16

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	Acquisition	DTE Energy
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
Note 10	Short-Term Credit Arrangements and Borrowings	DTE Energy and DTE Electric
Note 11	Commitments and Contingencies	DTE Energy and DTE Electric
Note 12	Retirement Benefits and Trusteed Assets	DTE Energy and DTE Electric
Note 13	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) natural gas pipelines, gathering, and storage; 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 2016 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, 2017.

17

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 accounted for under the equity method.

DTE Energy owns a 55% 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. See Note 4 to the Consolidated Financial Statements, "Acquisition," for more information.

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 March 31, 2017, 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 March 31, 2017, 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. For non-consolidated VIEs, the maximum risk exposure is generally limited to its investment, notes receivable, and future funding commitments.

18

DTE Energy Company — DTE Electric Company

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

The following table summarizes the major Consolidated Statements of Financial Position items for consolidated VIEs as of March 31, 2017 and December 31, 2016. All assets and liabilities of a consolidated VIE are presented where it has been determined that aconsolidated 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.

	March 31, 2017						December 31, 2016
	SGG(a)		Other		Total		SGG(a)		Other		Total
	(In millions)
ASSETS
Cash and cash equivalents	$	52	$	11	$	63	$	36	$	27	$	63
Restricted cash	—		7		7		—		7		7
Accounts receivable	10		19		29		8		34		42
Inventories	3		59		62		3		112		115
Property, plant, and equipment, net	397		75		472		398		76		474
Goodwill	22		—		22		17		—		17
Intangible assets	583		—		583		586		—		586
Other current and long-term assets	—		1		1		1		1		2
	$	1,067	$	172	$	1,239	$	1,049	$	257	$	1,306
LIABILITIES
Accounts payable and accrued current liabilities	$	19	$	21	$	40	$	19	$	32	$	51
Current portion long-term debt, including capital leases	—		5		5		—		5		5
Mortgage bonds, notes, and other	—		4		4		—		5		5
Other current and long-term liabilities	2		14		16		2		15		17
	$	21	$	44	$	65	$	21	$	57	$	78

_____________________________________

(a)Amounts shown are 100% of SGG's assets and liabilities, of which DTE Energy owns 55%.

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

	March 31, 2017		December 31, 2016
	(In millions)
Investments in equity method investees	$	186	$	187
Notes receivable	$	15	$	15
Future funding commitments	$	6	$	7

19

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 March 31,
	2017		2016
	(In millions)
Equity earnings of equity method investees	$	26	$	15
Income from REF investees	18		19
Gains from trading securities	8		5
Allowance for equity funds used during construction	7		5
Contract services	4		6
Other	1		2
	$	64	$	52

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

	Three Months Ended March 31,
	2017		2016
	(In millions)
Gains from trading securities allocated from DTE Energy	$	8	$	5
Allowance for equity funds used during construction	6		4
Contract services	4		6
Other	1		1
	$	19	$	16

Changes in Accumulated Other Comprehensive Income (Loss)

For the three months endedMarch 31, 2017 and 2016, reclassifications out of Accumulated other comprehensive income (loss) for the Registrants were not material. 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.

Income Taxes

The effective tax rate and unrecognized tax benefits of the Registrants are as follows:

	Effective Tax Rate				Unrecognized Tax Benefits
	Three Months Ended March 31,				March 31,
	2017		2016		2017
					(In millions)
DTE Energy	22	%	26	%	$	10
DTE Electric	35	%	36	%	$	13

The 4%decrease in DTE Energy's effective tax rate for the three months endedMarch 31, 2017 is primarily due to $13 million of excess tax benefits on stock-based compensation recognized in accordance with ASU 2016-09, Improvements to Employee Share-Based Payment Accounting, which was adopted effective July 1, 2016.

DTE Energy had $7 million of unrecognized tax benefits that, if recognized, would favorably impact its effective tax rate. DTE Electric had $8 million of unrecognized tax benefits that, 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.

20

DTE Energy Company — DTE Electric Company

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

DTE Electric had income tax receivables with DTE Energy of $10 million and $9 million at March 31, 2017 and December 31, 2016, respectively.

Unrecognized Compensation Costs

As of March 31, 2017, DTE Energy had $92 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 1.82 years.

Allocated Stock-Based Compensation

DTE Electric received an allocation of costs from DTE Energy associated with stock-based compensation of $8 million and $10 million for the three months ended March 31, 2017 and 2016, respectively.

NOTE 3 — NEW ACCOUNTING PRONOUNCEMENTS

Recently Adopted Pronouncements

In July 2015, the FASB issued ASU No. 2015-11, Inventory (Topic 330), Simplifying the Measurement of Inventory. The ASU replaces the current lower of cost or market test with a lower of cost or net realizable value test when cost is determined on a first-in, first-out or average cost basis. The standard is effective for public entities for annual reporting periods beginning after December 15, 2016, and interim periods therein. It is applied prospectively. The Registrants adopted this ASU at January 1, 2017. The adoption of the ASU did not have a significant impact on the Registrants' Consolidated Financial Statements.

Recently Issued Pronouncements

In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606), as amended. The objectives of this ASU are to improve upon revenue recognition requirements by providing a single comprehensive model to determine the measurement of revenue and timing of recognition. The core principle is that an entity will recognize revenue to depict the transfer of goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services. This ASU also requires expanded qualitative and quantitative disclosures regarding the nature, amount, timing, and uncertainty of revenues and cash flows arising from contracts with customers. The standard is effective for the first interim period within annual reporting periods beginning after December 15, 2017. The standard is to be applied retrospectively, and early adoption is permitted in the preceding year. The Registrants do not plan to early adopt the standard. The Registrants are currently assessing the impact of the ASU, as amended, on their Consolidated Financial Statements as well as the transition method the Registrants will use to adopt the guidance. The Registrants have completed the preliminary evaluations of the impact of this guidance and do not expect the ASU to significantly affect results of operations for tariff-based sales, which represent a majority of the Registrants' revenues, and the remaining non-tariff revenues. The Registrants will continue to evaluate the impact of the ASU on existing revenue recognition policies and procedures and monitor the unresolved industry-related issues. Specifically, the Registrants are considering whether the new guidance will affect accounting for certain contracts where collectibility is in question, contributions in aid of construction, and other utility industry-related areas. The Registrants are evaluating information that would be useful for users of the Consolidated Financial Statements, including information already provided in disclosures outside of the Combined Notes to the Consolidated Financial Statements.

In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842), a replacement of Leases (Topic 840). This guidance requires a lessee to account for leases as finance or operating leases. Both 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. For lessors, the standard modifies the classification criteria and the accounting for sales-type and direct financing leases. Entities will classify leases to determine how to recognize lease-related revenue and expense. This ASU is effective for public entities for fiscal years, and interim periods within those years, beginning after December 15, 2018, and early adoption is permitted. A modified retrospective approach is required for leases existing or entered into after the beginning of the earliest comparative period in the Consolidated Financial Statements. The Registrants expect an increase in assets and liabilities, however, they are currently assessing the impact of this ASU on their Consolidated Financial Statements.

21

DTE Energy Company — DTE Electric Company

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

In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments — Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments. The amendments in this update replace the incurred loss impairment methodology in current GAAP with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates.  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 are currently assessing the impact of this standard on their Consolidated Financial Statements.

In March 2017, the FASB issued ASU No. 2017-07, Compensation — Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. The amendments in this update require that an employer report the service cost component in the same line item or items as other compensation costs arising from services rendered by the pertinent employees during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside income from operations. The amendments in this update also allow only the service cost component to be eligible for capitalization when applicable. The standard will be applied retrospectively for the presentation of the service cost component and the other components of net periodic pension cost and net periodic postretirement benefit cost in the income statement and prospectively for the capitalization of the service cost component of net periodic pension cost and net periodic postretirement benefit in assets. The ASU is effective for the Registrants beginning after December 15, 2017, including interim periods therein. Early adoption is permitted. The components of net periodic benefit costs (credits) for pension benefits and other postretirement benefits are disclosed in Note 12 to the Consolidated Financial Statements, "Retirement Benefits and Trusteed Assets." The ASU will not have a significant impact on the Registrants' Consolidated Financial Statements.

NOTE 4 — ACQUISITION

Gas Storage and Pipelines Acquisition

Effective October 1, 2016, DTE Energy closed on the purchase of midstream natural gas assets in support of the strategy to continue to grow and earn competitive returns for shareholders. DTE Energy purchased 100% of AGS, located in Pennsylvania and West Virginia, and 40% of SGG, located in West Virginia, from M3 Midstream. In addition, DTE Energy purchased 15% of SGG from Vega Energy Partners, resulting in 55% total ownership of SGG by DTE Energy.

Consideration transferred for the entities acquired was approximately $1.2 billion paid in cash and the assumption of SGG debt of $204 million. The $204 million of debt was comprised of DTE Energy's 55% interest in SGG of $112 million and 45% related to noncontrolling interest partners of $92 million. The acquisition was financed through the issuance of Equity Units and Senior Notes. These entities are part of DTE Energy's Gas Storage and Pipelines segment which owns and manages a network of natural gas gathering, transmission, and storage facilities servicing the Midwest, Ontario, and Northeast markets. SGG has been deemed to be a VIE, and DTE Energy is the primary beneficiary. Thus, SGG's assets and liabilities are included in DTE Energy's Consolidated Statements of Financial Position. See Note 1 to the Consolidated Financial Statements, "Organization and Basis of Presentation," for more information.

DTE Energy has applied purchase accounting to the acquired entities. The allocation of the purchase price included in the Consolidated Statements of Financial Position is preliminary and may be revised up to one year from the date of acquisition due to adjustments in the estimated fair value of the assets acquired and the liabilities assumed. The purchase price is subject to (i) final working capital settlement adjustments, and (ii) resolution of any indemnification claims that might be deducted from the $130 million of cash consideration paid and held in escrow. As such, DTE Energy cannot estimate the potential amount of the additional revisions to the purchase price allocation in 2017. The excess purchase price over the fair value of net assets acquired totaled approximately $268 million and was classified as goodwill. During the first quarter of 2017, a final working capital adjustment was recognized resulting in an additional goodwill of approximately $6 million. The factors contributing to the recognition of goodwill are based on various strategic benefits that are expected to be realized from the AGS and SGG acquisition. The acquisition provides DTE Energy with 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 a new set of producer relationships that may lead to more partnering opportunities. The goodwill is expected to be deductible for income tax purposes.

22

DTE Energy Company — DTE Electric Company

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

The preliminary allocation of the purchase price was based on estimated fair values of the AGS and SGG assets acquired and liabilities assumed at the date of acquisition, October 1, 2016. The components of the preliminary purchase price allocation were as follows:

	(In millions)
Assets
Cash	$	83
Accounts receivable	24
Inventory	6
Property, plant, and equipment, net	730
Goodwill	268
Customer relationship intangibles	770
Other current assets	1
	$	1,882
Liabilities
Accounts payable	$	19
Other current liabilities	14
Long-term debt	204
Other long-term liabilities	26
	$	263
Less noncontrolling interest	390
Total cash consideration	$	1,229

The intangible assets recorded as a result of the acquisition pertain to existing customer relationships, which were valued at approximately $770 million as of the acquisition date. The fair value of the intangible assets acquired was estimated by applying the income approach. The income approach was based upon discounted projected future cash flows attributable to the existing contracts and agreements. The fair value measurement was based on significant unobservable inputs, including management estimates and assumptions, and thus represents a Level 3 measurement, pursuant to the applicable accounting guidance. Key estimates and inputs included revenue and expense projections and discount rates based on the risks associated with the entities. The intangible assets are amortized on a straight line basis over a period of 40 years, which is based on the number of years the assets are expected to economically contribute to the business. The expected economic benefit incorporates existing customer contracts with a weighted-average amortization life of 10 years and expected renewal rates, based on the estimated volume and production lives of gas resources in the region.

The fair value of the noncontrolling interest in the table above was derived based on the purchase price DTE Energy paid for the 55% interest in SGG.

DTE Energy evaluated pre-acquisition contingencies relating to AGS and SGG that existed as of the acquisition date. Based on the evaluation, DTE Energy determined that $39 million of certain pre-acquisition contingencies, related to repairing existing right-of-ways, are probable in nature and estimable as of the acquisition date. Accordingly, DTE Energy recorded its best estimates for these contingencies as part of the purchase accounting for AGS and SGG.

DTE Energy incurred $15 million of direct transaction costs for the year ended December 31, 2016. These costs were primarily related to advisory fees and included in Operation and maintenance in DTE Energy's 2016 Consolidated Statements of Operations.

DTE Energy's 2016 Consolidated Statements of Operations included Operating Revenues — Non-utility operations of $39 million and Net Income of $4 million associated with the acquired entities for the three-month period following the acquisition date, excluding the $15 million transaction costs described above. The pro forma financial information was not presented for DTE Energy because the effects of the acquisition were not material to the Consolidated Statements of Operations.

23

DTE Energy Company — DTE Electric Company

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

NOTE 5 — REGULATORY MATTERS

2016 Electric Rate Case Filing

DTE Electric filed a rate case with the MPSC on February 1, 2016 requesting an increase in base rates of $344 million based on a projected twelve-month period ending July 31, 2017. On August 1, 2016, DTE Electric self-implemented a base rate increase of $245 million. On January 31, 2017, the MPSC issued an order approving an annual revenue increase of $184 million for service rendered on or after February 7, 2017. The MPSC authorized a return on equity of 10.1%. DTE Electric has recorded a refund liability of $37 million, representing the total estimated refund due to customers, inclusive of interest, at March 31, 2017. DTE Electric will file a self-implementation reconciliation with the MPSC by April 30, 2017.

2017 Electric Rate Case Filing

DTE Electric filed a rate case with the MPSC on April 19, 2017 requesting an increase in base rates of $231 million based on a projected twelve-month period ending October 31, 2018. The requested increase in base rates is due primarily to an increase in net plant resulting from infrastructure investments, environmental compliance, and reliability improvement projects. The rate filing also includes projected changes in sales, operation and maintenance expenses, and working capital. The rate filing also requests an increase in return on equity from 10.1% to 10.5% on capital structure. DTE Electric anticipates self-implementing a rate increase in November 2017 with an MPSC order expected by April 2018.

PSCR Proceedings

The PSCR process is designed to allow DTE Electric to recover all of its power supply costs if incurred under reasonable and prudent policies and practices. DTE Electric's power supply costs include fuel and related transportation costs, purchased and net interchange power costs, NOx and SO₂ emission allowances costs, urea costs, transmission costs, MISO, and other related costs. The MPSC reviews these costs, policies, and practices for prudence in annual plan and reconciliation filings.

2015 PSCR Year — In March 2016, DTE Electric filed its 2015 PSCR reconciliation. The Administrative Law Judge and certain intervenors in the reconciliation case have challenged the recovery of approximately $13 million of costs related to a customer settlement. Resolution of this matter is expected in 2017.

2016 DTE Main Electric Depreciation Case Filing

DTE Electric filed a depreciation case with the MPSC on November 1, 2016 requesting an increase in depreciation rates of $156 million when compared to current depreciation rates for Plant in service balances as of December 31, 2015. An MPSC order in this case is expected in 2018.

24

DTE Energy Company — DTE Electric Company

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

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 March 31,
	2017			2016
	(In millions, except per share amounts)
Basic Earnings per Share
Net income attributable to DTE Energy Company	$	400		$	247
Less allocation of earnings to net restricted stock awards	(1		)	—
Net income available to common shareholders — basic	$	399		$	247
Average number of common shares outstanding	179			179
Basic Earnings per Common Share	$	2.23		$	1.38
Diluted Earnings per Share
Net income attributable to DTE Energy Company	$	400		$	247
Less allocation of earnings to net restricted stock awards	(1		)	—
Net income available to common shareholders — diluted	$	399		$	247
Average number of common shares outstanding	179			180
Diluted Earnings per Common Share(a)	$	2.23		$	1.37

_______________________________________

(a) The October 2016 Equity Units are potentially dilutive securities but were excluded from the calculation of diluted EPS for the three months ended March 31, 2017, as the dilutive stock price threshold was not met.

25

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 March 31, 2017 and December 31, 2016. 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.

26

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:

	March 31, 2017															December 31, 2016
	Level 1			Level 2			Level 3			Netting(a)			Net Balance			Level 1			Level 2			Level 3			Netting(a)			Net Balance
	(In millions)
Assets:
Cash equivalents(b)	$	14		$	3		$	—		$	—		$	17		$	14		$	3		$	—		$	—		$	17
Nuclear decommissioning trusts(c)
Equity securities	890			—			—			—			890			887			—			—			—			887
Fixed income securities	11			460			—			—			471			11			414			—			—			425
Cash equivalents	3			—			—			—			3			8			—			—			—			8
Other investments(d)
Equity securities	110			—			—			—			110			104			—			—			—			104
Fixed income securities	63			—			—			—			63			61			—			—			—			61
Derivative assets
Commodity Contracts
Natural Gas	82			151			71			(206		)	98			216			79			53			(306		)	42
Electricity	—			152			34			(146		)	40			—			154			39			(157		)	36
Other	—			—			1			—			1			—			—			2			—			2
Foreign currency exchange contracts	—			5			—			(3		)	2			—			6			—			(5		)	1
Total derivative assets	82			308			106			(355		)	141			216			239			94			(468		)	81
Total	$	1,173		$	771		$	106		$	(355	)	$	1,695		$	1,301		$	656		$	94		$	(468	)	$	1,583
Liabilities:
Derivative liabilities
Commodity Contracts
Natural Gas	$	(82	)	$	(121	)	$	(86	)	$	202		$	(87	)	$	(226	)	$	(86	)	$	(149	)	$	321		$	(140	)
Electricity	—			(157		)	(40		)	158			(39		)	—			(159		)	(30		)	163			(26		)
Other	—			—			(3		)	3			—			—			—			(3		)	2			(1		)
Foreign currency exchange contracts	—			(2		)	—			2			—			—			(3		)	—			3			—
Total derivative liabilities	(82		)	(280		)	(129		)	365			(126		)	(226		)	(248		)	(182		)	489			(167		)
Total	$	(82	)	$	(280	)	$	(129	)	$	365		$	(126	)	$	(226	)	$	(248	)	$	(182	)	$	489		$	(167	)
Net Assets (Liabilities) at end of period	$	1,091		$	491		$	(23	)	$	10		$	1,569		$	1,075		$	408		$	(88	)	$	21		$	1,416
Assets:
Current	$	78		$	228		$	60		$	(281	)	$	85		$	205		$	199		$	60		$	(400	)	$	64
Noncurrent	1,095			543			46			(74		)	1,610			1,096			457			34			(68		)	1,519
Total Assets	$	1,173		$	771		$	106		$	(355	)	$	1,695		$	1,301		$	656		$	94		$	(468	)	$	1,583
Liabilities:
Current	$	(63	)	$	(213	)	$	(36	)	$	279		$	(33	)	$	(203	)	$	(211	)	$	(79	)	$	424		$	(69	)
Noncurrent	(19		)	(67		)	(93		)	86			(93		)	(23		)	(37		)	(103		)	65			(98		)
Total Liabilities	$	(82	)	$	(280	)	$	(129	)	$	365		$	(126	)	$	(226	)	$	(248	)	$	(182	)	$	489		$	(167	)
Net Assets (Liabilities) at end of period	$	1,091		$	491		$	(23	)	$	10		$	1,569		$	1,075		$	408		$	(88	)	$	21		$	1,416

_______________________________________

(a) 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.

(b) At March 31, 2017 and December 31, 2016, available-for-sale securities of $17 million, included $7 million and $10 million of cash equivalents included in Restricted cash and Other investments on DTE Energy's Consolidated Statements of Financial Position, respectively.

(c) At March 31, 2017, the Nuclear Decommissioning Master Trust had outstanding commitments to invest in private equity investments of approximately $15 million. These commitments will be funded by existing nuclear decommissioning trust funds.

(d) Excludes cash surrender value of life insurance investments.

27

DTE Energy Company — DTE Electric Company

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

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

	March 31, 2017								December 31, 2016
	Level 1		Level 2		Level 3		Net Balance		Level 1		Level 2		Level 3		Net Balance
	(In millions)
Assets:
Cash equivalents(a)	$	8	$	3	$	—	$	11	$	8	$	3	$	—	$	11
Nuclear decommissioning trusts(b)
Equity securities	890		—		—		890		887		—		—		887
Fixed income securities	11		460		—		471		11		414		—		425
Cash equivalents	3		—		—		3		8		—		—		8
Other investments
Equity securities	9		—		—		9		9		—		—		9
Derivative assets — FTRs	—		—		1		1		—		—		2		2
Total	$	921	$	463	$	1	$	1,385	$	923	$	417	$	2	$	1,342
Assets:
Current	$	8	$	3	$	1	$	12	$	8	$	3	$	2	$	13
Noncurrent	913		460		—		1,373		915		414		—		1,329
Total Assets	$	921	$	463	$	1	$	1,385	$	923	$	417	$	2	$	1,342

_______________________________________

(a) At March 31, 2017 and December 31, 2016, available-for-sale securities of $11 million consisted of cash equivalents included in Other investments on DTE Electric's Consolidated Statements of Financial Position, respectively.

(b) At March 31, 2017, the Nuclear Decommissioning Master Trust had outstanding commitments to invest in private equity investments of approximately $15 million. These commitments will be funded by existing nuclear decommissioning trust funds.

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 institutional mutual funds and commingled funds. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. Non-exchange-traded fixed income securities are valued based upon quotations available from brokers or pricing services. The institutional mutual funds hold exchange-traded equity or debt securities (exchange and non-exchange traded) and are valued based on publicly available NAVs. 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 to be 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. Additionally, the Registrants selectively corroborate the fair value of securities by comparison of market-based price sources. Investment policies and procedures are determined by DTE Energy's Trust Investments Department which reports to DTE Energy's Vice President and Treasurer.

28

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 March 31, 2017												Three Months Ended March 31, 2016
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of January 1	$	(96	)	$	9		$	(1	)	$	(88	)	$	(5	)	$	6		$	(5	)	$	(4	)
Transfers into Level 3 from Level 2	—			—			—			—			—			—			—			—
Transfers from Level 3 into Level 2	—			—			—			—			(1		)	—			—			(1		)
Total gains (losses)
Included in earnings	52			(9		)	1			44			(20		)	(58		)	(1		)	(79		)
Recorded in Regulatory liabilities	—			—			2			2			—			—			(2		)	(2		)
Purchases, issuances, and settlements
Settlements	29			(6		)	(4		)	19			(8		)	36			1			29
Net Liabilities as of March 31	$	(15	)	$	(6	)	$	(2	)	$	(23	)	$	(34	)	$	(16	)	$	(7	)	$	(57	)
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 March 31, 2017 and 2016 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	$	35		$	(3	)	$	—		$	32		$	(72	)	$	(3	)	$	(1	)	$	(76	)

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 March 31,
	2017			2016
	(In millions)
Net Assets as of January 1	$	2		$	3
Change in fair value recorded in Regulatory liabilities	2			(2		)
Purchases, issuances, and settlements
Settlements	(3		)	—
Net Assets as of March 31	$	1		$	1
The amount of total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets held at March 31, 2017 and 2016 and reflected in DTE Electric's Consolidated Statements of Financial Position	$	—		$	—

29

DTE Energy Company — DTE Electric Company

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

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 months endedMarch 31, 2017 and 2016, 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:

	March 31, 2017
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	71	$	(86	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(0.87	)	—	$	6.25	/MMBtu	$	(0.14	)/MMBtu
Electricity	$	34	$	(40	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(6	)	—	$	8	/MWh	$	1	/MWh

	December 31, 2016
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	53	$	(149	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.00	)	—	$	7.90	/MMBtu	$	(0.05	)/MMBtu
Electricity	$	39	$	(30	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(6	)	—	$	12	/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 fair value of financial instruments included in the table below is determined by using quoted market prices when available. When quoted prices are not available, pricing services may be used to determine the fair value with reference to observable interest rate indexes. The Registrants have obtained an understanding of how the fair values are derived. The Registrants also selectively corroborate the fair value of their transactions by comparison of market-based price sources. Discounted cash flow analyses based upon estimated current borrowing rates are also used to determine fair value when quoted market prices are not available. The fair values of notes receivable, excluding capital leases, and notes payable are generally estimated using discounted cash flow techniques that incorporate market interest rates as well as assumptions about the remaining life of the loans and credit risk. Depending on the information available, other valuation techniques may be used that rely on internal assumptions and models. Valuation policies and procedures for the Registrants are determined by DTE Energy's Treasury Department which reports to DTE Energy's Vice President and Treasurer and DTE Energy's Controller's Department which reports to DTE Energy's Vice President and Controller.

30

DTE Energy Company — DTE Electric Company

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

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

	March 31, 2017								December 31, 2016
	Carrying		Fair Value						Carrying		Fair Value
	Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3
	(In millions)
Notes receivable, excluding capital leases	$	31	$	—	$	—	$	31	$	36	$	—	$	—	$	36
Dividends payable	$	148	$	148	$	—	$	—	$	148	$	148	$	—	$	—
Short-term borrowings	$	59	$	—	$	59	$	—	$	499	$	—	$	499	$	—
Notes payable — Other(a)	$	18	$	—	$	—	$	18	$	17	$	—	$	—	$	17
Long-term debt(b)	$	11,762	$	1,505	$	9,874	$	1,044	$	11,270	$	1,465	$	9,384	$	1,056

_______________________________________

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

(b) Includes debt due within one year, unamortized debt discounts, premiums, and issuance costs. Excludes Capital lease obligations.

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

	March 31, 2017								December 31, 2016
	Carrying		Fair Value						Carrying		Fair Value
	Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3
	(In millions)
Notes receivable, excluding capital leases	$	—	$	—	$	—	$	—	$	5	$	—	$	—	$	5
Short-term borrowings — affiliates	$	205	$	—	$	—	$	205	$	117	$	—	$	—	$	117
Short-term borrowings — other	$	59	$	—	$	59	$	—	$	62	$	—	$	62	$	—
Notes payable — Other(a)	$	6	$	—	$	—	$	6	$	6	$	—	$	—	$	6
Long-term debt(b)	$	5,879	$	—	$	6,016	$	262	$	5,878	$	—	$	6,026	$	264

_______________________________________

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

(b) Includes debt due within one year, unamortized debt discounts, and issuance costs. Excludes Capital 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:

	March 31, 2017		December 31, 2016
	(In millions)
Fermi 2	$	1,350	$	1,291
Fermi 1	3		3
Low-level radioactive waste	11		26
Total	$	1,364	$	1,320

31

DTE Energy Company — DTE Electric Company

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

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 March 31,
	2017			2016
	(In millions)
Realized gains	$	23		$	9
Realized losses	$	(8	)	$	(15	)
Proceeds from sale of securities	$	394		$	260

Realized gains and losses from the sale of securities for Fermi 2 are recorded to the Regulatory asset and Nuclear decommissioning liability. Realized gains and losses from the sale of securities for 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:

	March 31, 2017							December 31, 2016
	Fair Value		Unrealized Gains		Unrealized Losses			Fair Value		Unrealized Gains		Unrealized Losses
	(In millions)
Equity securities	$	890	$	250	$	(38	)	$	887	$	222	$	(46	)
Fixed income securities	471		12		(4		)	425		11		(5		)
Cash equivalents	3		—		—			8		—		—
	$	1,364	$	262	$	(42	)	$	1,320	$	233	$	(51	)

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

	March 31, 2017
	(In millions)
Due within one year	$	19
Due after one through five years	109
Due after five through ten years	91
Due after ten years	252
	$	471

Securities held in the Nuclear decommissioning trust funds are classified as available-for-sale. As DTE Electric does not have the ability to hold impaired investments for a period of time sufficient to allow for the anticipated recovery of market value, all unrealized losses are considered to be other-than-temporary impairments.

Unrealized losses incurred by the Fermi 2 trust are recognized as a Regulatory asset and Nuclear decommissioning liability. Unrealized losses on the low-level radioactive waste funds are recognized as a Nuclear decommissioning liability.

Other Securities

At March 31, 2017 and December 31, 2016, the Registrants' securities were comprised primarily of money market and equity securities. There were no unrealized losses on available-for-sale securities which were reclassified out of Other comprehensive income (loss) and realized into Net Income for DTE Energy or DTE Electric during the three months endedMarch 31, 2017 and 2016. Gains related to trading securities held at March 31, 2017 and 2016 were $8 million and $5 million, respectively, for the Registrants. The trading gains or losses related to the Rabbi Trust assets, included in Other investments at DTE Energy, are allocated from DTE Energy to DTE Electric.

32

DTE Energy Company — DTE Electric Company

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

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 energy 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 2020. 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, landfill 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.

33

DTE Energy Company — DTE Electric Company

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

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 March 31, 2017 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:

	March 31, 2017					December 31, 2016
	Derivative Assets		Derivative Liabilities			Derivative Assets		Derivative Liabilities
	(In millions)
Derivatives not designated as hedging instruments
Commodity Contracts
Natural Gas	$	304	$	(289	)	$	348	$	(461	)
Electricity	186		(197		)	193		(189		)
Other	1		(3		)	2		(3		)
Foreign currency exchange contracts	5		(2		)	6		(3		)
Total derivatives not designated as hedging instruments	$	496	$	(491	)	$	549	$	(656	)
Current	$	349	$	(312	)	$	447	$	(493	)
Noncurrent	147		(179		)	102		(163		)
Total derivatives	$	496	$	(491	)	$	549	$	(656	)

34

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 Electric:

	March 31, 2017		December 31, 2016
	(In millions)
FTRs — Other current assets	$	1	$	2
Total derivatives not designated as hedging instrument	$	1	$	2

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 approximately $3 million and $2 million outstanding at March 31, 2017 and December 31, 2016, 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 $4 million and $2 million at March 31, 2017 and December 31, 2016, 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. Certain contracts that have netting arrangements have not been offset in DTE Energy's Consolidated Statements of Financial Position. The impact of netting these derivative instruments and cash collateral related to such contracts is not material. Only the gross amounts for these derivative instruments are included in the table below.

For DTE Energy, the total cash collateral posted, net of cash collateral received, was $48 million and $34 million as of March 31, 2017 and December 31, 2016, respectively. DTE Energy had $3 million of cash collateral related to unrealized positions to net against Derivative assets while Derivative liabilities are shown net of cash collateral of $13 million as of March 31, 2017. DTE Energy had $7 million of cash collateral related to unrealized positions to net against Derivative assets while Derivative liabilities are shown net of cash collateral of $28 million as of December 31, 2016. DTE Energy recorded cash collateral paid of $41 million and cash collateral received of $3 million not related to unrealized derivative positions as of March 31, 2017. DTE Energy recorded cash collateral paid of $18 million and cash collateral received of $5 million not related to unrealized derivative positions as of December 31, 2016. These amounts are included in Accounts receivable and Accounts payable and are recorded net by counterparty.

35

DTE Energy Company — DTE Electric Company

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

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

	March 31, 2017									December 31, 2016
	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	$	304		$	(206	)	$	98		$	348		$	(306	)	$	42
Electricity	186			(146		)	40			193			(157		)	36
Other	1			—			1			2			—			2
Foreign currency exchange contracts	5			(3		)	2			6			(5		)	1
Total derivative assets	$	496		$	(355	)	$	141		$	549		$	(468	)	$	81
Derivative liabilities
Commodity Contracts
Natural Gas	$	(289	)	$	202		$	(87	)	$	(461	)	$	321		$	(140	)
Electricity	(197		)	158			(39		)	(189		)	163			(26		)
Other	(3		)	3			—			(3		)	2			(1		)
Foreign currency exchange contracts	(2		)	2			—			(3		)	3			—
Total derivative liabilities	$	(491	)	$	365		$	(126	)	$	(656	)	$	489		$	(167	)

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:

	March 31, 2017												December 31, 2016
	Derivative Assets						Derivative Liabilities						Derivative Assets						Derivative Liabilities
	Current			Noncurrent			Current			Noncurrent			Current			Noncurrent			Current			Noncurrent
	(In millions)
Total fair value of derivatives	$	349		$	147		$	(312	)	$	(179	)	$	447		$	102		$	(493	)	$	(163	)
Counterparty netting	(278		)	(74		)	278			74			(396		)	(65		)	396			65
Collateral adjustment	(3		)	—			1			12			(4		)	(3		)	28			—
Total derivatives as reported	$	68		$	73		$	(33	)	$	(93	)	$	47		$	34		$	(69	)	$	(98	)

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

Derivatives not Designated as Hedging Instruments	Location of Gain (Loss) Recognized in Income on Derivatives	Gain (Loss) Recognized in Income on Derivatives for the Three Months Ended March 31,
		2017			2016
		(In millions)
Commodity Contracts
Natural Gas	Operating Revenues — Non-utility operations	$	57		$	(56	)
Natural Gas	Fuel, purchased power, and gas — non-utility	61			41
Electricity	Operating Revenues — Non-utility operations	(7		)	(24		)
Other	Operating Revenues — Non-utility operations	—			(2		)
Foreign currency exchange contracts	Operating Revenues — Non-utility operations	—			(5		)
Total		$	111		$	(46	)

36

DTE Energy Company — DTE Electric Company

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

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 March 31, 2017:

Commodity	Number of Units
Natural Gas (MMBtu)	1,781,816,780
Electricity (MWh)	35,032,431
Oil (Gallons)	12,936,000
Foreign Currency Exchange (Canadian dollars)	73,633,072

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 March 31, 2017, 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 approximately $437 million.

As of March 31, 2017, DTE Energy had approximately $397 million of derivatives in net liability positions, for which hard triggers exist. There is no collateral that has been posted against such liabilities, including cash and letters of credit. Associated derivative net asset positions for which contractual offset exists were approximately $342 million. The net remaining amount of approximately $55 million is derived from the $437 million noted above.

NOTE 9 — LONG-TERM DEBT

Debt Issuances

In 2017, the following debt was issued:

Company	Month	Type	Interest Rate	Maturity	Amount
					(In millions)
DTE Energy	March	Senior Notes(a)	3.80%	2027	$	500
					$	500

_______________________________________

(a) Proceeds were used for repayment of short-term borrowings and general corporate purposes.

Debt Redemptions

In 2017, the following debt was redeemed:

Company	Month	Type	Interest Rate	Maturity	Amount
					(In millions)
DTE Energy	Various	Other Long-Term Debt	Various	2017	$	5
					$	5

37

DTE Energy Company — DTE Electric Company

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

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 March 31, 2017, the total funded debt to total capitalization ratios for DTE Energy, DTE Electric, and DTE Gas were 0.53 to 1, 0.50 to 1, and 0.45 to 1, respectively, and were in compliance with this financial covenant.

The availability under the facilities in place at March 31, 2017 is shown in the following table:

	DTE Energy		DTE Electric		DTE Gas		Total
	(In millions)
Unsecured letter of credit facility, expiring in February 2019(a)	$	150	$	—	$	—	$	150
Unsecured letter of credit facility, expiring in September 2017	70		—		—		70
Unsecured revolving credit facility, expiring April 2021	1,200		400		300		1,900
	1,420		400		300		2,120
Amounts outstanding at March 31, 2017
Commercial paper issuances	—		59		—		59
Letters of credit	139		—		—		139
	139		59		—		198
Net availability at March 31, 2017	$	1,281	$	341	$	300	$	1,922

_______________________________________

(a) In February 2017, DTE Energy amended its $100 million letter of credit facility. The facility's maturity date was amended from February 2017 to February 2019. As part of this amendment, DTE Energy increased its $100 million letter of credit facility to $150 million.

In April 2017, DTE Energy, DTE Electric, and DTE Gas exercised the extension features in their revolving credit agreements to add one year to the existing maturities. Each of these revolvers' expirations were extended from April 2021 to April 2022.

DTE Energy has other outstanding letters of credit which are not included in the above described facilities totaling approximately $17 million which are used for various corporate purposes.

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 March 31, 2017, a $35 million letter of credit was in place, raising the capacity under this facility to $135 million. The $35 million letter of credit is included in the table above. The amount outstanding under this agreement was $16 million and $50 million at March 31, 2017 and December 31, 2016, respectively, and was fully offset by the posted collateral.

38

DTE Energy Company — DTE Electric Company

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

NOTE 11 — COMMITMENTS AND CONTINGENCIES

Environmental

DTE Electric

Air — DTE Electric is subject to the EPA ozone and fine particulate transport and acid rain regulations that limit power plant emissions of SO₂ and NOx. The EPA and the State of Michigan have also issued emission reduction regulations relating to ozone, fine particulate, regional haze, mercury, and other air pollution. These rules have led to controls on fossil-fueled power plants to reduce NOx, SO₂, mercury, and other emissions. Additional rulemakings may occur over the next few years which could require additional controls for SO₂, NOx, and other hazardous air pollutants.

The Cross State Air Pollution Rule (CSAPR), required further reductions of SO₂ and NOx emissions beginning in January 2015. On September 7, 2016, the EPA finalized an update to the CSAPR ozone season program by issuing the CSAPR Update Rule. Beginning in May 2017, this rule is expected to reduce summertime (May - September) NOx emissions from power plants in 22 states in the eastern half of the U.S., including DTE Electric facilities. The CSAPR Update Rule is intended to reduce air quality impacts of the interstate transport of air pollution on downwind areas' ability to meet the 2008 ozone National Ambient Air Quality Standards implementing power sector emission budgets and NOx allowance trading programs. DTE Electric expects to meet its obligations under CSAPR. DTE Electric does not expect this rule to have a material effect on its compliance program.

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. The EPA will designate areas as either attainment or non-attainment with ozone standards by October 2017. DTE Electric cannot predict the financial impact of the revised ozone standards at this time.

In July 2009, DTE Energy 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 caused to be 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 caused to be 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 granted again 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 until the appeal is resolved by the Court of Appeals for the Sixth Circuit. Oral arguments for the appeal occurred in December 2015. On January 10, 2017, a divided panel of the Court reversed the decision of the U.S. District Court. On February 24, 2017, DTE Energy and DTE Electric filed a petition with the Sixth Circuit Court for a rehearing and a rehearing en banc. The Court requested responses to the petition from the EPA and the Sierra Club, which were filed on April 3, 2017.

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 cannot predict the financial impact or outcome of this matter, or the timing of its resolution.

39

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, the EPA finalized performance standards for emissions of carbon dioxide from new and existing 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. In February 2016, the U.S. Supreme Court granted petitioners' requests for a stay of the carbon rules for existing EGUs (also known as the EPA Clean Power Plan) pending final review by the courts. The Clean Power Plan has no legal effect while the stay is in place. On March 28, 2017, a presidential executive order was issued on "Promoting Energy Independence and Economic Growth." The order instructs the EPA to review, and if appropriate, suspend, revise or rescind the Clean Power Plan rule. Additionally, federal agencies have been directed to conduct a review of all existing regulations that potentially burden the development and use of domestically produced energy resources. Following the issuance of this order, the federal government requested the U.S. Court of Appeals for the D.C. Circuit to hold all legal challenges in abeyance until the review of these regulations is completed. It is not possible to determine the potential impact of this order on existing sources at this time.

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 2016. DTE Electric does not anticipate additional capital expenditures through 2023.

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 2015. The final rule requires studies to be completed by April 2018 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 each 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 March 31, 2017 and December 31, 2016, DTE Electric had $8 million 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 CCR, commonly known as coal ash, became effective in October 2015. 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. At certain facilities, the rule requires the installation of monitoring wells, compliance with groundwater standards, and the closure of basins at the end of the useful life of the associated power plant or as a basin becomes inactive. At other facilities, the rule requires ash laden waters be moved from earthen basins to steel and concrete tanks.

40

DTE Energy Company — DTE Electric Company

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

In November 2015, the EPA finalized the ELG Rule for the steam electric power generating industry which may require additional controls to be installed between 2018 and 2023. Compliance schedules for individual facilities and individual waste streams are determined through issuance of new wastewater permits by the State of Michigan. The State of Michigan has issued a National Pollutant Discharge Elimination System permit for the Belle River Power Plant establishing a compliance deadline of December 31, 2021. No new permits have been issued for other facilities, consequently no compliance timelines have been established. Under the current rule, certain ELG requirements would be required to be performed in conjunction with the CCR. Over the next six years, to comply with the ELG requirements of the November 2015 rules and for CCR requirements, costs associated with the building of new facilities or installation of controls are estimated to be approximately $309 million.

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 wastewater, among others. The administrative stay will become effective when published in the Federal Register. The ELG compliance requirements, deadlines, and compliance costs will not be known until the EPA completes its reconsideration of the ELG Rule.

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 six of the MGP sites is complete, and the sites are closed. DTE Gas has also completed partial closure of four additional sites. Cleanup activities associated with the remaining sites will continue over the next several years. The MPSC has established a cost deferral and rate recovery mechanism for investigation and remediation costs incurred at former MGP sites. In addition to the MGP sites, DTE Gas is also in the process of cleaning up other contaminated sites, including gate stations, gas pipeline releases, and underground storage tank locations. As of March 31, 2017 and December 31, 2016, DTE Gas had $41 million and $43 million accrued for remediation, respectively.  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.

The District Attorney's office of Yolo County, California has been investigating the ash management and disposition practices of Woodland Biomass Power, Ltd., and DTE Woodland, LLC, wholly-owned subsidiaries of DTE Energy (the Woodland Companies), a renewable wood-fired power generation facility. The District Attorney alleged that some of the ash generated at the Woodland Companies' generating facility should have been characterized and handled as hazardous waste under California regulation. DTE Energy is currently working through a final settlement, which includes reimbursement of the District Attorney's investigation costs. As of March 31, 2017, DTE Energy had approximately $4 million accrued for this matter. DTE Energy does not expect changes in estimated remediation and settlement costs to be materially different than the amounts accrued at March 31, 2017.

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 three 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.

41

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 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 plans (SIPs) for Phase 2 areas describing the control strategy and timeline for demonstrating compliance with the new SO₂ standard are due to the EPA by mid-2018. 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 as it currently is under development.

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 March 31, 2017 is approximately $620 million. Payment under these guarantees is considered remote.

REF Guarantees

DTE Energy has provided certain guarantees and indemnities in conjunction with the sales of interests in or lease of its REF facilities. The guarantees cover potential commercial, environmental, and tax-related obligations that will survive until 90 days after expiration of all applicable statutes of limitations. DTE Energy estimates that its maximum potential liability under these guarantees at March 31, 2017 is approximately $308 million. Payment under these guarantees is considered remote.

NEXUS Guarantees

NEXUS entered into certain 15-year capacity lease 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 $53 million and $8 million, respectively; each representing 50% of all payment obligations due and payable by NEXUS. Should NEXUS fail to perform under the terms of those agreements, DTE Energy is required to perform on its behalf. 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 lease agreements. Subsequent to the NEXUS in-service date, the amount of each guarantee decreases annually as payments are made by NEXUS to each of the aforementioned counterparties. 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 $55 million at March 31, 2017. Payment under these guarantees is 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 March 31, 2017, DTE Energy had approximately $56 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.

42

DTE Energy Company — DTE Electric Company

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

Labor Contracts

There are several bargaining units for DTE Energy's approximately 4,800 represented employees, including DTE Electric's approximately 2,600 represented employees. The majority of the represented employees are under contracts that expire in 2017 and 2020.

Purchase Commitments

DTE Energy and DTE Electric expect that 2017 annual capital expenditures and contributions to equity method investees will be approximately $3.0 billion and $1.5 billion, respectively. The Registrants have made certain commitments in connection with the estimated 2017 annual capital expenditures and contributions to equity method investees.

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 12 — 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
	2017			2016			2017			2016
Three Months Ended March 31,	(In millions)
Service cost	$	24		$	23		$	7		$	6
Interest cost	54			54			18			20
Expected return on plan assets	(78		)	(77		)	(33		)	(32		)
Amortization of:
Net actuarial loss	43			40			3			8
Prior service credit	—			—			(3		)	(30		)
Net periodic benefit cost (credit)	$	43		$	40		$	(8	)	$	(28	)

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

	Pension Benefits						Other Postretirement Benefits
	2017			2016			2017			2016
Three Months Ended March 31,	(In millions)
Service cost	$	18		$	18		$	5		$	5
Interest cost	41			41			14			15
Expected return on plan assets	(55		)	(55		)	(23		)	(23		)
Amortization of:
Net actuarial loss	31			29			2			6
Prior service credit	—			—			(2		)	(22		)
Net periodic benefit cost (credit)	$	35		$	33		$	(4	)	$	(19	)

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DTE Energy Company — DTE Electric Company

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

Pension and Other Postretirement Contributions

During the first three months of 2017, DTE Energy made cash contributions of $126 million, including contributions from DTE Electric of $125 million, to its pension plans. At the discretion of management and depending upon financial market conditions, DTE Energy may make additional contributions up to $180 million, including additional contributions from DTE Electric of $145 million, to its pension plans in 2017.

DTE Energy does not anticipate making any contributions to the other postretirement benefit plans in 2017.

NOTE 13 — 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 consists of natural gas pipeline, gathering, and storage businesses.

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 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 March 31,
	2017		2016
	(In millions)
Electric	$	12	$	9
Gas	3		—
Gas Storage and Pipelines	7		2
Power and Industrial Projects	168		148
Energy Trading	11		10
Corporate and Other	1		—
	$	202	$	169

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DTE Energy Company — DTE Electric Company

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

Financial data of DTE Energy's business segments follows:

	Three Months Ended March 31,
	2017			2016
	(In millions)
Operating Revenues — Utility operations
Electric	$	1,175		$	1,153
Gas	557			520
Operating Revenues — Non-utility operations
Gas Storage and Pipelines	105			67
Power and Industrial Projects	548			446
Energy Trading	1,052			549
Corporate and Other	1			—
Reconciliation and Eliminations	(202		)	(169		)
Total	$	3,236		$	2,566

Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	106	$	127
Gas	107		87
Gas Storage and Pipelines	45		30
Power and Industrial Projects	30		17
Energy Trading	96		(7		)
Corporate and Other	16		(7		)
Net Income Attributable to DTE Energy Company	$	400	$	247

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 March 31,
	2017		2016
	(In millions, except per share amounts)
Net Income Attributable to DTE Energy Company	$	400	$	247
Diluted Earnings per Common Share	$	2.23	$	1.37

The increase in Net Income for the three months ended March 31, 2017 is primarily due to higher earnings in the Energy Trading and Gas segments, partially offset by lower earnings in the Electric segment.

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.

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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.

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.

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 2017-2021 period are estimated at $8.4 billion comprised of $3.2 billion for capital replacements and other projects, $3.2 billion for distribution infrastructure, and $2.0 billion for new generation. DTE Electric has retired three coal-fired generation units at the Trenton Channel and River Rouge facilities and has announced plans to retire an additional eight coal-fired generating units through 2023 at the Trenton Channel, River Rouge, and St. Clair facilities. The retired facilities will be replaced with natural gas-fired generation and renewables. DTE Electric plans to build natural gas turbine plants to provide approximately 1,000 megawatts of energy between 2021 and 2023. In September 2016, DTE Electric received an order from the MPSC in its amended Renewable Energy Plan approving two 150 megawatt wind projects expected to be constructed and in service between 2018 and 2020, and 25 megawatts of company-owned solar projects which will be constructed and in service between 2019 and 2020. DTE Electric is also currently constructing 50 megawatts of solar generation expected to be in service mid-2017. DTE Electric plans to seek regulatory approval for capital expenditures consistent with prior ratemaking treatment.

DTE Gas' capital investments over the 2017-2021 period are estimated at $1.8 billion comprised of $1.0 billion for base infrastructure, $700 million for gas main renewal, meter move out, and pipeline integrity programs, and $100 million for expenditures related to the NEXUS Pipeline. DTE Gas plans to seek regulatory approval in general rate case filings for base infrastructure capital expenditures consistent with prior 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 2017-2021 period are estimated at $2.2 billion to $2.8 billion for gathering and pipeline investments and expansions, including the NEXUS Pipeline. Power and Industrial Projects' capital investments over the 2017-2021 period are estimated at $600 million to $1.0 billion for investments in cogeneration and on-site energy 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.

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DTE Electric is subject to the EPA ozone and fine particulate transport and acid rain regulations that limit power plant emissions of SO₂ and NOx. The EPA and the State of Michigan have also issued emission reduction regulations relating to ozone, fine particulate, regional haze, mercury, and other air pollution. These rules have led to controls on fossil-fueled power plants to reduce NOx, SO₂, mercury and other emissions. Additional rulemakings are expected over the next few years which could require additional controls for SO₂, NOx, and other hazardous air pollutants. To comply with these requirements, DTE Electric spent approximately $2.4 billion through 2016. DTE Electric does not anticipate additional capital expenditures through 2023.

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, the EPA finalized performance standards for emissions of carbon dioxide from new and existing 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. In February 2016, the U.S. Supreme Court granted petitioners' requests for a stay of the carbon rules for existing EGUs (also known as the EPA Clean Power Plan) pending final review by the courts. The Clean Power Plan has no legal effect while the stay is in place. On March 28, 2017, a presidential executive order was issued on "Promoting Energy Independence and Economic Growth." The order instructs the EPA to review, and if appropriate, suspend, revise or rescind the Clean Power Plan rule. Additionally, federal agencies have been directed to conduct a review of all existing regulations that potentially burden the development and use of domestically produced energy resources. Following the issuance of this order, the federal government requested the U.S. Court of Appeals for the D.C. Circuit to hold all legal challenges in abeyance until the review of these regulations is completed. It is not possible to determine the potential impact of the EPA Clean Power Plan on existing sources at this time.

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.

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-fired generation, and/or nuclear sources, energy efficiency 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 11 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.

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;

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• 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

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 March 31,
	2017		2016
	(In millions)
Net Income (Loss) Attributable to DTE Energy by Segment
Electric	$	106	$	127
Gas	107		87
Gas Storage and Pipelines	45		30
Power and Industrial Projects	30		17
Energy Trading	96		(7		)
Corporate and Other	16		(7		)
Net Income Attributable to DTE Energy Company	$	400	$	247

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. Results for Electric segment with a reconciliation to DTE Electric are discussed below:

	Three Months Ended March 31,
	2017		2016
	(In millions)
Operating Revenues — Utility operations	$	1,175	$	1,153
Fuel and purchased power — utility	314		335
Gross Margin	861		818
Operation and maintenance	383		324
Depreciation and amortization	181		176
Taxes other than income	80		73
Operating Income	217		245
Other (Income) and Deductions	54		48
Income Tax Expense	57		70
DTE Electric Net Income Attributable to DTE Energy Company	$	106	$	127

See DTE Electric's Consolidated Statements of Operations for a complete view of its results.

Gross Marginincreased$43 million in the three months endedMarch 31, 2017. Revenues associated with certain mechanisms and surcharges are offset by related expenses elsewhere in the Registrants' Consolidated Statements of Operations.

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The following table details changes in various gross margin components relative to the comparable prior period:

	Three Months
	(In millions)
Implementation of new rates	$	46
Base sales	2
Weather	(13		)
Regulatory mechanisms and other	8
Increase in gross margin	$	43

	Three Months Ended March 31,
	2017	2016
	(In thousands of MWh)
DTE Electric Sales
Residential	3,518	3,618
Commercial	4,083	4,109
Industrial	2,375	2,421
Other	79	78
	10,055	10,226
Interconnection sales(a)	672	693
Total DTE Electric Sales	10,727	10,919
DTE Electric Deliveries
Retail and wholesale	10,055	10,226
Electric retail access, including self-generators(b)	1,194	1,159
Total DTE Electric Sales and Deliveries	11,249	11,385

______________________________

(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 increased$59 million in the three months endedMarch 31, 2017. The increase was primarily due to increased power plant generation expenses of $28 million related to outages, increased storm restoration expenses of $21 million, increased distribution operations expenses of $6 million, and increased benefits expense of $4 million. The increased power plant generation expenses include $9 million of costs related to the 2016 fire at a generation facility, which DTE Electric expects to be partially reimbursed by insurance proceeds.

Depreciation and amortization expense increased$5 million in the three months endedMarch 31, 2017. The increase was primarily due to $4 million of increased expenses due to an increased depreciable base and an increase of $4 million associated with the TRM, partially offset by a decrease of $3 million in amortization of regulatory assets.

Other (Income) and Deductionsincreased$6 million in the three months endedMarch 31, 2017. The increase was primarily due to lower interest income of $8 million related to a sales and use tax settlement received in 2016, partially offset by $3 million of higher investment earnings.

Outlook— DTE Electric will continue to move forward in its efforts to achieve operational excellence, sustained 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 expects to continue its efforts to improve productivity and decrease costs while improving customer satisfaction with consideration of customer rate affordability. 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, impact of 2016 Michigan energy legislation, uncertainty of legislative or regulatory actions regarding climate change, and effects of energy efficiency programs.

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DTE Electric filed a rate case with the MPSC on April 19, 2017 requesting an increase in base rates of $231 million based on a projected twelve-month period ending October 31, 2018. The requested increase in base rates is due primarily to an increase in net plant resulting from infrastructure investments, environmental compliance, and reliability improvement projects. The rate filing also includes projected changes in sales, operation and maintenance expenses, and working capital. The rate filing also requests an increase in return on equity from 10.1% to 10.5% on capital structure. DTE Electric anticipates self-implementing a rate increase in November 2017 with an MPSC order expected by April 2018.

GAS

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

	Three Months Ended March 31,
	2017		2016
	(In millions)
Operating Revenues — Utility operations	$	557	$	520
Cost of gas — utility	221		233
Gross Margin	336		287
Operation and maintenance	107		96
Depreciation and amortization	30		26
Taxes other than income	20		19
Operating Income	179		146
Other (Income) and Deductions	13		11
Income Tax Expense	59		48
Net Income Attributable to DTE Energy Company	$	107	$	87

Gross Marginincreased$49 million in the three months endedMarch 31, 2017. Revenues associated with certain surcharges are offset by related expenses elsewhere in DTE Energy's Consolidated Statements of Operations.

The following table details changes in various gross margin components relative to the comparable prior period:

	Three Months
	(In millions)
Implementation of new rates	$	54
Revenue decoupling mechanism	5
Weather	(12		)
Other	2
Increase in gross margin	$	49

	Three Months Ended March 31,
	2017	2016
	(In Bcf)
Gas Markets
Gas sales	53	55
End-user transportation	52	56
	105	111
Intermediate transportation	82	67
Total Gas sales	187	178

Operation and maintenance expense increased$11 million in the three months endedMarch 31, 2017. The increase was primarily due to increased employee benefits expenses of $8 million, increased corporate expenses of $2 million, and increased energy optimization expenses of $2 million, partially offset by decreased uncollectible expense of $1 million.

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Outlook — DTE Gas will continue to move forward in its efforts to achieve operational excellence, sustained 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.

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 March 31,
	2017			2016
	(In millions)
Operating Revenues — Non-utility operations	$	105		$	67
Cost of gas — Non-utility	6			—
Operation and maintenance	19			16
Depreciation and amortization	19			8
Taxes other than income	3			1
Operating Income	58			42
Other (Income) and Deductions	(14		)	(8		)
Income Tax Expense	21			19
Net Income	51			31
Less: Net Income Attributable to Noncontrolling Interests	6			1
Net Income Attributable to DTE Energy Company	$	45		$	30

Operating Revenues — Non-utility operationsincreased$38 million in the three months endedMarch 31, 2017. The increase was primarily due to the acquisition of AGS and SGG and increased volumes from Susquehanna gathering.

Depreciation and amortization expenseincreased$11 million in the three months endedMarch 31, 2017. The increase is primarily due to the acquisition of AGS and SGG.

Other (Income) and Deductionsincreased$6 million in the three months endedMarch 31, 2017. This increase is primarily due to higher pipeline earnings from AFUDC recorded on the NEXUS Pipeline.

Net Income Attributable to Noncontrolling Interestsincreased$5 million in the three months endedMarch 31, 2017. The increase is primarily due to the acquisition of SGG.

See Note 4 to the Consolidated Financial Statements, "Acquisition," for discussion of the acquisition of AGS and SGG in October 2016.

Outlook — The Bluestone Pipeline expansion is expected to be in service in the second quarter of 2017. Additionally, the Susquehanna gathering system will be expanded with additional compression facilities and gathering lines as needed to accommodate shipper demand. DTE Energy believes its long-term agreement with Southwestern Energy Production Company and the quality of the natural gas reserves in the Marcellus region soundly positions Bluestone Pipeline and Susquehanna gathering system for future growth.

Progress continues on development activities on the NEXUS Pipeline, a transportation path to transport 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 with an investment balance of $435 million at March 31, 2017. A FERC application was filed in the fourth quarter of 2015. With the departure of one of the three remaining FERC commissioners on February 3, 2017, a necessary quorum of three FERC commissioners no longer exists, thereby delaying pipeline approvals until at least one new commissioner is appointed. Construction will commence as soon as the FERC order is received. Premised on a timely appointment of at least one FERC Commissioner, DTE Energy is targeting a year-end 2017 in-service date for the NEXUS Pipeline.

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The October 2016 acquisition of AGS and SGG provides 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 a new set of 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 from renewable energy projects. Power and Industrial Projects results are discussed below:

	Three Months Ended March 31,
	2017			2016
	(In millions)
Operating Revenues — Non-utility operations	$	548		$	446
Fuel, purchased power, and gas — non-utility	486			383
Gross Margin	62			63
Operation and maintenance	82			75
Depreciation and amortization	18			18
Taxes other than income	4			5
Operating Loss	(42		)	(35		)
Other (Income) and Deductions	(16		)	(14		)
Income Taxes
Benefit	(6		)	(5		)
Production Tax Credits	(38		)	(25		)
	(44		)	(30		)
Net Income	18			9
Less: Net Loss Attributable to Noncontrolling Interests	(12		)	(8		)
Net Income Attributable to DTE Energy Company	$	30		$	17

Operating Revenues — Non-utility operationsincreased$102 million in the three months endedMarch 31, 2017. The increase was primarily due to $96 million associated with higher production in the REF business, and a $9 million increase primarily due to higher sales as a result of improved conditions in the steel business.

Gross Margindecreased$1 million in the three months endedMarch 31, 2017. The decrease was primarily due to $4 million of lower sales associated with expired contracts in the on-site business, and a $3 million decrease associated with production in the REF business, offset by a $9 million increase primarily due to higher sales as a result of improved business conditions in the steel business.

Operation and maintenance expense increased$7 million in the three months endedMarch 31, 2017. The increase was primarily due to $4 million of higher maintenance in the renewables projects, and $2 million of higher spending primarily due to new projects and higher production in the REF business.

Income Tax — Production Tax Creditsincreased by $13 million in the three months endedMarch 31, 2017. The increase was primarily due to new projects and higher production in the REF business.

Outlook— Power and Industrial Projects has constructed and placed in service REF facilities at eleven sites including facilities located at eight third-party owned coal-fired power plants. DTE Energy has sold membership interests in four of the facilities and entered into lease arrangements in three of the facilities. DTE Energy will continue to optimize these facilities by seeking investors or entering into lease arrangements for facilities operating at DTE Electric and other utility sites. DTE Energy is in the process of entering into a sub license agreement with a third-party owned and operated REF facility.

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DTE Energy expects improved production levels of metallurgical coke and pulverized coal supplied to steel industry customers for 2017. The segment has four renewable power generation facilities in operation. On-site energy services will continue to be delivered in accordance with the terms of long-term contracts. DTE Energy will continue to look for additional investment opportunities and other energy projects at favorable prices.

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.

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 March 31,
	2017		2016
	(In millions)
Operating Revenues — Non-utility operations	$	1,052	$	549
Purchased power and gas — non-utility	873		541
Gross Margin	179		8
Operation and maintenance	19		16
Depreciation and amortization	1		1
Taxes other than income	1		1
Operating Income (Loss)	158		(10		)
Other (Income) and Deductions	1		1
Income Tax Expense (Benefit)	61		(4		)
Net Income (Loss) Attributable to DTE Energy Company	$	96	$	(7	)

Operating Revenues — Non-utility operationsincreased$503 million in the three months endedMarch 31, 2017. The increase was due primarily to high gas prices, primarily in the gas structured strategy.

Gross Marginincreased$171 million in the three months endedMarch 31, 2017. The increase was due primarily to timing from MTM adjustments on certain transactions in the gas structured strategy.

The increase in Gross Margin in the three months ended March 31, 2017 represents a $91 million increase in unrealized margins and a $80 million increase in realized margins. The $91 million increase in unrealized margins was due to $103 million of favorable results, primarily in gas structured and power full requirements strategies, offset by $12 million of unfavorable results, primarily in power and gas trading strategies. The $80 million increase in realized margins was due to $85 million of favorable results, primarily in gas structured, gas storage, gas full requirements, and environmental, power and gas trading strategies, offset by $5 million of unfavorable results, primarily in the power full requirements strategy.

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. Included in the $103 million of favorable unrealized results for the three months ended March 31, 2017, related to gas strategies was $95 million of timing related gains which will reverse in future periods as the underlying contracts settle. Included in the $85 million of favorable realized results for the three months ended March 31, 2017 related to gas strategies was $71 million of timing related losses recognized in previous periods that reversed as the underlying contracts settled.

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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 financial reform, regulatory changes, and changes in operating rules of RTOs. 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 income of $16 million in the three months endedMarch 31, 2017 represents an increase of $23 million from the net loss of $7 million in the comparable 2016 period. The increase was due primarily to effective income tax rate adjustments and $13 million of excess tax benefits on stock-based compensation recognized in accordance with ASU 2016-09, Improvements to Employee Share-Based Payment Accounting, which was adopted effective July 1, 2016.

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 2017 will be approximately $1.9 billion. DTE Energy anticipates base level utility capital investments; environmental, renewable, and energy optimization expenditures; expenditures for non-utility businesses; and contributions to equity method investees in 2017 of approximately $3.0 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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	Three Months Ended March 31,
	2017			2016
Cash and Cash Equivalents	(In millions)
Cash Flow From (Used For)
Operating Activities
Net Income	$	394		$	240
Adjustments to reconcile Net Income to Net cash from operating activities:
Depreciation and amortization	249			229
Nuclear fuel amortization	12			15
Allowance for equity funds used during construction	(7		)	(5		)
Deferred income taxes	100			80
Working capital and other	39			186
Net cash from operating activities	787			745
Investing Activities
Plant and equipment expenditures — utility	(533		)	(394		)
Plant and equipment expenditures — non-utility	(22		)	(30		)
Contributions to equity method investees	(112		)	(26		)
Other	26			13
Net cash used for investing activities	(641		)	(437		)
Financing Activities
Issuance of long-term debt, net of issuance costs	496			—
Redemption of long-term debt	(5		)	(11		)
Short-term borrowings, net	(440		)	(134		)
Repurchase of common stock	(51		)	(33		)
Dividends on common stock and other	(156		)	(132		)
Net cash used for financing activities	(156		)	(310		)
Net Decrease in Cash and Cash Equivalents	$	(10	)	$	(2	)

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 increased by $42 million in the three months ended March 31, 2017 compared to the three months ended March 31, 2016. The increase in operating cash flows reflects an increase to Net Income, Depreciation and amortization, and Deferred income taxes, partially offset by a decrease to working capital adjustments.

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.

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.

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Net cash used for investing activities increased by $204 million in 2017 due to increased capital expenditures by the utility business and increased contributions to equity method investees, primarily the NEXUS Pipeline as it continues to develop.

Cash 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 continually evaluates its leverage target, which is currently 50% to 53%, to ensure it is consistent with the objective of a strong investment grade debt rating.

Net cash used for financing activities decreased by $154 million in 2017 due primarily to an increase in Issuance of long-term debt, partially offset by a decrease to Short-term borrowings, net and increased Repurchase of common stock and Dividends on common stock.

Outlook

DTE Energy expects cash flows from operations to increase over the long-term, primarily as a result of growth from the utility and non-utility businesses. Growth in the utilities is expected to be driven primarily by capital spending to maintain and improve the electric generation and electric and natural gas distribution infrastructure and to comply with new and existing state and federal regulations that will result in additional environmental and renewable energy investments 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 $10 million in long-term debt, including capital 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 $2.0 billion of available liquidity at March 31, 2017, consisting of cash and amounts available under unsecured revolving credit agreements.

At the discretion of management and depending upon financial market conditions, DTE Energy may make additional contributions up to $180 million, including contributions from DTE Electric of $145 million, to its pension plans in 2017. DTE Energy does not anticipate making any contributions to the other postretirement benefit plans in 2017.

Various subsidiaries and an equity investee 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 March 31, 2017, 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 approximately $437 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.

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See Notes 5, 9, 10, 11, and 12 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."

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

	Three Months Ended
	March 31, 2017
	(In millions)
MTM at December 31, 2016	$	(86	)
Reclassified to realized upon settlement	(1		)
Changes in fair value recorded to income	111
Amounts recorded to unrealized income	110
Changes in fair value recorded in regulatory liabilities	2
Change in collateral held for others	(11		)
MTM at March 31, 2017	$	15

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The table below shows the maturity of DTE Energy's MTM positions. The positions from 2020 and beyond principally represent longer tenor gas structured transactions:

Source of Fair Value	2017			2018			2019		2020 and Beyond			Total Fair Value
	(In millions)
Level 1	$	(2	)	$	(1	)	$	4	$	(1	)	$	—
Level 2	11			5			8		4			28
Level 3	1			13			4		(41		)	(23		)
MTM before collateral adjustments	$	10		$	17		$	16	$	(38	)	5
Collateral adjustments												10
MTM at March 31, 2017												$	15

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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 business 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

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 March 31, 2017:

	Credit Exposure Before Cash Collateral		Cash Collateral			Net Credit Exposure
	(In millions)
Investment Grade(a)
A− and Greater	$	210	$	(1	)	$	209
BBB+ and BBB	230		—			230
BBB−	33		—			33
Total Investment Grade	473		(1		)	472
Non-investment grade(b)	4		—			4
Internally Rated — investment grade(c)	331		—			331
Internally Rated — non-investment grade(d)	17		(2		)	15
Total	$	825	$	(3	)	$	822

_______________________________________

(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 approximately 17% 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 approximately 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 approximately 15% of the total gross credit exposure.

(d) This category includes counterparties that have not been rated by Moody’s or Standard & Poor’s, and are considered non-investment grade based on DTE Energy’s evaluation of the counterparty’s creditworthiness. The five largest counterparty exposures, combined, for this category represented approximately 2% 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 March 31, 2017, DTE Energy had a floating rate debt-to-total debt ratio of approximately 0.6%.

Foreign Currency Exchange Risk

DTE Energy has foreign currency exchange risk arising from market price fluctuations associated with fixed priced contracts. These contracts are denominated in Canadian dollars and are primarily for the purchase and sale of natural gas and power, as well as for long-term transportation capacity. To limit DTE Energy's exposure to foreign currency exchange fluctuations, DTE Energy has entered into a series of foreign currency exchange forward contracts through December 2020.

Summary of Sensitivity Analyses

The Registrants performed sensitivity analyses on the fair values of commodity contracts and long-term debt obligations. The commodity contracts listed below principally relate to energy marketing and trading activities. The sensitivity analysis involved increasing and decreasing forward prices and rates at March 31, 2017 and 2016 by a hypothetical 10% and calculating the resulting change in the fair values.

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The results of the sensitivity analysis calculations:

	Assuming a 10% Increase in Prices/Rates						Assuming a 10% Decrease in Prices/Rates
	As of March 31,						As of March 31,
Activity	2017			2016			2017			2016			Change in the Fair Value of
	(In millions)
Gas contracts	$	21		$	17		$	(21	)	$	(17	)	Commodity contracts
Power contracts	$	9		$	17		$	(10	)	$	(16	)	Commodity contracts
Interest rate risk — DTE Energy	$	(540	)	$	(356	)	$	526		$	377		Long-term debt
Interest rate risk — DTE Electric	$	(232	)	$	(214	)	$	249		$	230		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 March 31, 2017, 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 March 31, 2017 that have materially affected, or are reasonably likely to materially affect, DTE Energy's internal control over financial reporting. In April 2017, DTE Energy implemented a new customer billing system which is designed to improve efficiency and enhance the customer experience.

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 March 31, 2017, 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 March 31, 2017 that have materially affected, or are reasonably likely to materially affect, DTE Electric's internal control over financial reporting. In April 2017, DTE Electric implemented a new customer billing system which is designed to improve efficiency and enhance the customer experience.

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Part II — Other Information

Item 1. Legal Proceedings

As a result of a multimedia inspection by the EPA, EES Coke, the Michigan coke battery facility, a wholly-owned subsidiary of DTE Energy, received two FOVs in 2015 related to: 1) failing to repeat benzene sampling of waste streams due to a process change and use of calibration gas that is inconsistent with the applicable regulation; and 2) alleged deficiencies in its oil pollution prevention measures and spill prevention, control and countermeasures plan. EES Coke is currently working with the EPA to address the alleged violations. At this time, DTE Energy cannot predict the impact of the final settlement.

For more information on legal proceedings and matters related to the Registrants, see Notes 5 and 11 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 2016 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 March 31, 2017:

	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
01/01/2017 — 01/31/2017	2,232	$	95.68	—	—	—
02/01/2017 — 02/28/2017	568,633	$	97.95	—	—	—
03/01/2017 — 03/31/2017	1,014	$	93.45	—	—	—
Total	571,879			—

_______________________________________

(a) Represents shares of DTE Energy common stock purchased on the open market to provide shares to participants under various employee compensation and incentive programs. This also includes 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.

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Item 6. Exhibits

Exhibit Number	Description	DTE Energy	DTE Electric
	(i) Exhibits filed herewith:
4.298	Supplemental Indenture, dated as of March 1, 2017 to the Amended and Restated Indenture, dated as of April 9, 2001, by and between DTE Energy Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (2017 Series A)	X
12.75	Computation of Ratio of Earnings to Fixed Charges	X
12.76	Computation of Ratio of Earnings to Fixed Charges		X
31.129	Chief Executive Officer Section 302 Form 10-Q Certification of Periodic Report	X
31.130	Chief Financial Officer Section 302 Form 10-Q Certification of Periodic Report	X
31.131	Chief Executive Officer Section 302 Form 10-Q Certification of Periodic Report		X
31.132	Chief Financial Officer Section 302 Form 10-Q Certification of Periodic Report		X
101.INS	XBRL Instance Document	X	X
101.SCH	XBRL Taxonomy Extension Schema	X	X
101.CAL	XBRL Taxonomy Extension Calculation Linkbase	X	X
101.DEF	XBRL Taxonomy Extension Definition Database	X	X
101.LAB	XBRL Taxonomy Extension Label Linkbase	X	X
101.PRE	XBRL Taxonomy Extension Presentation Linkbase	X	X
	(ii) Exhibits furnished herewith:
32.129	Chief Executive Officer Section 906 Form 10-Q Certification of Periodic Report	X
32.130	Chief Financial Officer Section 906 Form 10-Q Certification of Periodic Report	X
32.131	Chief Executive Officer Section 906 Form 10-Q Certification of Periodic Report		X
32.132	Chief Financial Officer Section 906 Form 10-Q Certification of Periodic Report		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:	April 26, 2017
			DTE ENERGY COMPANY
		By:	/S/DONNA M. ENGLAND
			Donna M. England Chief Accounting Officer
			(Duly Authorized Officer)
			DTE ELECTRIC COMPANY
		By:	/S/DONNA M. ENGLAND
			Donna M. England Chief Accounting Officer
			(Duly Authorized Officer)

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EX-4.298

Exhibit 4.298

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

__________________________

SUPPLEMENTAL INDENTURE
DATED AS OF MARCH 1, 2017

__________________________

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

PROVIDING FOR

2017 SERIES A 3.80% SENIOR NOTES DUE 2027

1

SUPPLEMENTAL INDENTURE, dated as of the 1st day of March, 2017, 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 a 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 form or terms of, and to provide for the creation and issue of, a series of its debt securities under the Original Indenture, which shall be known as the “2017 Series A 3.80% Senior Notes due 2027”; 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 a 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 ONE
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 terms shall have the respective meanings set forth below:

1

“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.

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 TWO

TITLE AND TERMS OF THE SECURITIES

SECTION 201.Title of the Securities; Stated Maturity. This Supplemental Indenture hereby establishes a series of Securities, which shall be known as the Company's “2017 Series A 3.80% Senior Notes due 2017” (the “Notes”). The Stated Maturity on which the principal of the Notes shall be due and payable will be March 15, 2027.

SECTION 202.Rank. The 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 Notes. Section 403(2) and Section 403(3) shall be applicable to the 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 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 Notes, “reopen” the Notes so as to increase the aggregate principal amount of the 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 Notes have the same tenor and terms (including, without limitation, rights to receive accrued and unpaid interest) as the Notes then Outstanding. No additional Notes may be issued if an Event of Default has occurred. The 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 Notes will initially be issued in global form (the “Global 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.

(b)    Further to Section 305 of the Original Indenture, any Global Note shall be exchangeable for Notes registered in the name of, and a transfer of a Global Note may be registered to, any Person other than the Depositary for such 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 Note

2

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 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 Notes. Upon the occurrence in respect of a Global Note of any or more of the conditions specified in clause (i), (ii) or (iii) of the preceding sentence, such Global Note may be exchanged for Notes registered in the name of, and the transfer of such Global 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 Notes.

(a)    The Notes shall bear interest at the rate of 3.80% per annum on the principal amount thereof from March 15, 2017, or from the most recent Interest Payment Date to which interest has been paid or duly provided for, until the principal of the 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 Notes will be payable semiannually in arrears on March 15 and September 15 of each year (each such date, an “Interest Payment Date”), commencing September 15, 2017. 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 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 Note will, as provided in the Original Indenture, be paid to the person in whose name the 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 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 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 Original 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, The 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

3

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 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 Note attached hereto as Exhibit A, the 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 Note, redemption shall be effected in accordance with Article Eleven of the Original Indenture.

(a)The Notes shall have such other terms and provisions as are set forth in the form of 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 Notes. Attached hereto as Exhibit A is the form of the Notes.

ARTICLE THREE

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.

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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/ Mark C. Rolling

Name:    Mark C. Rolling

Title:     Vice President and Treasurer

ATTEST:

By:/s/ Lisa A. Muschong

Name:    Lisa A. Muschong

Title:     Vice President, Corporate Secretary

and Chief of Staff

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

By:/s/ Valere Boyd

Name:    Valere Boyd

Title:     Vice President

1

EXHIBIT A

FORM OF 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. ___________                              $__________

NO. : ______

DTE ENERGY COMPANY
2017 SERIES A 3.80% SENIOR NOTES DUE 2027

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 March 15, 2027 (“Stated Maturity” with respect to the principal of this Note), unless previously redeemed, and to pay interest at the rate of 3.80% per annum on said principal sum from March 15, 2017 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 March 15 and September 15 of each year (each such date, an “Interest Payment Date”), commencing September 15, 2017. 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, The 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 “2017 Series A 3.80% Senior Notes due 2027” (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 March 1, 2017 (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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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 determined 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 December 15, 2026.

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

“Reference Treasury Dealer” means: (i) each of Barclays Capital Inc., BNP Paribas Securities Corp., Citigroup Global Markets Inc., J.P. Morgan Securities LLC and Scotia Capital (USA) Inc. (or their respective affiliates which are Primary Treasury Dealers), and their respective successors; provided, however, that if any of the foregoing cease to be a primary U.S. Government securities dealer in the United States (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.

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“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)

A-4

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 $2,000 and integral multiples of $1,000 in excess 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 integral multiples 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

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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.

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

DTE ENERGY COMPANY

By: ______________________________________

Name: 

Title: 

Date: ____________

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: _______________

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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.

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EX-12.75

Exhibit 12.75

DTE Energy Company

Computation of Ratio of Earnings to Fixed Charges

	Three Months Ended			Year Ended December 31,
	March 31, 2017			2016		2015			2014			2013			2012
	(In millions)
Earnings:
Pretax earnings	$	504		$	1,105	$	950		$	1,275		$	922		$	960
Adjustments	(6		)	23		(3		)	(15		)	(26		)	71
Fixed charges	132			493		473			453			461			463
Net earnings	$	630		$	1,621	$	1,420		$	1,713		$	1,357		$	1,494
Fixed Charges:
Interest expense	$	124		$	468	$	446		$	424		$	432		$	441
Adjustments	8			25		27			29			29			22
Fixed charges	$	132		$	493	$	473		$	453		$	461		$	463
Ratio of earnings to fixed charges	4.77			3.29		3.00			3.78			2.94			3.23

EX-12.76

Exhibit 12.76

DTE Electric Company

Computation of Ratio of Earnings to Fixed Charges

	Three Months Ended			Year Ended December 31,
	March 31, 2017			2016			2015			2014			2013			2012
	(In millions)
Earnings:
Pretax earnings	$	163		$	975		$	836		$	830		$	741		$	768
Adjustments	(3		)	(8		)	(11		)	(11		)	(7		)	(7		)
Fixed charges	70			278			277			267			281			286
Net earnings	$	230		$	1,245		$	1,102		$	1,086		$	1,015		$	1,047
Fixed Charges:
Interest expense	$	65		$	261		$	255		$	247		$	264		$	269
Adjustments	5			17			22			20			17			17
Fixed charges	$	70		$	278		$	277		$	267		$	281		$	286
Ratio of earnings to fixed charges	3.29			4.48			3.98			4.07			3.61			3.66

EX-31.129

Exhibit 31.129

FORM 10-Q CERTIFICATION

I, Gerard M. Anderson, 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/ GERARD M. ANDERSON	Date:	April 26, 2017
Gerard M. Anderson Chairman of the Board and Chief Executive Officer of DTE Energy Company

EX-31.130

Exhibit 31.130

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:	April 26, 2017
Peter B. Oleksiak Senior Vice President and Chief Financial Officer of DTE Energy Company

EX-31.131

Exhibit 31.131

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:	April 26, 2017
Gerard M. Anderson  Chairman of the Board and Chief Executive Officer of DTE Electric Company

EX-31.132

Exhibit 31.132

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:	April 26, 2017
Peter B. Oleksiak Senior Vice President and Chief Financial Officer of DTE Electric Company

EX-32.129

Exhibit 32.129

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 March 31, 2017, 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:	April 26, 2017	/S/ GERARD M. ANDERSON
		Gerard M. Anderson Chairman of the Board 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-32.130

Exhibit 32.130

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 March 31, 2017, 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:	April 26, 2017	/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-32.131

Exhibit 32.131

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 March 31, 2017, 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:	April 26, 2017	/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-32.132

Exhibit 32.132

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 March 31, 2017, 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:	April 26, 2017	/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	3 Months Ended
	Mar. 31, 2017 shares
Entity Registrant Name	DTE ENERGY CO
Entity Central Index Key	0000936340
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Mar. 31, 2017
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	Q1
Amendment Flag	false
Entity Common Stock, Shares Outstanding	179,387,424
DTE Electric
Entity Registrant Name	DTE ELECTRIC CO
Entity Central Index Key	0000028385
Entity Filer Category	Non-accelerated Filer
Document Type	10-Q
Document Fiscal Period Focus	Q1
Amendment Flag	false
Entity Common Stock, Shares Outstanding	138,632,324

XML

Consolidated Statements of Operations (Unaudited) - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Operating Revenues
Utility operations	$ 1,718	$ 1,664
Non-utility operations	1,518	902
Operating Revenues	3,236	2,566
Operating Expenses
Fuel, purchased power, and gas — utility	529	565
Fuel, purchased power, and gas — non-utility	1,180	776
Operation and maintenance	600	516
Depreciation and amortization	249	229
Taxes other than income	109	99
Operating Expenses	2,667	2,185
Operating Income	569	381
Other (Income) and Deductions
Interest expense	125	113
Interest income	(3)	(11)
Other income	64	52
Other expenses	7	8
Total Other (Income) and Deductions	65	58
Income Before Income Taxes	504	323
Income Tax Expense	110	83
Net Income	394	240
Less: Net Loss Attributable to Noncontrolling Interests	(6)	(7)
Net Income Attributable to DTE Energy Company/DTE Electric Company	$ 400	$ 247
Basic Earnings per Common Share
Net Income Attributable to DTE Energy Company (in dollars per share)	$ 2.23	$ 1.38
Diluted Earnings per Common Share
Net Income Attributable to DTE Energy Company (in dollars per share)	$ 2.23	$ 1.37
Weighted Average Common Shares Outstanding
Basic (in shares)	179	179
Diluted (in shares)	179	180
Dividends Declared per Common Share (in dollars per share)	$ 0.825	$ 0.73
DTE Electric
Operating Revenues
Utility operations	$ 1,175	$ 1,153
Operating Expenses
Fuel and purchased power — utility	314	335
Operation and maintenance	383	324
Depreciation and amortization	181	176
Taxes other than income	80	73
Operating Expenses	958	908
Operating Income	217	245
Other (Income) and Deductions
Interest expense	66	65
Interest income	0	(8)
Other income	19	16
Other expenses	7	7
Total Other (Income) and Deductions	54	48
Income Before Income Taxes	163	197
Income Tax Expense	57	70
Net Income Attributable to DTE Energy Company/DTE Electric Company	$ 106	$ 127

XML

Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Net Income	$ 394	$ 240
Net Income	400	247
Other comprehensive income, net of tax:
Benefit obligations, net of taxes of $2, for both periods	4	3
Foreign currency translation	0	2
Other comprehensive income	4	5
Comprehensive income	398	245
Less comprehensive loss attributable to noncontrolling interests	(6)	(7)
Comprehensive Income Attributable to DTE Energy Company/DTE Electric Company	404	252
DTE Electric
Net Income	106	127
Other comprehensive income, net of tax:
Other comprehensive income	0	0
Comprehensive Income Attributable to DTE Energy Company/DTE Electric Company	$ 106	$ 127

XML

Consolidated Statements of Comprehensive Income (Unaudited) (Parentheticals) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Tax effect on benefit obligation	$ 2	$ 2

XML

Consolidated Statements of Financial Position (Unaudited) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Current Assets
Cash and cash equivalents	$ 82	$ 92
Restricted cash	20	21
Accounts receivable (less allowance for doubtful accounts)
Customer	1,408	1,522
Other	101	71
Inventories
Fuel and gas	286	416
Materials and supplies	354	356
Derivative assets	68	47
Regulatory assets	26	42
Other	222	195
Total Current Assets	2,567	2,762
Investments
Nuclear decommissioning trust funds	1,364	1,320
Investments in equity method investees	868	752
Other	210	201
Total Investments	2,442	2,273
Property
Property, plant, and equipment	30,287	30,029
Accumulated depreciation and amortization	(10,421)	(10,299)
Property, plant, and equipment, net	19,866	19,730
Other Assets
Goodwill	2,292	2,286
Regulatory assets	3,833	3,871
Intangible assets	837	842
Notes receivable	71	73
Derivative assets	73	34
Other	168	170
Total Other Assets	7,274	7,276
Total Assets	32,149	32,041
Accounts payable
Accounts payable	910	1,079
Accrued interest	131	96
Dividends payable	148	148
Short-term borrowings	59	499
Current portion long-term debt, including capital leases	13	14
Derivative liabilities	33	69
Gas inventory equalization	86	0
Regulatory liabilities	37	34
Short-term borrowings
Other	417	498
Total Current Liabilities	1,834	2,437
Long-Term Debt (net of current portion)
Mortgage bonds, notes, and other	10,999	10,506
Junior subordinated debentures	756	756
Capital lease obligations	3	7
Total Long-Term Debt (net of current portion)	11,758	11,269
Other Liabilities
Deferred income taxes	4,270	4,162
Regulatory liabilities	563	555
Asset retirement obligations	2,229	2,197
Unamortized investment tax credit	91	93
Derivative liabilities	93	98
Accrued pension liability	1,022	1,152
Accrued postretirement liability	63	36
Nuclear decommissioning	203	194
Other	335	349
Total Other Liabilities	8,869	8,836
Commitments and Contingencies
Equity
Common stock	3,958	4,030
Retained earnings	5,365	5,114
Accumulated other comprehensive income (loss)	(129)	(133)
Total DTE Energy Company Equity	9,194	9,011
Noncontrolling interests	494	488
Total Equity	9,688	9,499
Total Liabilities and Equity	32,149	32,041
DTE Electric
Current Assets
Cash and cash equivalents	11	13
Accounts receivable (less allowance for doubtful accounts)
Customer	654	728
Affiliates	19	12
Other	38	29
Inventories
Fuel and gas	178	225
Materials and supplies	276	271
Regulatory assets	11	36
Prepaid property tax	89	45
Other	16	18
Total Current Assets	1,292	1,377
Investments
Nuclear decommissioning trust funds	1,364	1,320
Other	34	36
Total Investments	1,398	1,356
Property
Property, plant, and equipment	22,276	22,094
Accumulated depreciation and amortization	(7,812)	(7,721)
Property, plant, and equipment, net	14,464	14,373
Other Assets
Regulatory assets	3,090	3,113
Intangible assets	32	31
Prepaid postretirement costs — affiliates	114	114
Other	125	125
Total Other Assets	3,361	3,383
Total Assets	20,515	20,489
Accounts payable
Affiliates	55	58
Other	384	452
Accrued interest	72	65
Current portion long-term debt, including capital leases	5	6
Regulatory liabilities	33	27
Short-term borrowings
Affiliates	205	117
Other	59	62
Other	149	146
Total Current Liabilities	962	933
Long-Term Debt (net of current portion)
Mortgage bonds, notes, and other	5,879	5,878
Capital lease obligations	3	7
Total Long-Term Debt (net of current portion)	5,882	5,885
Other Liabilities
Deferred income taxes	3,850	3,793
Regulatory liabilities	241	229
Asset retirement obligations	2,041	2,012
Unamortized investment tax credit	88	90
Nuclear decommissioning	203	194
Accrued pension liability — affiliates	885	1,008
Accrued postretirement liability — affiliates	290	269
Other	79	81
Total Other Liabilities	7,677	7,676
Commitments and Contingencies
Equity
Common stock	4,206	4,206
Retained earnings	1,786	1,787
Accumulated other comprehensive income (loss)	2	2
Total DTE Energy Company Equity	5,994	5,995
Total Liabilities and Equity	$ 20,515	$ 20,489

XML

Consolidated Statements of Financial Position (Unaudited) (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Allowance for doubtful accounts	$ 32	$ 41
Shareholder’s Equity
Common stock, shares authorized (in shares)	400,000,000	400,000,000
Common stock, shares issued (in shares)	179,387,424	179,432,581
Common stock, shares outstanding (in shares)	179,387,424	179,432,581
DTE Electric
Allowance for doubtful accounts	$ 19	$ 25
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

XML

Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Operating Activities
Net Income	$ 394	$ 240
Net Income	400	247
Adjustments to reconcile Net Income to net cash from operating activities:
Depreciation and amortization	249	229
Nuclear fuel amortization	12	15
Allowance for equity funds used during construction	(7)	(5)
Deferred income taxes	100	80
Equity earnings of equity method investees	(26)	(15)
Dividends from equity method investees	18	18
Changes in assets and liabilities:
Accounts receivable, net	84	97
Inventories	135	143
Accounts payable	(33)	(93)
Gas inventory equalization	86	87
Accrued pension liability	(130)	(3)
Accrued postretirement liability	27	(29)
Derivative assets and liabilities	(100)	40
Regulatory assets and liabilities	128	34
Other current and noncurrent assets and liabilities	(150)	(93)
Net cash from operating activities	787	745
Investing Activities
Plant and equipment expenditures — utility	(533)	(394)
Plant and equipment expenditures — non-utility	(22)	(30)
Proceeds from sale of nuclear decommissioning trust fund assets	394	260
Investment in nuclear decommissioning trust funds	(378)	(262)
Distributions from equity method investees	6	3
Contributions to equity method investees	(112)	(26)
Other	4	12
Net cash used for investing activities	(641)	(437)
Financing Activities
Issuance of long-term debt, net of issuance costs	496	0
Redemption of long-term debt	(5)	(11)
Short-term borrowings, net	(440)	(134)
Repurchase of common stock	(51)	(33)
Dividends on common stock	(148)	(131)
Other	(8)	(1)
Net cash used for financing activities	(156)	(310)
Net Increase (Decrease) in Cash and Cash Equivalents	(10)	(2)
Cash and Cash Equivalents at Beginning of Period	92	37
Cash and Cash Equivalents at End of Period	82	35
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	196	134
DTE Electric
Operating Activities
Net Income	106	127
Adjustments to reconcile Net Income to net cash from operating activities:
Depreciation and amortization	181	176
Nuclear fuel amortization	12	15
Allowance for equity funds used during construction	(6)	(4)
Deferred income taxes	57	70
Changes in assets and liabilities:
Accounts receivable, net	58	57
Inventories	44	31
Accounts payable	26	25
Accrued pension liability — affiliates	(123)	3
Accrued postretirement liability — affiliates	21	(19)
Regulatory assets and liabilities	122	40
Other current and noncurrent assets and liabilities	(87)	(68)
Net cash from operating activities	411	453
Investing Activities
Plant and equipment expenditures	(408)	(315)
Proceeds from sale of assets	0	6
Proceeds from sale of nuclear decommissioning trust fund assets	394	260
Investment in nuclear decommissioning trust funds	(378)	(262)
Other	5	14
Net cash used for investing activities	(387)	(297)
Financing Activities
Redemption of long-term debt	0	(10)
Short-term borrowings, net — affiliate	88	22
Short-term borrowings, net — other	(3)	(61)
Dividends on common stock	(108)	(105)
Other	(3)	0
Net cash used for financing activities	(26)	(154)
Net Increase (Decrease) in Cash and Cash Equivalents	(2)	2
Cash and Cash Equivalents at Beginning of Period	13	15
Cash and Cash Equivalents at End of Period	11	17
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	$ 134	$ 100

XML

Consolidated Statements of Changes in Equity (Unaudited) - 3 months ended Mar. 31, 2017 - 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, shares at Dec. 31, 2016	179,432,581	179,433,000				138,632,324	138,632,000
Beginning Balance at Dec. 31, 2016	$ 9,499	$ 4,030	$ 5,114	$ (133)	$ 488
Beginning Balance at Dec. 31, 2016	9,011					$ 5,995	$ 1,386	$ 2,820	$ 1,787	$ 2
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income (Loss)	394		400		(6)
Net Income	400					106			106
Dividends declared on common stock	(148)		(148)			(108)			(108)
Repurchase of common stock, shares		(524,000)
Repurchase of common stock	(51)	$ (51)
Benefit obligations, net of tax	4			4
Stock-based compensation, net contributions from noncontrolling interests, and other, shares		478,000
Stock-based compensation, net contributions from noncontrolling interests, and other	$ (10)	$ (21)	(1)		12	$ 1			1
Ending Balance, shares at Mar. 31, 2017	179,387,424	179,387,000				138,632,324	138,632,000
Ending Balance at Mar. 31, 2017	$ 9,688	$ 3,958	$ 5,365	$ (129)	$ 494
Ending Balance at Mar. 31, 2017	$ 9,194					$ 5,994	$ 1,386	$ 2,820	$ 1,786	$ 2

XML

Organization and Basis of Presentation

3 Months Ended

Mar. 31, 2017

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) natural gas pipelines, gathering, and storage; 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 2016 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, 2017.

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 accounted for under the equity method.

DTE Energy owns a 55% 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. See Note 4 to the Consolidated Financial Statements, "Acquisition," for more information.

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 March 31, 2017, 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 March 31, 2017, 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. For non-consolidated VIEs, the maximum risk exposure is generally limited to its investment, notes receivable, and future funding commitments.

The following table summarizes the major Consolidated Statements of Financial Position items for consolidated VIEs as of March 31, 2017 and December 31, 2016. All assets and liabilities of a consolidated VIE are presented where it has been determined that aconsolidated 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.

	March 31, 2017						December 31, 2016
	SGG(a)		Other		Total		SGG(a)		Other		Total
	(In millions)
ASSETS
Cash and cash equivalents	$	52	$	11	$	63	$	36	$	27	$	63
Restricted cash	—		7		7		—		7		7
Accounts receivable	10		19		29		8		34		42
Inventories	3		59		62		3		112		115
Property, plant, and equipment, net	397		75		472		398		76		474
Goodwill	22		—		22		17		—		17
Intangible assets	583		—		583		586		—		586
Other current and long-term assets	—		1		1		1		1		2
	$	1,067	$	172	$	1,239	$	1,049	$	257	$	1,306
LIABILITIES
Accounts payable and accrued current liabilities	$	19	$	21	$	40	$	19	$	32	$	51
Current portion long-term debt, including capital leases	—		5		5		—		5		5
Mortgage bonds, notes, and other	—		4		4		—		5		5
Other current and long-term liabilities	2		14		16		2		15		17
	$	21	$	44	$	65	$	21	$	57	$	78

_____________________________________

(a)Amounts shown are 100% of SGG's assets and liabilities, of which DTE Energy owns 55%.

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

	March 31, 2017		December 31, 2016
	(In millions)
Investments in equity method investees	$	186	$	187
Notes receivable	$	15	$	15
Future funding commitments	$	6	$	7

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Significant Accounting Policies

3 Months Ended

Mar. 31, 2017

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 March 31,
	2017		2016
	(In millions)
Equity earnings of equity method investees	$	26	$	15
Income from REF investees	18		19
Gains from trading securities	8		5
Allowance for equity funds used during construction	7		5
Contract services	4		6
Other	1		2
	$	64	$	52

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

	Three Months Ended March 31,
	2017		2016
	(In millions)
Gains from trading securities allocated from DTE Energy	$	8	$	5
Allowance for equity funds used during construction	6		4
Contract services	4		6
Other	1		1
	$	19	$	16

Changes in Accumulated Other Comprehensive Income (Loss)

For the three months endedMarch 31, 2017 and 2016, reclassifications out of Accumulated other comprehensive income (loss) for the Registrants were not material. 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.

Income Taxes

The effective tax rate and unrecognized tax benefits of the Registrants are as follows:

	Effective Tax Rate				Unrecognized Tax Benefits
	Three Months Ended March 31,				March 31,
	2017		2016		2017
					(In millions)
DTE Energy	22	%	26	%	$	10
DTE Electric	35	%	36	%	$	13

The 4%decrease in DTE Energy's effective tax rate for the three months endedMarch 31, 2017 is primarily due to $13 million of excess tax benefits on stock-based compensation recognized in accordance with ASU 2016-09, Improvements to Employee Share-Based Payment Accounting, which was adopted effective July 1, 2016.

DTE Energy had $7 million of unrecognized tax benefits that, if recognized, would favorably impact its effective tax rate. DTE Electric had $8 million of unrecognized tax benefits that, 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 with DTE Energy of $10 million and $9 million at March 31, 2017 and December 31, 2016, respectively.

Unrecognized Compensation Costs

As of March 31, 2017, DTE Energy had $92 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 1.82 years.

Allocated Stock-Based Compensation

DTE Electric received an allocation of costs from DTE Energy associated with stock-based compensation of $8 million and $10 million for the three months ended March 31, 2017 and 2016, respectively.

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New Accounting Pronouncements

3 Months Ended

Mar. 31, 2017

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New Accounting Pronouncements

NEW ACCOUNTING PRONOUNCEMENTS

Recently Adopted Pronouncements

In July 2015, the FASB issued ASU No. 2015-11, Inventory (Topic 330), Simplifying the Measurement of Inventory. The ASU replaces the current lower of cost or market test with a lower of cost or net realizable value test when cost is determined on a first-in, first-out or average cost basis. The standard is effective for public entities for annual reporting periods beginning after December 15, 2016, and interim periods therein. It is applied prospectively. The Registrants adopted this ASU at January 1, 2017. The adoption of the ASU did not have a significant impact on the Registrants' Consolidated Financial Statements.

Recently Issued Pronouncements

In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606), as amended. The objectives of this ASU are to improve upon revenue recognition requirements by providing a single comprehensive model to determine the measurement of revenue and timing of recognition. The core principle is that an entity will recognize revenue to depict the transfer of goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services. This ASU also requires expanded qualitative and quantitative disclosures regarding the nature, amount, timing, and uncertainty of revenues and cash flows arising from contracts with customers. The standard is effective for the first interim period within annual reporting periods beginning after December 15, 2017. The standard is to be applied retrospectively, and early adoption is permitted in the preceding year. The Registrants do not plan to early adopt the standard. The Registrants are currently assessing the impact of the ASU, as amended, on their Consolidated Financial Statements as well as the transition method the Registrants will use to adopt the guidance. The Registrants have completed the preliminary evaluations of the impact of this guidance and do not expect the ASU to significantly affect results of operations for tariff-based sales, which represent a majority of the Registrants' revenues, and the remaining non-tariff revenues. The Registrants will continue to evaluate the impact of the ASU on existing revenue recognition policies and procedures and monitor the unresolved industry-related issues. Specifically, the Registrants are considering whether the new guidance will affect accounting for certain contracts where collectibility is in question, contributions in aid of construction, and other utility industry-related areas. The Registrants are evaluating information that would be useful for users of the Consolidated Financial Statements, including information already provided in disclosures outside of the Combined Notes to the Consolidated Financial Statements.

In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842), a replacement of Leases (Topic 840). This guidance requires a lessee to account for leases as finance or operating leases. Both 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. For lessors, the standard modifies the classification criteria and the accounting for sales-type and direct financing leases. Entities will classify leases to determine how to recognize lease-related revenue and expense. This ASU is effective for public entities for fiscal years, and interim periods within those years, beginning after December 15, 2018, and early adoption is permitted. A modified retrospective approach is required for leases existing or entered into after the beginning of the earliest comparative period in the Consolidated Financial Statements. The Registrants expect an increase in assets and liabilities, however, they are currently assessing the impact of this ASU on their Consolidated Financial Statements.

In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments — Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments. The amendments in this update replace the incurred loss impairment methodology in current GAAP with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates.  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 are currently assessing the impact of this standard on their Consolidated Financial Statements.

In March 2017, the FASB issued ASU No. 2017-07, Compensation — Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. The amendments in this update require that an employer report the service cost component in the same line item or items as other compensation costs arising from services rendered by the pertinent employees during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside income from operations. The amendments in this update also allow only the service cost component to be eligible for capitalization when applicable. The standard will be applied retrospectively for the presentation of the service cost component and the other components of net periodic pension cost and net periodic postretirement benefit cost in the income statement and prospectively for the capitalization of the service cost component of net periodic pension cost and net periodic postretirement benefit in assets. The ASU is effective for the Registrants beginning after December 15, 2017, including interim periods therein. Early adoption is permitted. The components of net periodic benefit costs (credits) for pension benefits and other postretirement benefits are disclosed in Note 12 to the Consolidated Financial Statements, "Retirement Benefits and Trusteed Assets." The ASU will not have a significant impact on the Registrants' Consolidated Financial Statements.

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Acquisition

3 Months Ended

Mar. 31, 2017

Business Combinations [Abstract]

Acquisition

ACQUISITION

Gas Storage and Pipelines Acquisition

Effective October 1, 2016, DTE Energy closed on the purchase of midstream natural gas assets in support of the strategy to continue to grow and earn competitive returns for shareholders. DTE Energy purchased 100% of AGS, located in Pennsylvania and West Virginia, and 40% of SGG, located in West Virginia, from M3 Midstream. In addition, DTE Energy purchased 15% of SGG from Vega Energy Partners, resulting in 55% total ownership of SGG by DTE Energy.

Consideration transferred for the entities acquired was approximately $1.2 billion paid in cash and the assumption of SGG debt of $204 million. The $204 million of debt was comprised of DTE Energy's 55% interest in SGG of $112 million and 45% related to noncontrolling interest partners of $92 million. The acquisition was financed through the issuance of Equity Units and Senior Notes. These entities are part of DTE Energy's Gas Storage and Pipelines segment which owns and manages a network of natural gas gathering, transmission, and storage facilities servicing the Midwest, Ontario, and Northeast markets. SGG has been deemed to be a VIE, and DTE Energy is the primary beneficiary. Thus, SGG's assets and liabilities are included in DTE Energy's Consolidated Statements of Financial Position. See Note 1 to the Consolidated Financial Statements, "Organization and Basis of Presentation," for more information.

DTE Energy has applied purchase accounting to the acquired entities. The allocation of the purchase price included in the Consolidated Statements of Financial Position is preliminary and may be revised up to one year from the date of acquisition due to adjustments in the estimated fair value of the assets acquired and the liabilities assumed. The purchase price is subject to (i) final working capital settlement adjustments, and (ii) resolution of any indemnification claims that might be deducted from the $130 million of cash consideration paid and held in escrow. As such, DTE Energy cannot estimate the potential amount of the additional revisions to the purchase price allocation in 2017. The excess purchase price over the fair value of net assets acquired totaled approximately $268 million and was classified as goodwill. During the first quarter of 2017, a final working capital adjustment was recognized resulting in an additional goodwill of approximately $6 million. The factors contributing to the recognition of goodwill are based on various strategic benefits that are expected to be realized from the AGS and SGG acquisition. The acquisition provides DTE Energy with 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 a new set of producer relationships that may lead to more partnering opportunities. The goodwill is expected to be deductible for income tax purposes.

The preliminary allocation of the purchase price was based on estimated fair values of the AGS and SGG assets acquired and liabilities assumed at the date of acquisition, October 1, 2016. The components of the preliminary purchase price allocation were as follows:

	(In millions)
Assets
Cash	$	83
Accounts receivable	24
Inventory	6
Property, plant, and equipment, net	730
Goodwill	268
Customer relationship intangibles	770
Other current assets	1
	$	1,882
Liabilities
Accounts payable	$	19
Other current liabilities	14
Long-term debt	204
Other long-term liabilities	26
	$	263
Less noncontrolling interest	390
Total cash consideration	$	1,229

The intangible assets recorded as a result of the acquisition pertain to existing customer relationships, which were valued at approximately $770 million as of the acquisition date. The fair value of the intangible assets acquired was estimated by applying the income approach. The income approach was based upon discounted projected future cash flows attributable to the existing contracts and agreements. The fair value measurement was based on significant unobservable inputs, including management estimates and assumptions, and thus represents a Level 3 measurement, pursuant to the applicable accounting guidance. Key estimates and inputs included revenue and expense projections and discount rates based on the risks associated with the entities. The intangible assets are amortized on a straight line basis over a period of 40 years, which is based on the number of years the assets are expected to economically contribute to the business. The expected economic benefit incorporates existing customer contracts with a weighted-average amortization life of 10 years and expected renewal rates, based on the estimated volume and production lives of gas resources in the region.

The fair value of the noncontrolling interest in the table above was derived based on the purchase price DTE Energy paid for the 55% interest in SGG.

DTE Energy evaluated pre-acquisition contingencies relating to AGS and SGG that existed as of the acquisition date. Based on the evaluation, DTE Energy determined that $39 million of certain pre-acquisition contingencies, related to repairing existing right-of-ways, are probable in nature and estimable as of the acquisition date. Accordingly, DTE Energy recorded its best estimates for these contingencies as part of the purchase accounting for AGS and SGG.

DTE Energy incurred $15 million of direct transaction costs for the year ended December 31, 2016. These costs were primarily related to advisory fees and included in Operation and maintenance in DTE Energy's 2016 Consolidated Statements of Operations.

DTE Energy's 2016 Consolidated Statements of Operations included Operating Revenues — Non-utility operations of $39 million and Net Income of $4 million associated with the acquired entities for the three-month period following the acquisition date, excluding the $15 million transaction costs described above. The pro forma financial information was not presented for DTE Energy because the effects of the acquisition were not material to the Consolidated Statements of Operations.

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Regulatory Matters

3 Months Ended

Mar. 31, 2017

Public Utilities, General Disclosures [Abstract]

Regulatory Matters

REGULATORY MATTERS

2016 Electric Rate Case Filing

DTE Electric filed a rate case with the MPSC on February 1, 2016 requesting an increase in base rates of $344 million based on a projected twelve-month period ending July 31, 2017. On August 1, 2016, DTE Electric self-implemented a base rate increase of $245 million. On January 31, 2017, the MPSC issued an order approving an annual revenue increase of $184 million for service rendered on or after February 7, 2017. The MPSC authorized a return on equity of 10.1%. DTE Electric has recorded a refund liability of $37 million, representing the total estimated refund due to customers, inclusive of interest, at March 31, 2017. DTE Electric will file a self-implementation reconciliation with the MPSC by April 30, 2017.

2017 Electric Rate Case Filing

DTE Electric filed a rate case with the MPSC on April 19, 2017 requesting an increase in base rates of $231 million based on a projected twelve-month period ending October 31, 2018. The requested increase in base rates is due primarily to an increase in net plant resulting from infrastructure investments, environmental compliance, and reliability improvement projects. The rate filing also includes projected changes in sales, operation and maintenance expenses, and working capital. The rate filing also requests an increase in return on equity from 10.1% to 10.5% on capital structure. DTE Electric anticipates self-implementing a rate increase in November 2017 with an MPSC order expected by April 2018.

PSCR Proceedings

The PSCR process is designed to allow DTE Electric to recover all of its power supply costs if incurred under reasonable and prudent policies and practices. DTE Electric's power supply costs include fuel and related transportation costs, purchased and net interchange power costs, NOx and SO₂ emission allowances costs, urea costs, transmission costs, MISO, and other related costs. The MPSC reviews these costs, policies, and practices for prudence in annual plan and reconciliation filings.

2015 PSCR Year — In March 2016, DTE Electric filed its 2015 PSCR reconciliation. The Administrative Law Judge and certain intervenors in the reconciliation case have challenged the recovery of approximately $13 million of costs related to a customer settlement. Resolution of this matter is expected in 2017.

2016 DTE Main Electric Depreciation Case Filing

DTE Electric filed a depreciation case with the MPSC on November 1, 2016 requesting an increase in depreciation rates of $156 million when compared to current depreciation rates for Plant in service balances as of December 31, 2015. An MPSC order in this case is expected in 2018.

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Earnings Per Share

3 Months Ended

Mar. 31, 2017

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 March 31,
	2017			2016
	(In millions, except per share amounts)
Basic Earnings per Share
Net income attributable to DTE Energy Company	$	400		$	247
Less allocation of earnings to net restricted stock awards	(1		)	—
Net income available to common shareholders — basic	$	399		$	247
Average number of common shares outstanding	179			179
Basic Earnings per Common Share	$	2.23		$	1.38
Diluted Earnings per Share
Net income attributable to DTE Energy Company	$	400		$	247
Less allocation of earnings to net restricted stock awards	(1		)	—
Net income available to common shareholders — diluted	$	399		$	247
Average number of common shares outstanding	179			180
Diluted Earnings per Common Share(a)	$	2.23		$	1.37

_______________________________________

(a) The October 2016 Equity Units are potentially dilutive securities but were excluded from the calculation of diluted EPS for the three months ended March 31, 2017, as the dilutive stock price threshold was not met.

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Fair Value

3 Months Ended

Mar. 31, 2017

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 March 31, 2017 and December 31, 2016. 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:

	March 31, 2017															December 31, 2016
	Level 1			Level 2			Level 3			Netting(a)			Net Balance			Level 1			Level 2			Level 3			Netting(a)			Net Balance
	(In millions)
Assets:
Cash equivalents(b)	$	14		$	3		$	—		$	—		$	17		$	14		$	3		$	—		$	—		$	17
Nuclear decommissioning trusts(c)
Equity securities	890			—			—			—			890			887			—			—			—			887
Fixed income securities	11			460			—			—			471			11			414			—			—			425
Cash equivalents	3			—			—			—			3			8			—			—			—			8
Other investments(d)
Equity securities	110			—			—			—			110			104			—			—			—			104
Fixed income securities	63			—			—			—			63			61			—			—			—			61
Derivative assets
Commodity Contracts
Natural Gas	82			151			71			(206		)	98			216			79			53			(306		)	42
Electricity	—			152			34			(146		)	40			—			154			39			(157		)	36
Other	—			—			1			—			1			—			—			2			—			2
Foreign currency exchange contracts	—			5			—			(3		)	2			—			6			—			(5		)	1
Total derivative assets	82			308			106			(355		)	141			216			239			94			(468		)	81
Total	$	1,173		$	771		$	106		$	(355	)	$	1,695		$	1,301		$	656		$	94		$	(468	)	$	1,583
Liabilities:
Derivative liabilities
Commodity Contracts
Natural Gas	$	(82	)	$	(121	)	$	(86	)	$	202		$	(87	)	$	(226	)	$	(86	)	$	(149	)	$	321		$	(140	)
Electricity	—			(157		)	(40		)	158			(39		)	—			(159		)	(30		)	163			(26		)
Other	—			—			(3		)	3			—			—			—			(3		)	2			(1		)
Foreign currency exchange contracts	—			(2		)	—			2			—			—			(3		)	—			3			—
Total derivative liabilities	(82		)	(280		)	(129		)	365			(126		)	(226		)	(248		)	(182		)	489			(167		)
Total	$	(82	)	$	(280	)	$	(129	)	$	365		$	(126	)	$	(226	)	$	(248	)	$	(182	)	$	489		$	(167	)
Net Assets (Liabilities) at end of period	$	1,091		$	491		$	(23	)	$	10		$	1,569		$	1,075		$	408		$	(88	)	$	21		$	1,416
Assets:
Current	$	78		$	228		$	60		$	(281	)	$	85		$	205		$	199		$	60		$	(400	)	$	64
Noncurrent	1,095			543			46			(74		)	1,610			1,096			457			34			(68		)	1,519
Total Assets	$	1,173		$	771		$	106		$	(355	)	$	1,695		$	1,301		$	656		$	94		$	(468	)	$	1,583
Liabilities:
Current	$	(63	)	$	(213	)	$	(36	)	$	279		$	(33	)	$	(203	)	$	(211	)	$	(79	)	$	424		$	(69	)
Noncurrent	(19		)	(67		)	(93		)	86			(93		)	(23		)	(37		)	(103		)	65			(98		)
Total Liabilities	$	(82	)	$	(280	)	$	(129	)	$	365		$	(126	)	$	(226	)	$	(248	)	$	(182	)	$	489		$	(167	)
Net Assets (Liabilities) at end of period	$	1,091		$	491		$	(23	)	$	10		$	1,569		$	1,075		$	408		$	(88	)	$	21		$	1,416

_______________________________________

(a) 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.

(b) At March 31, 2017 and December 31, 2016, available-for-sale securities of $17 million, included $7 million and $10 million of cash equivalents included in Restricted cash and Other investments on DTE Energy's Consolidated Statements of Financial Position, respectively.

(c) At March 31, 2017, the Nuclear Decommissioning Master Trust had outstanding commitments to invest in private equity investments of approximately $15 million. These commitments will be funded by existing nuclear decommissioning trust funds.

(d) 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:

	March 31, 2017								December 31, 2016
	Level 1		Level 2		Level 3		Net Balance		Level 1		Level 2		Level 3		Net Balance
	(In millions)
Assets:
Cash equivalents(a)	$	8	$	3	$	—	$	11	$	8	$	3	$	—	$	11
Nuclear decommissioning trusts(b)
Equity securities	890		—		—		890		887		—		—		887
Fixed income securities	11		460		—		471		11		414		—		425
Cash equivalents	3		—		—		3		8		—		—		8
Other investments
Equity securities	9		—		—		9		9		—		—		9
Derivative assets — FTRs	—		—		1		1		—		—		2		2
Total	$	921	$	463	$	1	$	1,385	$	923	$	417	$	2	$	1,342
Assets:
Current	$	8	$	3	$	1	$	12	$	8	$	3	$	2	$	13
Noncurrent	913		460		—		1,373		915		414		—		1,329
Total Assets	$	921	$	463	$	1	$	1,385	$	923	$	417	$	2	$	1,342

_______________________________________

(a) At March 31, 2017 and December 31, 2016, available-for-sale securities of $11 million consisted of cash equivalents included in Other investments on DTE Electric's Consolidated Statements of Financial Position, respectively.

(b) At March 31, 2017, the Nuclear Decommissioning Master Trust had outstanding commitments to invest in private equity investments of approximately $15 million. These commitments will be funded by existing nuclear decommissioning trust funds.

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 institutional mutual funds and commingled funds. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. Non-exchange-traded fixed income securities are valued based upon quotations available from brokers or pricing services. The institutional mutual funds hold exchange-traded equity or debt securities (exchange and non-exchange traded) and are valued based on publicly available NAVs. 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 to be 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. Additionally, the Registrants selectively corroborate the fair value of securities by comparison of market-based price sources. Investment policies and procedures are determined by DTE Energy's Trust Investments Department which reports to DTE Energy's Vice President and Treasurer.

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 March 31, 2017												Three Months Ended March 31, 2016
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of January 1	$	(96	)	$	9		$	(1	)	$	(88	)	$	(5	)	$	6		$	(5	)	$	(4	)
Transfers into Level 3 from Level 2	—			—			—			—			—			—			—			—
Transfers from Level 3 into Level 2	—			—			—			—			(1		)	—			—			(1		)
Total gains (losses)
Included in earnings	52			(9		)	1			44			(20		)	(58		)	(1		)	(79		)
Recorded in Regulatory liabilities	—			—			2			2			—			—			(2		)	(2		)
Purchases, issuances, and settlements
Settlements	29			(6		)	(4		)	19			(8		)	36			1			29
Net Liabilities as of March 31	$	(15	)	$	(6	)	$	(2	)	$	(23	)	$	(34	)	$	(16	)	$	(7	)	$	(57	)
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 March 31, 2017 and 2016 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	$	35		$	(3	)	$	—		$	32		$	(72	)	$	(3	)	$	(1	)	$	(76	)

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 March 31,
	2017			2016
	(In millions)
Net Assets as of January 1	$	2		$	3
Change in fair value recorded in Regulatory liabilities	2			(2		)
Purchases, issuances, and settlements
Settlements	(3		)	—
Net Assets as of March 31	$	1		$	1
The amount of total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets held at March 31, 2017 and 2016 and reflected in DTE Electric's Consolidated Statements of Financial Position	$	—		$	—

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 months endedMarch 31, 2017 and 2016, 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:

	March 31, 2017
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	71	$	(86	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(0.87	)	—	$	6.25	/MMBtu	$	(0.14	)/MMBtu
Electricity	$	34	$	(40	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(6	)	—	$	8	/MWh	$	1	/MWh

	December 31, 2016
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	53	$	(149	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.00	)	—	$	7.90	/MMBtu	$	(0.05	)/MMBtu
Electricity	$	39	$	(30	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(6	)	—	$	12	/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 fair value of financial instruments included in the table below is determined by using quoted market prices when available. When quoted prices are not available, pricing services may be used to determine the fair value with reference to observable interest rate indexes. The Registrants have obtained an understanding of how the fair values are derived. The Registrants also selectively corroborate the fair value of their transactions by comparison of market-based price sources. Discounted cash flow analyses based upon estimated current borrowing rates are also used to determine fair value when quoted market prices are not available. The fair values of notes receivable, excluding capital leases, and notes payable are generally estimated using discounted cash flow techniques that incorporate market interest rates as well as assumptions about the remaining life of the loans and credit risk. Depending on the information available, other valuation techniques may be used that rely on internal assumptions and models. Valuation policies and procedures for the Registrants are determined by DTE Energy's Treasury Department which reports to DTE Energy's Vice President and Treasurer and DTE Energy's Controller's Department which reports to DTE Energy's Vice President and Controller.

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

	March 31, 2017								December 31, 2016
	Carrying		Fair Value						Carrying		Fair Value
	Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3
	(In millions)
Notes receivable, excluding capital leases	$	31	$	—	$	—	$	31	$	36	$	—	$	—	$	36
Dividends payable	$	148	$	148	$	—	$	—	$	148	$	148	$	—	$	—
Short-term borrowings	$	59	$	—	$	59	$	—	$	499	$	—	$	499	$	—
Notes payable — Other(a)	$	18	$	—	$	—	$	18	$	17	$	—	$	—	$	17
Long-term debt(b)	$	11,762	$	1,505	$	9,874	$	1,044	$	11,270	$	1,465	$	9,384	$	1,056

_______________________________________

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

(b) Includes debt due within one year, unamortized debt discounts, premiums, and issuance costs. Excludes Capital lease obligations.

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

	March 31, 2017								December 31, 2016
	Carrying		Fair Value						Carrying		Fair Value
	Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3
	(In millions)
Notes receivable, excluding capital leases	$	—	$	—	$	—	$	—	$	5	$	—	$	—	$	5
Short-term borrowings — affiliates	$	205	$	—	$	—	$	205	$	117	$	—	$	—	$	117
Short-term borrowings — other	$	59	$	—	$	59	$	—	$	62	$	—	$	62	$	—
Notes payable — Other(a)	$	6	$	—	$	—	$	6	$	6	$	—	$	—	$	6
Long-term debt(b)	$	5,879	$	—	$	6,016	$	262	$	5,878	$	—	$	6,026	$	264

_______________________________________

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

(b) Includes debt due within one year, unamortized debt discounts, and issuance costs. Excludes Capital 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:

	March 31, 2017		December 31, 2016
	(In millions)
Fermi 2	$	1,350	$	1,291
Fermi 1	3		3
Low-level radioactive waste	11		26
Total	$	1,364	$	1,320

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 March 31,
	2017			2016
	(In millions)
Realized gains	$	23		$	9
Realized losses	$	(8	)	$	(15	)
Proceeds from sale of securities	$	394		$	260

Realized gains and losses from the sale of securities for Fermi 2 are recorded to the Regulatory asset and Nuclear decommissioning liability. Realized gains and losses from the sale of securities for 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:

	March 31, 2017							December 31, 2016
	Fair Value		Unrealized Gains		Unrealized Losses			Fair Value		Unrealized Gains		Unrealized Losses
	(In millions)
Equity securities	$	890	$	250	$	(38	)	$	887	$	222	$	(46	)
Fixed income securities	471		12		(4		)	425		11		(5		)
Cash equivalents	3		—		—			8		—		—
	$	1,364	$	262	$	(42	)	$	1,320	$	233	$	(51	)

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

	March 31, 2017
	(In millions)
Due within one year	$	19
Due after one through five years	109
Due after five through ten years	91
Due after ten years	252
	$	471

Securities held in the Nuclear decommissioning trust funds are classified as available-for-sale. As DTE Electric does not have the ability to hold impaired investments for a period of time sufficient to allow for the anticipated recovery of market value, all unrealized losses are considered to be other-than-temporary impairments.

Unrealized losses incurred by the Fermi 2 trust are recognized as a Regulatory asset and Nuclear decommissioning liability. Unrealized losses on the low-level radioactive waste funds are recognized as a Nuclear decommissioning liability.

Other Securities

At March 31, 2017 and December 31, 2016, the Registrants' securities were comprised primarily of money market and equity securities. There were no unrealized losses on available-for-sale securities which were reclassified out of Other comprehensive income (loss) and realized into Net Income for DTE Energy or DTE Electric during the three months endedMarch 31, 2017 and 2016. Gains related to trading securities held at March 31, 2017 and 2016 were $8 million and $5 million, respectively, for the Registrants. The trading gains or losses related to the Rabbi Trust assets, included in Other investments at DTE Energy, are allocated from DTE Energy to DTE Electric.

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Financial and Other Derivative Instruments

3 Months Ended

Mar. 31, 2017

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 energy 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 2020. 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, landfill 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 March 31, 2017 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:

	March 31, 2017					December 31, 2016
	Derivative Assets		Derivative Liabilities			Derivative Assets		Derivative Liabilities
	(In millions)
Derivatives not designated as hedging instruments
Commodity Contracts
Natural Gas	$	304	$	(289	)	$	348	$	(461	)
Electricity	186		(197		)	193		(189		)
Other	1		(3		)	2		(3		)
Foreign currency exchange contracts	5		(2		)	6		(3		)
Total derivatives not designated as hedging instruments	$	496	$	(491	)	$	549	$	(656	)
Current	$	349	$	(312	)	$	447	$	(493	)
Noncurrent	147		(179		)	102		(163		)
Total derivatives	$	496	$	(491	)	$	549	$	(656	)

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

	March 31, 2017		December 31, 2016
	(In millions)
FTRs — Other current assets	$	1	$	2
Total derivatives not designated as hedging instrument	$	1	$	2

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 approximately $3 million and $2 million outstanding at March 31, 2017 and December 31, 2016, 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 $4 million and $2 million at March 31, 2017 and December 31, 2016, 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. Certain contracts that have netting arrangements have not been offset in DTE Energy's Consolidated Statements of Financial Position. The impact of netting these derivative instruments and cash collateral related to such contracts is not material. Only the gross amounts for these derivative instruments are included in the table below.

For DTE Energy, the total cash collateral posted, net of cash collateral received, was $48 million and $34 million as of March 31, 2017 and December 31, 2016, respectively. DTE Energy had $3 million of cash collateral related to unrealized positions to net against Derivative assets while Derivative liabilities are shown net of cash collateral of $13 million as of March 31, 2017. DTE Energy had $7 million of cash collateral related to unrealized positions to net against Derivative assets while Derivative liabilities are shown net of cash collateral of $28 million as of December 31, 2016. DTE Energy recorded cash collateral paid of $41 million and cash collateral received of $3 million not related to unrealized derivative positions as of March 31, 2017. DTE Energy recorded cash collateral paid of $18 million and cash collateral received of $5 million not related to unrealized derivative positions as of December 31, 2016. These amounts are included in Accounts receivable and Accounts payable and are recorded net by counterparty.

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

	March 31, 2017									December 31, 2016
	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	$	304		$	(206	)	$	98		$	348		$	(306	)	$	42
Electricity	186			(146		)	40			193			(157		)	36
Other	1			—			1			2			—			2
Foreign currency exchange contracts	5			(3		)	2			6			(5		)	1
Total derivative assets	$	496		$	(355	)	$	141		$	549		$	(468	)	$	81
Derivative liabilities
Commodity Contracts
Natural Gas	$	(289	)	$	202		$	(87	)	$	(461	)	$	321		$	(140	)
Electricity	(197		)	158			(39		)	(189		)	163			(26		)
Other	(3		)	3			—			(3		)	2			(1		)
Foreign currency exchange contracts	(2		)	2			—			(3		)	3			—
Total derivative liabilities	$	(491	)	$	365		$	(126	)	$	(656	)	$	489		$	(167	)

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:

	March 31, 2017												December 31, 2016
	Derivative Assets						Derivative Liabilities						Derivative Assets						Derivative Liabilities
	Current			Noncurrent			Current			Noncurrent			Current			Noncurrent			Current			Noncurrent
	(In millions)
Total fair value of derivatives	$	349		$	147		$	(312	)	$	(179	)	$	447		$	102		$	(493	)	$	(163	)
Counterparty netting	(278		)	(74		)	278			74			(396		)	(65		)	396			65
Collateral adjustment	(3		)	—			1			12			(4		)	(3		)	28			—
Total derivatives as reported	$	68		$	73		$	(33	)	$	(93	)	$	47		$	34		$	(69	)	$	(98	)

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

Derivatives not Designated as Hedging Instruments	Location of Gain (Loss) Recognized in Income on Derivatives	Gain (Loss) Recognized in Income on Derivatives for the Three Months Ended March 31,
		2017			2016
		(In millions)
Commodity Contracts
Natural Gas	Operating Revenues — Non-utility operations	$	57		$	(56	)
Natural Gas	Fuel, purchased power, and gas — non-utility	61			41
Electricity	Operating Revenues — Non-utility operations	(7		)	(24		)
Other	Operating Revenues — Non-utility operations	—			(2		)
Foreign currency exchange contracts	Operating Revenues — Non-utility operations	—			(5		)
Total		$	111		$	(46	)

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 March 31, 2017:

Commodity	Number of Units
Natural Gas (MMBtu)	1,781,816,780
Electricity (MWh)	35,032,431
Oil (Gallons)	12,936,000
Foreign Currency Exchange (Canadian dollars)	73,633,072

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 March 31, 2017, 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 approximately $437 million.

As of March 31, 2017, DTE Energy had approximately $397 million of derivatives in net liability positions, for which hard triggers exist. There is no collateral that has been posted against such liabilities, including cash and letters of credit. Associated derivative net asset positions for which contractual offset exists were approximately $342 million. The net remaining amount of approximately $55 million is derived from the $437 million noted above.

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Long-Term Debt

3 Months Ended

Mar. 31, 2017

Debt Disclosure [Abstract]

Long-Term Debt

LONG-TERM DEBT

Debt Issuances

In 2017, the following debt was issued:

Company	Month	Type	Interest Rate	Maturity	Amount
					(In millions)
DTE Energy	March	Senior Notes(a)	3.80%	2027	$	500
					$	500

_______________________________________

(a) Proceeds were used for repayment of short-term borrowings and general corporate purposes.

Debt Redemptions

In 2017, the following debt was redeemed:

Company	Month	Type	Interest Rate	Maturity	Amount
					(In millions)
DTE Energy	Various	Other Long-Term Debt	Various	2017	$	5
					$	5

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Short-Term Credit Arrangements and Borrowings

3 Months Ended

Mar. 31, 2017

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 March 31, 2017, the total funded debt to total capitalization ratios for DTE Energy, DTE Electric, and DTE Gas were 0.53 to 1, 0.50 to 1, and 0.45 to 1, respectively, and were in compliance with this financial covenant.

The availability under the facilities in place at March 31, 2017 is shown in the following table:

	DTE Energy		DTE Electric		DTE Gas		Total
	(In millions)
Unsecured letter of credit facility, expiring in February 2019(a)	$	150	$	—	$	—	$	150
Unsecured letter of credit facility, expiring in September 2017	70		—		—		70
Unsecured revolving credit facility, expiring April 2021	1,200		400		300		1,900
	1,420		400		300		2,120
Amounts outstanding at March 31, 2017
Commercial paper issuances	—		59		—		59
Letters of credit	139		—		—		139
	139		59		—		198
Net availability at March 31, 2017	$	1,281	$	341	$	300	$	1,922

_______________________________________

(a) In February 2017, DTE Energy amended its $100 million letter of credit facility. The facility's maturity date was amended from February 2017 to February 2019. As part of this amendment, DTE Energy increased its $100 million letter of credit facility to $150 million.

In April 2017, DTE Energy, DTE Electric, and DTE Gas exercised the extension features in their revolving credit agreements to add one year to the existing maturities. Each of these revolvers' expirations were extended from April 2021 to April 2022.

DTE Energy has other outstanding letters of credit which are not included in the above described facilities totaling approximately $17 million which are used for various corporate purposes.

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 March 31, 2017, a $35 million letter of credit was in place, raising the capacity under this facility to $135 million. The $35 million letter of credit is included in the table above. The amount outstanding under this agreement was $16 million and $50 million at March 31, 2017 and December 31, 2016, respectively, and was fully offset by the posted collateral.

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2017

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

COMMITMENTS AND CONTINGENCIES

Environmental

DTE Electric

Air — DTE Electric is subject to the EPA ozone and fine particulate transport and acid rain regulations that limit power plant emissions of SO₂ and NOx. The EPA and the State of Michigan have also issued emission reduction regulations relating to ozone, fine particulate, regional haze, mercury, and other air pollution. These rules have led to controls on fossil-fueled power plants to reduce NOx, SO₂, mercury, and other emissions. Additional rulemakings may occur over the next few years which could require additional controls for SO₂, NOx, and other hazardous air pollutants.

The Cross State Air Pollution Rule (CSAPR), required further reductions of SO₂ and NOx emissions beginning in January 2015. On September 7, 2016, the EPA finalized an update to the CSAPR ozone season program by issuing the CSAPR Update Rule. Beginning in May 2017, this rule is expected to reduce summertime (May - September) NOx emissions from power plants in 22 states in the eastern half of the U.S., including DTE Electric facilities. The CSAPR Update Rule is intended to reduce air quality impacts of the interstate transport of air pollution on downwind areas' ability to meet the 2008 ozone National Ambient Air Quality Standards implementing power sector emission budgets and NOx allowance trading programs. DTE Electric expects to meet its obligations under CSAPR. DTE Electric does not expect this rule to have a material effect on its compliance program.

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. The EPA will designate areas as either attainment or non-attainment with ozone standards by October 2017. DTE Electric cannot predict the financial impact of the revised ozone standards at this time.

In July 2009, DTE Energy 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 caused to be 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 caused to be 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 granted again 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 until the appeal is resolved by the Court of Appeals for the Sixth Circuit. Oral arguments for the appeal occurred in December 2015. On January 10, 2017, a divided panel of the Court reversed the decision of the U.S. District Court. On February 24, 2017, DTE Energy and DTE Electric filed a petition with the Sixth Circuit Court for a rehearing and a rehearing en banc. The Court requested responses to the petition from the EPA and the Sierra Club, which were filed on April 3, 2017.

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 cannot predict the financial impact or outcome of this matter, or the timing of its resolution.

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, the EPA finalized performance standards for emissions of carbon dioxide from new and existing 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. In February 2016, the U.S. Supreme Court granted petitioners' requests for a stay of the carbon rules for existing EGUs (also known as the EPA Clean Power Plan) pending final review by the courts. The Clean Power Plan has no legal effect while the stay is in place. On March 28, 2017, a presidential executive order was issued on "Promoting Energy Independence and Economic Growth." The order instructs the EPA to review, and if appropriate, suspend, revise or rescind the Clean Power Plan rule. Additionally, federal agencies have been directed to conduct a review of all existing regulations that potentially burden the development and use of domestically produced energy resources. Following the issuance of this order, the federal government requested the U.S. Court of Appeals for the D.C. Circuit to hold all legal challenges in abeyance until the review of these regulations is completed. It is not possible to determine the potential impact of this order on existing sources at this time.

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 2016. DTE Electric does not anticipate additional capital expenditures through 2023.

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 2015. The final rule requires studies to be completed by April 2018 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 each 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 March 31, 2017 and December 31, 2016, DTE Electric had $8 million 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 CCR, commonly known as coal ash, became effective in October 2015. 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. At certain facilities, the rule requires the installation of monitoring wells, compliance with groundwater standards, and the closure of basins at the end of the useful life of the associated power plant or as a basin becomes inactive. At other facilities, the rule requires ash laden waters be moved from earthen basins to steel and concrete tanks.

In November 2015, the EPA finalized the ELG Rule for the steam electric power generating industry which may require additional controls to be installed between 2018 and 2023. Compliance schedules for individual facilities and individual waste streams are determined through issuance of new wastewater permits by the State of Michigan. The State of Michigan has issued a National Pollutant Discharge Elimination System permit for the Belle River Power Plant establishing a compliance deadline of December 31, 2021. No new permits have been issued for other facilities, consequently no compliance timelines have been established. Under the current rule, certain ELG requirements would be required to be performed in conjunction with the CCR. Over the next six years, to comply with the ELG requirements of the November 2015 rules and for CCR requirements, costs associated with the building of new facilities or installation of controls are estimated to be approximately $309 million.

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 wastewater, among others. The administrative stay will become effective when published in the Federal Register. The ELG compliance requirements, deadlines, and compliance costs will not be known until the EPA completes its reconsideration of the ELG Rule.

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 six of the MGP sites is complete, and the sites are closed. DTE Gas has also completed partial closure of four additional sites. Cleanup activities associated with the remaining sites will continue over the next several years. The MPSC has established a cost deferral and rate recovery mechanism for investigation and remediation costs incurred at former MGP sites. In addition to the MGP sites, DTE Gas is also in the process of cleaning up other contaminated sites, including gate stations, gas pipeline releases, and underground storage tank locations. As of March 31, 2017 and December 31, 2016, DTE Gas had $41 million and $43 million accrued for remediation, respectively.  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.

The District Attorney's office of Yolo County, California has been investigating the ash management and disposition practices of Woodland Biomass Power, Ltd., and DTE Woodland, LLC, wholly-owned subsidiaries of DTE Energy (the Woodland Companies), a renewable wood-fired power generation facility. The District Attorney alleged that some of the ash generated at the Woodland Companies' generating facility should have been characterized and handled as hazardous waste under California regulation. DTE Energy is currently working through a final settlement, which includes reimbursement of the District Attorney's investigation costs. As of March 31, 2017, DTE Energy had approximately $4 million accrued for this matter. DTE Energy does not expect changes in estimated remediation and settlement costs to be materially different than the amounts accrued at March 31, 2017.

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 three 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 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 plans (SIPs) for Phase 2 areas describing the control strategy and timeline for demonstrating compliance with the new SO₂ standard are due to the EPA by mid-2018. 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 as it currently is under development.

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 March 31, 2017 is approximately $620 million. Payment under these guarantees is considered remote.

REF Guarantees

DTE Energy has provided certain guarantees and indemnities in conjunction with the sales of interests in or lease of its REF facilities. The guarantees cover potential commercial, environmental, and tax-related obligations that will survive until 90 days after expiration of all applicable statutes of limitations. DTE Energy estimates that its maximum potential liability under these guarantees at March 31, 2017 is approximately $308 million. Payment under these guarantees is considered remote.

NEXUS Guarantees

NEXUS entered into certain 15-year capacity lease 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 $53 million and $8 million, respectively; each representing 50% of all payment obligations due and payable by NEXUS. Should NEXUS fail to perform under the terms of those agreements, DTE Energy is required to perform on its behalf. 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 lease agreements. Subsequent to the NEXUS in-service date, the amount of each guarantee decreases annually as payments are made by NEXUS to each of the aforementioned counterparties. 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 $55 million at March 31, 2017. Payment under these guarantees is 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 March 31, 2017, DTE Energy had approximately $56 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.

Labor Contracts

There are several bargaining units for DTE Energy's approximately 4,800 represented employees, including DTE Electric's approximately 2,600 represented employees. The majority of the represented employees are under contracts that expire in 2017 and 2020.

Purchase Commitments

DTE Energy and DTE Electric expect that 2017 annual capital expenditures and contributions to equity method investees will be approximately $3.0 billion and $1.5 billion, respectively. The Registrants have made certain commitments in connection with the estimated 2017 annual capital expenditures and contributions to equity method investees.

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

3 Months Ended

Mar. 31, 2017

Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [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
	2017			2016			2017			2016
Three Months Ended March 31,	(In millions)
Service cost	$	24		$	23		$	7		$	6
Interest cost	54			54			18			20
Expected return on plan assets	(78		)	(77		)	(33		)	(32		)
Amortization of:
Net actuarial loss	43			40			3			8
Prior service credit	—			—			(3		)	(30		)
Net periodic benefit cost (credit)	$	43		$	40		$	(8	)	$	(28	)

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

	Pension Benefits						Other Postretirement Benefits
	2017			2016			2017			2016
Three Months Ended March 31,	(In millions)
Service cost	$	18		$	18		$	5		$	5
Interest cost	41			41			14			15
Expected return on plan assets	(55		)	(55		)	(23		)	(23		)
Amortization of:
Net actuarial loss	31			29			2			6
Prior service credit	—			—			(2		)	(22		)
Net periodic benefit cost (credit)	$	35		$	33		$	(4	)	$	(19	)

Pension and Other Postretirement Contributions

During the first three months of 2017, DTE Energy made cash contributions of $126 million, including contributions from DTE Electric of $125 million, to its pension plans. At the discretion of management and depending upon financial market conditions, DTE Energy may make additional contributions up to $180 million, including additional contributions from DTE Electric of $145 million, to its pension plans in 2017.

DTE Energy does not anticipate making any contributions to the other postretirement benefit plans in 2017.

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Segment and Related Information

3 Months Ended

Mar. 31, 2017

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 consists of natural gas pipeline, gathering, and storage businesses.

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 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 March 31,
	2017		2016
	(In millions)
Electric	$	12	$	9
Gas	3		—
Gas Storage and Pipelines	7		2
Power and Industrial Projects	168		148
Energy Trading	11		10
Corporate and Other	1		—
	$	202	$	169

Financial data of DTE Energy's business segments follows:

	Three Months Ended March 31,
	2017			2016
	(In millions)
Operating Revenues — Utility operations
Electric	$	1,175		$	1,153
Gas	557			520
Operating Revenues — Non-utility operations
Gas Storage and Pipelines	105			67
Power and Industrial Projects	548			446
Energy Trading	1,052			549
Corporate and Other	1			—
Reconciliation and Eliminations	(202		)	(169		)
Total	$	3,236		$	2,566

Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	106	$	127
Gas	107		87
Gas Storage and Pipelines	45		30
Power and Industrial Projects	30		17
Energy Trading	96		(7		)
Corporate and Other	16		(7		)
Net Income Attributable to DTE Energy Company	$	400	$	247

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Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2017

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 2016 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, 2017.

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 accounted for under the equity method.

DTE Energy owns a 55% 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. See Note 4 to the Consolidated Financial Statements, "Acquisition," for more information.

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 March 31, 2017, 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 March 31, 2017, 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. For non-consolidated VIEs, the maximum risk exposure is generally limited to its investment, notes receivable, and future funding commitments.

Changes in Accumulated Other Comprehensive Income (Loss)

Changes in Accumulated Other Comprehensive Income (Loss)

For the three months endedMarch 31, 2017 and 2016, reclassifications out of Accumulated other comprehensive income (loss) for the Registrants were not material. 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.

New Accounting Pronouncements

Recently Adopted Pronouncements

In July 2015, the FASB issued ASU No. 2015-11, Inventory (Topic 330), Simplifying the Measurement of Inventory. The ASU replaces the current lower of cost or market test with a lower of cost or net realizable value test when cost is determined on a first-in, first-out or average cost basis. The standard is effective for public entities for annual reporting periods beginning after December 15, 2016, and interim periods therein. It is applied prospectively. The Registrants adopted this ASU at January 1, 2017. The adoption of the ASU did not have a significant impact on the Registrants' Consolidated Financial Statements.

Recently Issued Pronouncements

In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606), as amended. The objectives of this ASU are to improve upon revenue recognition requirements by providing a single comprehensive model to determine the measurement of revenue and timing of recognition. The core principle is that an entity will recognize revenue to depict the transfer of goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services. This ASU also requires expanded qualitative and quantitative disclosures regarding the nature, amount, timing, and uncertainty of revenues and cash flows arising from contracts with customers. The standard is effective for the first interim period within annual reporting periods beginning after December 15, 2017. The standard is to be applied retrospectively, and early adoption is permitted in the preceding year. The Registrants do not plan to early adopt the standard. The Registrants are currently assessing the impact of the ASU, as amended, on their Consolidated Financial Statements as well as the transition method the Registrants will use to adopt the guidance. The Registrants have completed the preliminary evaluations of the impact of this guidance and do not expect the ASU to significantly affect results of operations for tariff-based sales, which represent a majority of the Registrants' revenues, and the remaining non-tariff revenues. The Registrants will continue to evaluate the impact of the ASU on existing revenue recognition policies and procedures and monitor the unresolved industry-related issues. Specifically, the Registrants are considering whether the new guidance will affect accounting for certain contracts where collectibility is in question, contributions in aid of construction, and other utility industry-related areas. The Registrants are evaluating information that would be useful for users of the Consolidated Financial Statements, including information already provided in disclosures outside of the Combined Notes to the Consolidated Financial Statements.

In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842), a replacement of Leases (Topic 840). This guidance requires a lessee to account for leases as finance or operating leases. Both 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. For lessors, the standard modifies the classification criteria and the accounting for sales-type and direct financing leases. Entities will classify leases to determine how to recognize lease-related revenue and expense. This ASU is effective for public entities for fiscal years, and interim periods within those years, beginning after December 15, 2018, and early adoption is permitted. A modified retrospective approach is required for leases existing or entered into after the beginning of the earliest comparative period in the Consolidated Financial Statements. The Registrants expect an increase in assets and liabilities, however, they are currently assessing the impact of this ASU on their Consolidated Financial Statements.

In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments — Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments. The amendments in this update replace the incurred loss impairment methodology in current GAAP with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates.  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 are currently assessing the impact of this standard on their Consolidated Financial Statements.

In March 2017, the FASB issued ASU No. 2017-07, Compensation — Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. The amendments in this update require that an employer report the service cost component in the same line item or items as other compensation costs arising from services rendered by the pertinent employees during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside income from operations. The amendments in this update also allow only the service cost component to be eligible for capitalization when applicable. The standard will be applied retrospectively for the presentation of the service cost component and the other components of net periodic pension cost and net periodic postretirement benefit cost in the income statement and prospectively for the capitalization of the service cost component of net periodic pension cost and net periodic postretirement benefit in assets. The ASU is effective for the Registrants beginning after December 15, 2017, including interim periods therein. Early adoption is permitted. The components of net periodic benefit costs (credits) for pension benefits and other postretirement benefits are disclosed in Note 12 to the Consolidated Financial Statements, "Retirement Benefits and Trusteed Assets." The ASU will not have a significant impact on the Registrants' Consolidated Financial Statements.

Fair Value Measurement

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable inputs. The Registrants make certain assumptions they believe that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. Credit risk of the Registrants and their counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at March 31, 2017 and December 31, 2016. 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

The nuclear decommissioning trusts and other investments hold debt and equity securities directly and indirectly through institutional mutual funds and commingled funds. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. Non-exchange-traded fixed income securities are valued based upon quotations available from brokers or pricing services. The institutional mutual funds hold exchange-traded equity or debt securities (exchange and non-exchange traded) and are valued based on publicly available NAVs. 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 to be 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. Additionally, the Registrants selectively corroborate the fair value of securities by comparison of market-based price sources. Investment policies and procedures are determined by DTE Energy's Trust Investments Department which reports to DTE Energy's Vice President and Treasurer.

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.

Fair Value of Financial Instruments

The fair value of financial instruments included in the table below is determined by using quoted market prices when available. When quoted prices are not available, pricing services may be used to determine the fair value with reference to observable interest rate indexes. The Registrants have obtained an understanding of how the fair values are derived. The Registrants also selectively corroborate the fair value of their transactions by comparison of market-based price sources. Discounted cash flow analyses based upon estimated current borrowing rates are also used to determine fair value when quoted market prices are not available. The fair values of notes receivable, excluding capital leases, and notes payable are generally estimated using discounted cash flow techniques that incorporate market interest rates as well as assumptions about the remaining life of the loans and credit risk. Depending on the information available, other valuation techniques may be used that rely on internal assumptions and models. Valuation policies and procedures for the Registrants are determined by DTE Energy's Treasury Department which reports to DTE Energy's Vice President and Treasurer and DTE Energy's Controller's Department which reports to DTE Energy's Vice President and Controller.

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 energy 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 2020. 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, landfill 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 March 31, 2017 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 approximately $3 million and $2 million outstanding at March 31, 2017 and December 31, 2016, 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 $4 million and $2 million at March 31, 2017 and December 31, 2016, 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. Certain contracts that have netting arrangements have not been offset in DTE Energy's Consolidated Statements of Financial Position. The impact of netting these derivative instruments and cash collateral related to such contracts is not material. Only the gross amounts for these derivative instruments are included in the table below.

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)

3 Months Ended

Mar. 31, 2017

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 March 31, 2017 and December 31, 2016. All assets and liabilities of a consolidated VIE are presented where it has been determined that aconsolidated 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.

	March 31, 2017						December 31, 2016
	SGG(a)		Other		Total		SGG(a)		Other		Total
	(In millions)
ASSETS
Cash and cash equivalents	$	52	$	11	$	63	$	36	$	27	$	63
Restricted cash	—		7		7		—		7		7
Accounts receivable	10		19		29		8		34		42
Inventories	3		59		62		3		112		115
Property, plant, and equipment, net	397		75		472		398		76		474
Goodwill	22		—		22		17		—		17
Intangible assets	583		—		583		586		—		586
Other current and long-term assets	—		1		1		1		1		2
	$	1,067	$	172	$	1,239	$	1,049	$	257	$	1,306
LIABILITIES
Accounts payable and accrued current liabilities	$	19	$	21	$	40	$	19	$	32	$	51
Current portion long-term debt, including capital leases	—		5		5		—		5		5
Mortgage bonds, notes, and other	—		4		4		—		5		5
Other current and long-term liabilities	2		14		16		2		15		17
	$	21	$	44	$	65	$	21	$	57	$	78

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(a)Amounts shown are 100% of SGG's assets and liabilities, of which DTE Energy owns 55%.

Summary of Amounts for Non-Consolidated Variable Interest Entities

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

	March 31, 2017		December 31, 2016
	(In millions)
Investments in equity method investees	$	186	$	187
Notes receivable	$	15	$	15
Future funding commitments	$	6	$	7

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Significant Accounting Policies (Tables)

3 Months Ended

Mar. 31, 2017

Accounting Policies [Abstract]

Schedule of Other Nonoperating Income, by Component

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

	Three Months Ended March 31,
	2017		2016
	(In millions)
Equity earnings of equity method investees	$	26	$	15
Income from REF investees	18		19
Gains from trading securities	8		5
Allowance for equity funds used during construction	7		5
Contract services	4		6
Other	1		2
	$	64	$	52

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

	Three Months Ended March 31,
	2017		2016
	(In millions)
Gains from trading securities allocated from DTE Energy	$	8	$	5
Allowance for equity funds used during construction	6		4
Contract services	4		6
Other	1		1
	$	19	$	16

Schedule of Effective Tax Rate and Unrecognized Tax Benefits

The effective tax rate and unrecognized tax benefits of the Registrants are as follows:

	Effective Tax Rate				Unrecognized Tax Benefits
	Three Months Ended March 31,				March 31,
	2017		2016		2017
					(In millions)
DTE Energy	22	%	26	%	$	10
DTE Electric	35	%	36	%	$	13

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Acquisition (Tables)

3 Months Ended

Mar. 31, 2017

Business Combinations [Abstract]

Schedule of Preliminary Purchase Price Allocation

The components of the preliminary purchase price allocation were as follows:

	(In millions)
Assets
Cash	$	83
Accounts receivable	24
Inventory	6
Property, plant, and equipment, net	730
Goodwill	268
Customer relationship intangibles	770
Other current assets	1
	$	1,882
Liabilities
Accounts payable	$	19
Other current liabilities	14
Long-term debt	204
Other long-term liabilities	26
	$	263
Less noncontrolling interest	390
Total cash consideration	$	1,229

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Earnings Per Share (Tables)

3 Months Ended

Mar. 31, 2017

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 March 31,
	2017			2016
	(In millions, except per share amounts)
Basic Earnings per Share
Net income attributable to DTE Energy Company	$	400		$	247
Less allocation of earnings to net restricted stock awards	(1		)	—
Net income available to common shareholders — basic	$	399		$	247
Average number of common shares outstanding	179			179
Basic Earnings per Common Share	$	2.23		$	1.38
Diluted Earnings per Share
Net income attributable to DTE Energy Company	$	400		$	247
Less allocation of earnings to net restricted stock awards	(1		)	—
Net income available to common shareholders — diluted	$	399		$	247
Average number of common shares outstanding	179			180
Diluted Earnings per Common Share(a)	$	2.23		$	1.37

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(a) The October 2016 Equity Units are potentially dilutive securities but were excluded from the calculation of diluted EPS for the three months ended March 31, 2017, as the dilutive stock price threshold was not met.

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Fair Value (Tables)

3 Months Ended

Mar. 31, 2017

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:

	March 31, 2017															December 31, 2016
	Level 1			Level 2			Level 3			Netting(a)			Net Balance			Level 1			Level 2			Level 3			Netting(a)			Net Balance
	(In millions)
Assets:
Cash equivalents(b)	$	14		$	3		$	—		$	—		$	17		$	14		$	3		$	—		$	—		$	17
Nuclear decommissioning trusts(c)
Equity securities	890			—			—			—			890			887			—			—			—			887
Fixed income securities	11			460			—			—			471			11			414			—			—			425
Cash equivalents	3			—			—			—			3			8			—			—			—			8
Other investments(d)
Equity securities	110			—			—			—			110			104			—			—			—			104
Fixed income securities	63			—			—			—			63			61			—			—			—			61
Derivative assets
Commodity Contracts
Natural Gas	82			151			71			(206		)	98			216			79			53			(306		)	42
Electricity	—			152			34			(146		)	40			—			154			39			(157		)	36
Other	—			—			1			—			1			—			—			2			—			2
Foreign currency exchange contracts	—			5			—			(3		)	2			—			6			—			(5		)	1
Total derivative assets	82			308			106			(355		)	141			216			239			94			(468		)	81
Total	$	1,173		$	771		$	106		$	(355	)	$	1,695		$	1,301		$	656		$	94		$	(468	)	$	1,583
Liabilities:
Derivative liabilities
Commodity Contracts
Natural Gas	$	(82	)	$	(121	)	$	(86	)	$	202		$	(87	)	$	(226	)	$	(86	)	$	(149	)	$	321		$	(140	)
Electricity	—			(157		)	(40		)	158			(39		)	—			(159		)	(30		)	163			(26		)
Other	—			—			(3		)	3			—			—			—			(3		)	2			(1		)
Foreign currency exchange contracts	—			(2		)	—			2			—			—			(3		)	—			3			—
Total derivative liabilities	(82		)	(280		)	(129		)	365			(126		)	(226		)	(248		)	(182		)	489			(167		)
Total	$	(82	)	$	(280	)	$	(129	)	$	365		$	(126	)	$	(226	)	$	(248	)	$	(182	)	$	489		$	(167	)
Net Assets (Liabilities) at end of period	$	1,091		$	491		$	(23	)	$	10		$	1,569		$	1,075		$	408		$	(88	)	$	21		$	1,416
Assets:
Current	$	78		$	228		$	60		$	(281	)	$	85		$	205		$	199		$	60		$	(400	)	$	64
Noncurrent	1,095			543			46			(74		)	1,610			1,096			457			34			(68		)	1,519
Total Assets	$	1,173		$	771		$	106		$	(355	)	$	1,695		$	1,301		$	656		$	94		$	(468	)	$	1,583
Liabilities:
Current	$	(63	)	$	(213	)	$	(36	)	$	279		$	(33	)	$	(203	)	$	(211	)	$	(79	)	$	424		$	(69	)
Noncurrent	(19		)	(67		)	(93		)	86			(93		)	(23		)	(37		)	(103		)	65			(98		)
Total Liabilities	$	(82	)	$	(280	)	$	(129	)	$	365		$	(126	)	$	(226	)	$	(248	)	$	(182	)	$	489		$	(167	)
Net Assets (Liabilities) at end of period	$	1,091		$	491		$	(23	)	$	10		$	1,569		$	1,075		$	408		$	(88	)	$	21		$	1,416

_______________________________________

(a) 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.

(b) At March 31, 2017 and December 31, 2016, available-for-sale securities of $17 million, included $7 million and $10 million of cash equivalents included in Restricted cash and Other investments on DTE Energy's Consolidated Statements of Financial Position, respectively.

(c) At March 31, 2017, the Nuclear Decommissioning Master Trust had outstanding commitments to invest in private equity investments of approximately $15 million. These commitments will be funded by existing nuclear decommissioning trust funds.

(d) 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:

	March 31, 2017								December 31, 2016
	Level 1		Level 2		Level 3		Net Balance		Level 1		Level 2		Level 3		Net Balance
	(In millions)
Assets:
Cash equivalents(a)	$	8	$	3	$	—	$	11	$	8	$	3	$	—	$	11
Nuclear decommissioning trusts(b)
Equity securities	890		—		—		890		887		—		—		887
Fixed income securities	11		460		—		471		11		414		—		425
Cash equivalents	3		—		—		3		8		—		—		8
Other investments
Equity securities	9		—		—		9		9		—		—		9
Derivative assets — FTRs	—		—		1		1		—		—		2		2
Total	$	921	$	463	$	1	$	1,385	$	923	$	417	$	2	$	1,342
Assets:
Current	$	8	$	3	$	1	$	12	$	8	$	3	$	2	$	13
Noncurrent	913		460		—		1,373		915		414		—		1,329
Total Assets	$	921	$	463	$	1	$	1,385	$	923	$	417	$	2	$	1,342

_______________________________________

(a) At March 31, 2017 and December 31, 2016, available-for-sale securities of $11 million consisted of cash equivalents included in Other investments on DTE Electric's Consolidated Statements of Financial Position, respectively.

(b) At March 31, 2017, the Nuclear Decommissioning Master Trust had outstanding commitments to invest in private equity investments of approximately $15 million. These commitments will be funded by existing nuclear decommissioning trust funds.

Fair value 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 March 31, 2017												Three Months Ended March 31, 2016
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of January 1	$	(96	)	$	9		$	(1	)	$	(88	)	$	(5	)	$	6		$	(5	)	$	(4	)
Transfers into Level 3 from Level 2	—			—			—			—			—			—			—			—
Transfers from Level 3 into Level 2	—			—			—			—			(1		)	—			—			(1		)
Total gains (losses)
Included in earnings	52			(9		)	1			44			(20		)	(58		)	(1		)	(79		)
Recorded in Regulatory liabilities	—			—			2			2			—			—			(2		)	(2		)
Purchases, issuances, and settlements
Settlements	29			(6		)	(4		)	19			(8		)	36			1			29
Net Liabilities as of March 31	$	(15	)	$	(6	)	$	(2	)	$	(23	)	$	(34	)	$	(16	)	$	(7	)	$	(57	)
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 March 31, 2017 and 2016 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	$	35		$	(3	)	$	—		$	32		$	(72	)	$	(3	)	$	(1	)	$	(76	)

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 March 31,
	2017			2016
	(In millions)
Net Assets as of January 1	$	2		$	3
Change in fair value recorded in Regulatory liabilities	2			(2		)
Purchases, issuances, and settlements
Settlements	(3		)	—
Net Assets as of March 31	$	1		$	1
The amount of total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets held at March 31, 2017 and 2016 and reflected in DTE Electric's Consolidated Statements of Financial Position	$	—		$	—

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:

	March 31, 2017
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	71	$	(86	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(0.87	)	—	$	6.25	/MMBtu	$	(0.14	)/MMBtu
Electricity	$	34	$	(40	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(6	)	—	$	8	/MWh	$	1	/MWh

	December 31, 2016
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	53	$	(149	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.00	)	—	$	7.90	/MMBtu	$	(0.05	)/MMBtu
Electricity	$	39	$	(30	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(6	)	—	$	12	/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:

	March 31, 2017								December 31, 2016
	Carrying		Fair Value						Carrying		Fair Value
	Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3
	(In millions)
Notes receivable, excluding capital leases	$	31	$	—	$	—	$	31	$	36	$	—	$	—	$	36
Dividends payable	$	148	$	148	$	—	$	—	$	148	$	148	$	—	$	—
Short-term borrowings	$	59	$	—	$	59	$	—	$	499	$	—	$	499	$	—
Notes payable — Other(a)	$	18	$	—	$	—	$	18	$	17	$	—	$	—	$	17
Long-term debt(b)	$	11,762	$	1,505	$	9,874	$	1,044	$	11,270	$	1,465	$	9,384	$	1,056

_______________________________________

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

(b) Includes debt due within one year, unamortized debt discounts, premiums, and issuance costs. Excludes Capital lease obligations.

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

	March 31, 2017								December 31, 2016
	Carrying		Fair Value						Carrying		Fair Value
	Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3
	(In millions)
Notes receivable, excluding capital leases	$	—	$	—	$	—	$	—	$	5	$	—	$	—	$	5
Short-term borrowings — affiliates	$	205	$	—	$	—	$	205	$	117	$	—	$	—	$	117
Short-term borrowings — other	$	59	$	—	$	59	$	—	$	62	$	—	$	62	$	—
Notes payable — Other(a)	$	6	$	—	$	—	$	6	$	6	$	—	$	—	$	6
Long-term debt(b)	$	5,879	$	—	$	6,016	$	262	$	5,878	$	—	$	6,026	$	264

_______________________________________

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

(b) Includes debt due within one year, unamortized debt discounts, and issuance costs. Excludes Capital 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:

	March 31, 2017		December 31, 2016
	(In millions)
Fermi 2	$	1,350	$	1,291
Fermi 1	3		3
Low-level radioactive waste	11		26
Total	$	1,364	$	1,320

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 March 31,
	2017			2016
	(In millions)
Realized gains	$	23		$	9
Realized losses	$	(8	)	$	(15	)
Proceeds from sale of securities	$	394		$	260

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:

	March 31, 2017							December 31, 2016
	Fair Value		Unrealized Gains		Unrealized Losses			Fair Value		Unrealized Gains		Unrealized Losses
	(In millions)
Equity securities	$	890	$	250	$	(38	)	$	887	$	222	$	(46	)
Fixed income securities	471		12		(4		)	425		11		(5		)
Cash equivalents	3		—		—			8		—		—
	$	1,364	$	262	$	(42	)	$	1,320	$	233	$	(51	)

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:

	March 31, 2017
	(In millions)
Due within one year	$	19
Due after one through five years	109
Due after five through ten years	91
Due after ten years	252
	$	471

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Financial and Other Derivative Instruments (Tables)

3 Months Ended

Mar. 31, 2017

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:

	March 31, 2017					December 31, 2016
	Derivative Assets		Derivative Liabilities			Derivative Assets		Derivative Liabilities
	(In millions)
Derivatives not designated as hedging instruments
Commodity Contracts
Natural Gas	$	304	$	(289	)	$	348	$	(461	)
Electricity	186		(197		)	193		(189		)
Other	1		(3		)	2		(3		)
Foreign currency exchange contracts	5		(2		)	6		(3		)
Total derivatives not designated as hedging instruments	$	496	$	(491	)	$	549	$	(656	)
Current	$	349	$	(312	)	$	447	$	(493	)
Noncurrent	147		(179		)	102		(163		)
Total derivatives	$	496	$	(491	)	$	549	$	(656	)

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

	March 31, 2017		December 31, 2016
	(In millions)
FTRs — Other current assets	$	1	$	2
Total derivatives not designated as hedging instrument	$	1	$	2

Netting Offsets of Derivative Assets and Liabilities

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

	March 31, 2017									December 31, 2016
	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	$	304		$	(206	)	$	98		$	348		$	(306	)	$	42
Electricity	186			(146		)	40			193			(157		)	36
Other	1			—			1			2			—			2
Foreign currency exchange contracts	5			(3		)	2			6			(5		)	1
Total derivative assets	$	496		$	(355	)	$	141		$	549		$	(468	)	$	81
Derivative liabilities
Commodity Contracts
Natural Gas	$	(289	)	$	202		$	(87	)	$	(461	)	$	321		$	(140	)
Electricity	(197		)	158			(39		)	(189		)	163			(26		)
Other	(3		)	3			—			(3		)	2			(1		)
Foreign currency exchange contracts	(2		)	2			—			(3		)	3			—
Total derivative liabilities	$	(491	)	$	365		$	(126	)	$	(656	)	$	489		$	(167	)

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:

	March 31, 2017												December 31, 2016
	Derivative Assets						Derivative Liabilities						Derivative Assets						Derivative Liabilities
	Current			Noncurrent			Current			Noncurrent			Current			Noncurrent			Current			Noncurrent
	(In millions)
Total fair value of derivatives	$	349		$	147		$	(312	)	$	(179	)	$	447		$	102		$	(493	)	$	(163	)
Counterparty netting	(278		)	(74		)	278			74			(396		)	(65		)	396			65
Collateral adjustment	(3		)	—			1			12			(4		)	(3		)	28			—
Total derivatives as reported	$	68		$	73		$	(33	)	$	(93	)	$	47		$	34		$	(69	)	$	(98	)

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:

Derivatives not Designated as Hedging Instruments	Location of Gain (Loss) Recognized in Income on Derivatives	Gain (Loss) Recognized in Income on Derivatives for the Three Months Ended March 31,
		2017			2016
		(In millions)
Commodity Contracts
Natural Gas	Operating Revenues — Non-utility operations	$	57		$	(56	)
Natural Gas	Fuel, purchased power, and gas — non-utility	61			41
Electricity	Operating Revenues — Non-utility operations	(7		)	(24		)
Other	Operating Revenues — Non-utility operations	—			(2		)
Foreign currency exchange contracts	Operating Revenues — Non-utility operations	—			(5		)
Total		$	111		$	(46	)

Volume of Commodity Contracts

The following represents the cumulative gross volume of DTE Energy's derivative contracts outstanding as of March 31, 2017:

Commodity	Number of Units
Natural Gas (MMBtu)	1,781,816,780
Electricity (MWh)	35,032,431
Oil (Gallons)	12,936,000
Foreign Currency Exchange (Canadian dollars)	73,633,072

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Long-Term Debt (Tables)

3 Months Ended

Mar. 31, 2017

Debt Disclosure [Abstract]

Schedule of Issued Debt

In 2017, the following debt was issued:

Company	Month	Type	Interest Rate	Maturity	Amount
					(In millions)
DTE Energy	March	Senior Notes(a)	3.80%	2027	$	500
					$	500

_______________________________________

(a) Proceeds were used for repayment of short-term borrowings and general corporate purposes.

Schedule of Debt Redemptions

In 2017, the following debt was redeemed:

Company	Month	Type	Interest Rate	Maturity	Amount
					(In millions)
DTE Energy	Various	Other Long-Term Debt	Various	2017	$	5
					$	5

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Short-Term Credit Arrangements and Borrowings (Tables)

3 Months Ended

Mar. 31, 2017

Short-term Debt [Abstract]

Schedule of Line of Credit Facilities

The availability under the facilities in place at March 31, 2017 is shown in the following table:

	DTE Energy		DTE Electric		DTE Gas		Total
	(In millions)
Unsecured letter of credit facility, expiring in February 2019(a)	$	150	$	—	$	—	$	150
Unsecured letter of credit facility, expiring in September 2017	70		—		—		70
Unsecured revolving credit facility, expiring April 2021	1,200		400		300		1,900
	1,420		400		300		2,120
Amounts outstanding at March 31, 2017
Commercial paper issuances	—		59		—		59
Letters of credit	139		—		—		139
	139		59		—		198
Net availability at March 31, 2017	$	1,281	$	341	$	300	$	1,922

_______________________________________

(a) In February 2017, DTE Energy amended its $100 million letter of credit facility. The facility's maturity date was amended from February 2017 to February 2019. As part of this amendment, DTE Energy increased its $100 million letter of credit facility to $150 million.

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Retirement Benefits and Trusteed Assets (Tables)

3 Months Ended

Mar. 31, 2017

Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [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
	2017			2016			2017			2016
Three Months Ended March 31,	(In millions)
Service cost	$	24		$	23		$	7		$	6
Interest cost	54			54			18			20
Expected return on plan assets	(78		)	(77		)	(33		)	(32		)
Amortization of:
Net actuarial loss	43			40			3			8
Prior service credit	—			—			(3		)	(30		)
Net periodic benefit cost (credit)	$	43		$	40		$	(8	)	$	(28	)

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

	Pension Benefits						Other Postretirement Benefits
	2017			2016			2017			2016
Three Months Ended March 31,	(In millions)
Service cost	$	18		$	18		$	5		$	5
Interest cost	41			41			14			15
Expected return on plan assets	(55		)	(55		)	(23		)	(23		)
Amortization of:
Net actuarial loss	31			29			2			6
Prior service credit	—			—			(2		)	(22		)
Net periodic benefit cost (credit)	$	35		$	33		$	(4	)	$	(19	)

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Segment and Related Information (Tables)

3 Months Ended

Mar. 31, 2017

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 March 31,
	2017		2016
	(In millions)
Electric	$	12	$	9
Gas	3		—
Gas Storage and Pipelines	7		2
Power and Industrial Projects	168		148
Energy Trading	11		10
Corporate and Other	1		—
	$	202	$	169

Financial data of DTE Energy's business segments follows:

	Three Months Ended March 31,
	2017			2016
	(In millions)
Operating Revenues — Utility operations
Electric	$	1,175		$	1,153
Gas	557			520
Operating Revenues — Non-utility operations
Gas Storage and Pipelines	105			67
Power and Industrial Projects	548			446
Energy Trading	1,052			549
Corporate and Other	1			—
Reconciliation and Eliminations	(202		)	(169		)
Total	$	3,236		$	2,566

Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	106	$	127
Gas	107		87
Gas Storage and Pipelines	45		30
Power and Industrial Projects	30		17
Energy Trading	96		(7		)
Corporate and Other	16		(7		)
Net Income Attributable to DTE Energy Company	$	400	$	247

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Organization and Basis of Presentation (Details Textuals) customer in Millions	Mar. 31, 2017 USD ($) customer	Oct. 01, 2016
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
West Virginia | Midstream Natural Gas Assets
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Percent of assets acquired	55.00%	55.00%

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Organization and Basis of Presentation (Consolidated Variable Interest Entities) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Dec. 31, 2016	Mar. 31, 2016	Dec. 31, 2015
ASSETS
Cash and cash equivalents	$ 82	$ 92	$ 35	$ 37
Restricted cash	20	21
Accounts receivable	1,408	1,522
Property, plant, and equipment, net	19,866	19,730
Goodwill	2,292	2,286
Intangible assets	837	842
Total Assets	32,149	32,041
LIABILITIES
Current portion long-term debt, including capital leases	13	14
Mortgage bonds, notes, and other	10,999	10,506
Variable interest entity, primary beneficiary, restricted
ASSETS
Cash and cash equivalents	63	63
Restricted cash	7	7
Accounts receivable	29	42
Inventories	62	115
Property, plant, and equipment, net	472	474
Goodwill	22	17
Intangible assets	583	586
Other current and long-term assets	1	2
Total Assets	1,239	1,306
LIABILITIES
Accounts payable and accrued current liabilities	40	51
Current portion long-term debt, including capital leases	5	5
Mortgage bonds, notes, and other	4	5
Other current and long-term liabilities	16	17
Total liabilities	65	78
Variable interest entity, primary beneficiary, SGG
ASSETS
Cash and cash equivalents	52	36
Restricted cash	0	0
Accounts receivable	10	8
Inventories	3	3
Property, plant, and equipment, net	397	398
Goodwill	22	17
Intangible assets	583	586
Other current and long-term assets	0	1
Total Assets	1,067	1,049
LIABILITIES
Accounts payable and accrued current liabilities	19	19
Current portion long-term debt, including capital leases	0	0
Mortgage bonds, notes, and other	0	0
Other current and long-term liabilities	2	2
Total liabilities	$ 21	21
VIE ownership and non-ownership percentage	100.00%
VIE ownership percentage	55.00%
Variable interest entity, primary beneficiary other, restricted
ASSETS
Cash and cash equivalents	$ 11	27
Restricted cash	7	7
Accounts receivable	19	34
Inventories	59	112
Property, plant, and equipment, net	75	76
Goodwill	0	0
Intangible assets	0	0
Other current and long-term assets	1	1
Total Assets	172	257
LIABILITIES
Accounts payable and accrued current liabilities	21	32
Current portion long-term debt, including capital leases	5	5
Mortgage bonds, notes, and other	4	5
Other current and long-term liabilities	14	15
Total liabilities	$ 44	$ 57

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Organization and Basis of Presentation (Non Consolidated Variable Interest Entities) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Variable Interest Entity [Line Items]
Investments in equity method investees	$ 868	$ 752
Notes receivable	71	73
Variable interest entity, non-consolidated
Variable Interest Entity [Line Items]
Investments in equity method investees	186	187
Notes receivable	15	15
Future funding commitments	$ 6	$ 7

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Significant Accounting Policies Significant Accounting Policies (Other Income) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Schedule of Other Nonoperating Income, by Component [Line Items]
Equity earnings of equity method investees	$ 26	$ 15
Income from REF investees	18	19
Gains from trading securities	8	5
Allowance for equity funds used during construction	7	5
Contract services	4	6
Other	1	2
Total other income	64	52
DTE Electric
Schedule of Other Nonoperating Income, by Component [Line Items]
Gains from trading securities	8	5
Allowance for equity funds used during construction	6	4
Contract services	4	6
Other	1	1
Total other income	$ 19	$ 16

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Significant Accounting Policies (Income Taxes) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Schedule of Income Taxes [Line Items]
Effective Tax Rate	22.00%	26.00%
Unrecognized Tax Benefits	$ 10
DTE Electric
Schedule of Income Taxes [Line Items]
Effective Tax Rate	35.00%	36.00%
Unrecognized Tax Benefits	$ 13

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Significant Accounting Policies (Details Textuals) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Significant Accounting Policies [Line Items]
Effective tax rate increase (decrease)	(4.00%)
ASU 2016-09 excess tax benefit amount	$ 13
Unrecognized tax benefits that would impact effective tax rate	7
Unrecognized compensation cost	$ 92
Recognition period (in years)	1 year 9 months 27 days
DTE Electric
Significant Accounting Policies [Line Items]
Unrecognized tax benefits that would impact effective tax rate	$ 8
DTE Electric | DTE Energy
Significant Accounting Policies [Line Items]
Income tax receivable	10		$ 9
Allocated costs	$ 8	$ 10

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Acquisition (Details) - USD ($) $ in Millions		3 Months Ended
	Oct. 01, 2016	Mar. 31, 2017	Dec. 31, 2016
Business Acquisition [Line Items]
Goodwill		$ 2,292	$ 2,286
Midstream Natural Gas Assets
Business Acquisition [Line Items]
Cash paid for gathering assets	$ 1,200
Assumed debt	204
Assumed debt, acquiree portion	$ 112
Noncontrolling interest percentage	45.00%
Assumed debt, noncontrolling interest portion	$ 92
Escrow deposit	130
Goodwill	268
Goodwill purchase accounting adjustments		$ 6
Customer relationship intangibles	$ 770
Useful life of acquired intangible assets	40 years
Pre-acquisition contingencies	$ 39
Direct transaction costs			15
Operating revenues associated with acquired entities			39
Net income (loss) associated with acquired entities			4
Midstream Natural Gas Assets | West Virginia
Business Acquisition [Line Items]
Percent of assets acquired	55.00%	55.00%
M3 Midstream | Midstream Natural Gas Assets | Pennsylvania and West Virginia
Business Acquisition [Line Items]
Percent of assets acquired	100.00%
M3 Midstream | Midstream Natural Gas Assets | West Virginia
Business Acquisition [Line Items]
Percent of assets acquired	40.00%
Vega Energy Partners | Midstream Natural Gas Assets | West Virginia
Business Acquisition [Line Items]
Percent of assets acquired	15.00%
Customer relationships | Midstream Natural Gas Assets
Business Acquisition [Line Items]
Useful life of acquired intangible assets	10 years
Transaction costs | Midstream Natural Gas Assets
Business Acquisition [Line Items]
Net income (loss) associated with acquired entities			$ (15)

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Acquisition (Schedule of Purchase Price Allocation) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016	Oct. 01, 2016
Assets
Goodwill	$ 2,292	$ 2,286
Midstream Natural Gas Assets
Assets
Cash			$ 83
Accounts receivable			24
Inventory			6
Property, plant, and equipment, net			730
Goodwill			268
Customer relationship intangibles			770
Other current assets			1
Total assets			1,882
Liabilities
Accounts payable			19
Other current liabilities			14
Long-term debt			204
Other long-term liabilities			26
Total liabilities			263
Less noncontrolling interest			390
Total cash consideration			$ 1,229

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Regulatory Matters (Details Textuals) - DTE Electric - MPSC - USD ($) $ in Millions	Apr. 19, 2017	Jan. 31, 2017	Nov. 01, 2016	Aug. 01, 2016	Feb. 01, 2016	Mar. 31, 2017
Public Utilities, General Disclosures [Line Items]
Estimated recovery challenged amount						$ 13
Electric Rate Case Filing 2016
Public Utilities, General Disclosures [Line Items]
Requested rate increase					$ 344
Self-implemented base rate				$ 245
Approved annual revenue change		$ 184
Return on equity percent		10.10%
DTE Main Electric Depreciation Case Filing 2016
Public Utilities, General Disclosures [Line Items]
Requested depreciation rate increase (decrease) amount			$ 156
Subsequent event | Electric Rate Case Filing 2017
Public Utilities, General Disclosures [Line Items]
Requested rate increase	$ 231
Return on equity percent	10.10%
Return on equity requested percent	10.50%
Refundable self-implemented rates | Electric Rate Case Filing 2016
Public Utilities, General Disclosures [Line Items]
Refund liabilities						$ 37

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Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Basic Earnings per Share
Net income attributable to DTE Energy Company	$ 400	$ 247
Less allocation of earnings to net restricted stock awards	(1)	0
Net income available to common shareholders — basic	$ 399	$ 247
Average number of common shares outstanding, basic (in shares)	179	179
Basic earnings per common share (in dollars per share)	$ 2.23	$ 1.38
Diluted Earnings per Share
Net income attributable to DTE Energy Company	$ 400	$ 247
Less allocation of earnings to net restricted stock awards	(1)	0
Net income available to common shareholders — diluted	$ 399	$ 247
Average number of common shares outstanding, diluted (in shares)	179	180
Diluted earnings per common share (in dollars per share)	$ 2.23	$ 1.37

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Fair Value (Assets and Liabilities Recorded at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
ASSETS
Decommissioning fund outstanding commitments	$ 15
Derivative Assets
Derivative assets, gross	496	$ 549
Derivative asset, netting	(355)	(468)
Derivative assets, net	141	81
Derivative Liabilities
Derivative liabilities, gross	(491)	(656)
Derivative liability, netting	365	489
Derivative liabilities, net	(126)	(167)
Current derivative liabilities
Derivative Liabilities
Derivative liabilities, gross	(312)	(493)
Noncurrent derivative liabilities
Derivative Liabilities
Derivative liabilities, gross	(179)	(163)
Natural Gas
Derivative Assets
Derivative assets, gross	304	348
Derivative asset, netting	(206)	(306)
Derivative assets, net	98	42
Derivative Liabilities
Derivative liabilities, gross	(289)	(461)
Derivative liability, netting	202	321
Derivative liabilities, net	(87)	(140)
Electricity
Derivative Assets
Derivative assets, gross	186	193
Derivative asset, netting	(146)	(157)
Derivative assets, net	40	36
Derivative Liabilities
Derivative liabilities, gross	(197)	(189)
Derivative liability, netting	158	163
Derivative liabilities, net	(39)	(26)
Other
Derivative Assets
Derivative assets, gross	1	2
Derivative asset, netting	0	0
Derivative assets, net	1	2
Derivative Liabilities
Derivative liabilities, gross	(3)	(3)
Derivative liability, netting	3	2
Derivative liabilities, net	0	(1)
Foreign currency exchange contracts
Derivative Assets
Derivative assets, gross	5	6
Derivative asset, netting	(3)	(5)
Derivative assets, net	2	1
Derivative Liabilities
Derivative liabilities, gross	(2)	(3)
Derivative liability, netting	2	3
Derivative liabilities, net	0	0
Recurring
ASSETS
Cash equivalents	17	17
Derivative Assets
Derivative asset, netting	(355)	(468)
Derivative assets, net	141	81
Total assets	1,695	1,583
Derivative Liabilities
Derivative liability, netting	365	489
Derivative liabilities, net	(126)	(167)
Net Assets (Liabilities) at the end of the period	1,569	1,416
Net Assets (Liabilities) at the end of the period, netting	10	21
Recurring | Current assets
Derivative Assets
Derivative asset, netting	(281)	(400)
Total assets	85	64
Recurring | Noncurrent assets
Derivative Assets
Derivative asset, netting	(74)	(68)
Total assets	1,610	1,519
Recurring | Current derivative liabilities
Derivative Liabilities
Derivative liability, netting	279	424
Derivative liabilities, net	(33)	(69)
Recurring | Noncurrent derivative liabilities
Derivative Liabilities
Derivative liability, netting	86	65
Derivative liabilities, net	(93)	(98)
Recurring | Restricted assets
ASSETS
Cash equivalents	7	7
Recurring | Other investments
ASSETS
Cash equivalents	10	10
Recurring | Natural Gas
Derivative Assets
Derivative asset, netting	(206)	(306)
Derivative assets, net	98	42
Derivative Liabilities
Derivative liability, netting	202	321
Derivative liabilities, net	(87)	(140)
Recurring | Electricity
Derivative Assets
Derivative asset, netting	(146)	(157)
Derivative assets, net	40	36
Derivative Liabilities
Derivative liability, netting	158	163
Derivative liabilities, net	(39)	(26)
Recurring | Other
Derivative Assets
Derivative asset, netting	0	0
Derivative assets, net	1	2
Derivative Liabilities
Derivative liability, netting	3	2
Derivative liabilities, net	0	(1)
Recurring | Foreign currency exchange contracts
Derivative Assets
Derivative asset, netting	(3)	(5)
Derivative assets, net	2	1
Derivative Liabilities
Derivative liability, netting	2	3
Derivative liabilities, net	0	0
Recurring | Level 1
ASSETS
Cash equivalents	14	14
Derivative Assets
Derivative assets, gross	82	216
Total assets	1,173	1,301
Derivative Liabilities
Derivative liabilities, gross	(82)	(226)
Net Assets (Liabilities) at the end of the period	1,091	1,075
Recurring | Level 1 | Current assets
Derivative Assets
Total assets	78	205
Recurring | Level 1 | Noncurrent assets
Derivative Assets
Total assets	1,095	1,096
Recurring | Level 1 | Current derivative liabilities
Derivative Liabilities
Derivative liabilities, gross	(63)	(203)
Recurring | Level 1 | Noncurrent derivative liabilities
Derivative Liabilities
Derivative liabilities, gross	(19)	(23)
Recurring | Level 1 | Natural Gas
Derivative Assets
Derivative assets, gross	82	216
Derivative Liabilities
Derivative liabilities, gross	(82)	(226)
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 | Foreign currency exchange contracts
Derivative Assets
Derivative assets, gross	0	0
Derivative Liabilities
Derivative liabilities, gross	0	0
Recurring | Level 2
ASSETS
Cash equivalents	3	3
Derivative Assets
Derivative assets, gross	308	239
Total assets	771	656
Derivative Liabilities
Derivative liabilities, gross	(280)	(248)
Net Assets (Liabilities) at the end of the period	491	408
Recurring | Level 2 | Current assets
Derivative Assets
Total assets	228	199
Recurring | Level 2 | Noncurrent assets
Derivative Assets
Total assets	543	457
Recurring | Level 2 | Current derivative liabilities
Derivative Liabilities
Derivative liabilities, gross	(213)	(211)
Recurring | Level 2 | Noncurrent derivative liabilities
Derivative Liabilities
Derivative liabilities, gross	(67)	(37)
Recurring | Level 2 | Natural Gas
Derivative Assets
Derivative assets, gross	151	79
Derivative Liabilities
Derivative liabilities, gross	(121)	(86)
Recurring | Level 2 | Electricity
Derivative Assets
Derivative assets, gross	152	154
Derivative Liabilities
Derivative liabilities, gross	(157)	(159)
Recurring | Level 2 | Other
Derivative Assets
Derivative assets, gross	0	0
Derivative Liabilities
Derivative liabilities, gross	0	0
Recurring | Level 2 | Foreign currency exchange contracts
Derivative Assets
Derivative assets, gross	5	6
Derivative Liabilities
Derivative liabilities, gross	(2)	(3)
Recurring | Level 3
ASSETS
Cash equivalents	0	0
Derivative Assets
Derivative assets, gross	106	94
Total assets	106	94
Derivative Liabilities
Derivative liabilities, gross	(129)	(182)
Net Assets (Liabilities) at the end of the period	(23)	(88)
Recurring | Level 3 | Current assets
Derivative Assets
Total assets	60	60
Recurring | Level 3 | Noncurrent assets
Derivative Assets
Total assets	46	34
Recurring | Level 3 | Current derivative liabilities
Derivative Liabilities
Derivative liabilities, gross	(36)	(79)
Recurring | Level 3 | Noncurrent derivative liabilities
Derivative Liabilities
Derivative liabilities, gross	(93)	(103)
Recurring | Level 3 | Natural Gas
Derivative Assets
Derivative assets, gross	71	53
Derivative Liabilities
Derivative liabilities, gross	(86)	(149)
Recurring | Level 3 | Electricity
Derivative Assets
Derivative assets, gross	34	39
Derivative Liabilities
Derivative liabilities, gross	(40)	(30)
Recurring | Level 3 | Other
Derivative Assets
Derivative assets, gross	1	2
Derivative Liabilities
Derivative liabilities, gross	(3)	(3)
Recurring | Level 3 | Foreign currency exchange contracts
Derivative Assets
Derivative assets, gross	0	0
Derivative Liabilities
Derivative liabilities, gross	0	0
DTE Electric
ASSETS
Decommissioning fund outstanding commitments	15
DTE Electric | Recurring
ASSETS
Cash equivalents	11	11
Derivative Assets
Total assets	1,385	1,342
DTE Electric | Recurring | Current assets
Derivative Assets
Total assets	12	13
DTE Electric | Recurring | Noncurrent assets
Derivative Assets
Total assets	1,373	1,329
DTE Electric | Recurring | Other investments
ASSETS
Cash equivalents	11	11
DTE Electric | Recurring | Financial transmission rights
Derivative Assets
Derivative assets, net	1	2
DTE Electric | Recurring | Level 1
ASSETS
Cash equivalents	8	8
Derivative Assets
Total assets	921	923
DTE Electric | Recurring | Level 1 | Current assets
Derivative Assets
Total assets	8	8
DTE Electric | Recurring | Level 1 | Noncurrent assets
Derivative Assets
Total assets	913	915
DTE Electric | Recurring | Level 1 | Financial transmission rights
Derivative Assets
Derivative assets, net	0	0
DTE Electric | Recurring | Level 2
ASSETS
Cash equivalents	3	3
Derivative Assets
Total assets	463	417
DTE Electric | Recurring | Level 2 | Current assets
Derivative Assets
Total assets	3	3
DTE Electric | Recurring | Level 2 | Noncurrent assets
Derivative Assets
Total assets	460	414
DTE Electric | Recurring | Level 2 | Financial transmission rights
Derivative Assets
Derivative assets, net	0	0
DTE Electric | Recurring | Level 3
ASSETS
Cash equivalents	0	0
Derivative Assets
Total assets	1	2
DTE Electric | Recurring | Level 3 | Current assets
Derivative Assets
Total assets	1	2
DTE Electric | Recurring | Level 3 | Noncurrent assets
Derivative Assets
Total assets	0	0
DTE Electric | Recurring | Level 3 | Financial transmission rights
Derivative Assets
Derivative assets, net	1	2
Equity securities | Recurring
ASSETS
Nuclear decommissioning trusts, fair value	890	887
Other investments, fair value	110	104
Equity securities | Recurring | Level 1
ASSETS
Nuclear decommissioning trusts, fair value	890	887
Other investments, fair value	110	104
Equity securities | Recurring | Level 2
ASSETS
Nuclear decommissioning trusts, fair value	0	0
Other investments, fair value	0	0
Equity securities | Recurring | Level 3
ASSETS
Nuclear decommissioning trusts, fair value	0	0
Other investments, fair value	0	0
Equity securities | DTE Electric | Recurring
ASSETS
Nuclear decommissioning trusts, fair value	890	887
Other investments, fair value	9	9
Equity securities | DTE Electric | Recurring | Level 1
ASSETS
Nuclear decommissioning trusts, fair value	890	887
Other investments, fair value	9	9
Equity securities | DTE Electric | Recurring | Level 2
ASSETS
Nuclear decommissioning trusts, fair value	0	0
Other investments, fair value	0	0
Equity securities | DTE Electric | Recurring | Level 3
ASSETS
Nuclear decommissioning trusts, fair value	0	0
Other investments, fair value	0	0
Fixed income securities | Recurring
ASSETS
Nuclear decommissioning trusts, fair value	471	425
Other investments, fair value	63	61
Fixed income securities | Recurring | Level 1
ASSETS
Nuclear decommissioning trusts, fair value	11	11
Other investments, fair value	63	61
Fixed income securities | Recurring | Level 2
ASSETS
Nuclear decommissioning trusts, fair value	460	414
Other investments, fair value	0	0
Fixed income securities | Recurring | Level 3
ASSETS
Nuclear decommissioning trusts, fair value	0	0
Other investments, fair value	0	0
Fixed income securities | DTE Electric | Recurring
ASSETS
Nuclear decommissioning trusts, fair value	471	425
Fixed income securities | DTE Electric | Recurring | Level 1
ASSETS
Nuclear decommissioning trusts, fair value	11	11
Fixed income securities | DTE Electric | Recurring | Level 2
ASSETS
Nuclear decommissioning trusts, fair value	460	414
Fixed income securities | DTE Electric | Recurring | Level 3
ASSETS
Nuclear decommissioning trusts, fair value	0	0
Cash equivalents | Recurring
ASSETS
Nuclear decommissioning trusts, fair value	3	8
Cash equivalents | Recurring | Level 1
ASSETS
Nuclear decommissioning trusts, fair value	3	8
Cash equivalents | Recurring | Level 2
ASSETS
Nuclear decommissioning trusts, fair value	0	0
Cash equivalents | Recurring | Level 3
ASSETS
Nuclear decommissioning trusts, fair value	0	0
Cash equivalents | DTE Electric | Recurring
ASSETS
Nuclear decommissioning trusts, fair value	3	8
Cash equivalents | DTE Electric | Recurring | Level 1
ASSETS
Nuclear decommissioning trusts, fair value	3	8
Cash equivalents | DTE Electric | Recurring | Level 2
ASSETS
Nuclear decommissioning trusts, fair value	0	0
Cash equivalents | DTE Electric | Recurring | Level 3
ASSETS
Nuclear decommissioning trusts, fair value	$ 0	$ 0

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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
	Mar. 31, 2017	Mar. 31, 2016
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net Assets (Liabilities) as of beginning of period	$ (88)	$ (4)
Transfers into Level 3 from Level 2	0	0
Transfers from Level 3 into Level 2	0	(1)
Total gains (losses):
Included in earnings	44	(79)
Recorded in Regulatory liabilities	2	(2)
Purchases, issuances, and settlements
Settlements	19	29
Net Assets (Liabilities) as of end of period	(23)	(57)
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 March 31, 2017 and 2016 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	32	(76)
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	3
Total gains (losses):
Recorded in Regulatory liabilities	2	(2)
Purchases, issuances, and settlements
Settlements	(3)	0
Net Assets (Liabilities) as of end of period	1	1
The amount of total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets held at March 31, 2017 and 2016 and reflected in DTE Electric's Consolidated Statements of Financial Position	0	0
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	(96)	(5)
Transfers into Level 3 from Level 2	0	0
Transfers from Level 3 into Level 2	0	(1)
Total gains (losses):
Included in earnings	52	(20)
Recorded in Regulatory liabilities	0	0
Purchases, issuances, and settlements
Settlements	29	(8)
Net Assets (Liabilities) as of end of period	(15)	(34)
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 March 31, 2017 and 2016 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	35	(72)
Electricity
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net Assets (Liabilities) as of beginning of period	9	6
Transfers into Level 3 from Level 2	0	0
Transfers from Level 3 into Level 2	0	0
Total gains (losses):
Included in earnings	(9)	(58)
Recorded in Regulatory liabilities	0	0
Purchases, issuances, and settlements
Settlements	(6)	36
Net Assets (Liabilities) as of end of period	(6)	(16)
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 March 31, 2017 and 2016 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	(3)	(3)
Other
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net Assets (Liabilities) as of beginning of period	(1)	(5)
Transfers into Level 3 from Level 2	0	0
Transfers from Level 3 into Level 2	0	0
Total gains (losses):
Included in earnings	1	(1)
Recorded in Regulatory liabilities	2	(2)
Purchases, issuances, and settlements
Settlements	(4)	1
Net Assets (Liabilities) as of end of period	(2)	(7)
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 March 31, 2017 and 2016 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	$ 0	$ (1)

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Fair Value (Unobservable Inputs related to Level 3 Assets and Liabilities) (Details) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2017 USD ($) $ / MWh $ / MMBTU	Dec. 31, 2016 USD ($) $ / MWh $ / MMBTU
Unobservable Inputs Valuation Techniques [Line Items]
Derivative assets, gross	$ 496	$ 549
Derivative liabilities, gross	(491)	(656)
Recurring | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Derivative assets, gross	106	94
Derivative liabilities, gross	(129)	(182)
Natural Gas
Unobservable Inputs Valuation Techniques [Line Items]
Derivative assets, gross	304	348
Derivative liabilities, gross	(289)	(461)
Natural Gas | Recurring | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Derivative assets, gross	71	53
Derivative liabilities, gross	$ (86)	$ (149)
Natural Gas | Minimum | Discounted cash flow valuation technique | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MMBTU	(0.87)	(1.00)
Natural Gas | Maximum | Discounted cash flow valuation technique | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MMBTU	6.25	7.90
Natural Gas | Weighted average | Discounted cash flow valuation technique | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MMBTU	(0.14)	(0.05)
Electricity
Unobservable Inputs Valuation Techniques [Line Items]
Derivative assets, gross	$ 186	$ 193
Derivative liabilities, gross	(197)	(189)
Electricity | Recurring | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Derivative assets, gross	34	39
Derivative liabilities, gross	$ (40)	$ (30)
Electricity | Minimum | Discounted cash flow valuation technique | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MWh	(6)	(6)
Electricity | Maximum | Discounted cash flow valuation technique | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MWh	8	12
Electricity | Weighted average | Discounted cash flow valuation technique | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MWh	1	1

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Fair Value (Fair Value of Financial Instruments) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	$ 31	$ 36
Dividends payable	148	148
Short-term borrowings	59	499
Notes payable — other	18	17
Long-term debt	11,762	11,270
Carrying amount | DTE Electric
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	0	5
Short-term borrowings	59	62
Notes payable — other	6	6
Long-term debt	5,879	5,878
Carrying amount | DTE Electric | Affiliates
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	205	117
Fair value | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	0	0
Dividends payable	148	148
Short-term borrowings	0	0
Notes payable — other	0	0
Long-term debt	1,505	1,465
Fair value | Level 1 | DTE Electric
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	0	0
Short-term borrowings	0	0
Notes payable — other	0	0
Long-term debt	0	0
Fair value | Level 1 | DTE Electric | Affiliates
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	0	0
Fair value | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	0	0
Dividends payable	0	0
Short-term borrowings	59	499
Notes payable — other	0	0
Long-term debt	9,874	9,384
Fair value | Level 2 | DTE Electric
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	0	0
Short-term borrowings	59	62
Notes payable — other	0	0
Long-term debt	6,016	6,026
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 capital leases	31	36
Dividends payable	0	0
Short-term borrowings	0	0
Notes payable — other	18	17
Long-term debt	1,044	1,056
Fair value | Level 3 | DTE Electric
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	0	5
Short-term borrowings	0	0
Notes payable — other	6	6
Long-term debt	262	264
Fair value | Level 3 | DTE Electric | Affiliates
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	$ 205	$ 117

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Fair Value (Fair Value of Nuclear Decommissioning Trust Fund Assets) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Schedule of Available-for-sale Securities [Line Items]
Nuclear decommissioning trust funds	$ 1,364	$ 1,320
DTE Electric
Schedule of Available-for-sale Securities [Line Items]
Nuclear decommissioning trust funds	1,364	1,320
DTE Electric | Nuclear decommissioning trust fund
Schedule of Available-for-sale Securities [Line Items]
Nuclear decommissioning trust funds	1,364	1,320
DTE Electric | Nuclear decommissioning trust fund | Fermi 2
Schedule of Available-for-sale Securities [Line Items]
Nuclear decommissioning trust funds	1,350	1,291
DTE Electric | Nuclear decommissioning trust fund | Fermi 1
Schedule of Available-for-sale Securities [Line Items]
Nuclear decommissioning trust funds	3	3
DTE Electric | Nuclear decommissioning trust fund | Low-level radioactive waste
Schedule of Available-for-sale Securities [Line Items]
Nuclear decommissioning trust funds	$ 11	$ 26

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
	Mar. 31, 2017	Mar. 31, 2016
Schedule of Available-for-sale Securities [Line Items]
Realized gains	$ 23	$ 9
Realized losses	(8)	(15)
Proceeds from sale of securities	$ 394	$ 260

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	Mar. 31, 2017	Dec. 31, 2016
Schedule of Available-for-sale Securities [Line Items]
Equity securities, fair value	$ 890	$ 887
Fixed income securities, fair value	471	425
Cash equivalents, fair value	3	8
Fair Value	1,364	1,320
Equity securities, unrealized gains	250	222
Fixed income securities, unrealized gains	12	11
Unrealized Gains	262	233
Equity securities, unrealized losses	(38)	(46)
Fixed income securities, unrealized losses	(4)	(5)
Unrealized Losses	$ (42)	$ (51)

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	Mar. 31, 2017 USD ($)
Schedule of Available-for-sale Securities [Line Items]
Due within one year	$ 19
Due after one through five years	109
Due after five through ten years	91
Due after ten years	252
Available-for-sale securities total	$ 471

XML

Fair Value (Details Textuals) - USD ($)	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Fair Value, Option, Quantitative Disclosures [Line Items]
Trading securities realized gain (loss)	$ 8,000,000	$ 5,000,000
DTE Electric
Fair Value, Option, Quantitative Disclosures [Line Items]
Trading securities realized gain (loss)	8,000,000	5,000,000
Accumulated net unrealized investment gain (loss)
Fair Value, Option, Quantitative Disclosures [Line Items]
Unrealized losses on available for sale securities	0	0
Accumulated net unrealized investment gain (loss) | DTE Electric
Fair Value, Option, Quantitative Disclosures [Line Items]
Unrealized losses on available for sale securities	$ 0	$ 0

XML

Financial and Other Derivative Instruments (Fair Value of Derivative Instruments) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Derivatives, Fair Value [Line Items]
Derivative assets	$ 496	$ 549
Derivative liabilities	(491)	(656)
Not designated as hedging instrument
Derivatives, Fair Value [Line Items]
Derivative assets	496	549
Derivative liabilities	(491)	(656)
DTE Electric | Not designated as hedging instrument
Derivatives, Fair Value [Line Items]
Derivative assets	1	2
Natural Gas
Derivatives, Fair Value [Line Items]
Derivative assets	304	348
Derivative liabilities	(289)	(461)
Natural Gas | Not designated as hedging instrument
Derivatives, Fair Value [Line Items]
Derivative assets	304	348
Derivative liabilities	(289)	(461)
Electricity
Derivatives, Fair Value [Line Items]
Derivative assets	186	193
Derivative liabilities	(197)	(189)
Electricity | Not designated as hedging instrument
Derivatives, Fair Value [Line Items]
Derivative assets	186	193
Derivative liabilities	(197)	(189)
Other
Derivatives, Fair Value [Line Items]
Derivative assets	1	2
Derivative liabilities	(3)	(3)
Other | Not designated as hedging instrument
Derivatives, Fair Value [Line Items]
Derivative assets	1	2
Derivative liabilities	(3)	(3)
Foreign currency exchange contracts
Derivatives, Fair Value [Line Items]
Derivative assets	5	6
Derivative liabilities	(2)	(3)
Foreign currency exchange contracts | Not designated as hedging instrument
Derivatives, Fair Value [Line Items]
Derivative assets	5	6
Derivative liabilities	(2)	(3)
Financial transmission rights | DTE Electric | Not designated as hedging instrument
Derivatives, Fair Value [Line Items]
Derivative assets	1	2
Current derivative assets
Derivatives, Fair Value [Line Items]
Derivative assets	349	447
Current derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	(312)	(493)
Noncurrent derivative assets
Derivatives, Fair Value [Line Items]
Derivative assets	147	102
Noncurrent derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative liabilities	$ (179)	$ (163)

XML

Financial and Other Derivative Instruments (Details Textuals) - USD ($)	Mar. 31, 2017	Dec. 31, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Letters of credit that could be used to offset net derivative liabilities	$ 3,000,000	$ 2,000,000
Letters of credit received that could be used to offset net derivative assets	4,000,000	2,000,000
Cash collateral posted, net of cash collateral received	48,000,000	34,000,000
Collateral adjustment on derivative assets	3,000,000	7,000,000
Collateral adjustment on derivative liabilities	13,000,000	28,000,000
Cash collateral paid	41,000,000	18,000,000
Cash collateral received	3,000,000	$ 5,000,000
Additional collateral, aggregate fair value	437,000,000
Derivative net liability position aggregate fair value	397,000,000
Collateral already posted fair value	0
Derivative net asset position, fair value	342,000,000
Remaining amount of offsets to derivative net liability positions for hard and soft trigger provisions	$ 55,000,000

XML

Financial and Other Derivative Instruments (Netting Offsets of Derivative Assets and Liabilities) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Offsetting Assets [Line Items]
Derivative assets	$ 496	$ 549
Gross amounts offset in the Consolidated Statements of Financial Position, Assets	(355)	(468)
Derivative assets, net	141	81
Derivative liabilities	(491)	(656)
Gross amounts offset in the Consolidated Statements of Financial Position, Liabilities	365	489
Derivative liabilities, net	(126)	(167)
Natural Gas
Offsetting Assets [Line Items]
Derivative assets	304	348
Gross amounts offset in the Consolidated Statements of Financial Position, Assets	(206)	(306)
Derivative assets, net	98	42
Derivative liabilities	(289)	(461)
Gross amounts offset in the Consolidated Statements of Financial Position, Liabilities	202	321
Derivative liabilities, net	(87)	(140)
Electricity
Offsetting Assets [Line Items]
Derivative assets	186	193
Gross amounts offset in the Consolidated Statements of Financial Position, Assets	(146)	(157)
Derivative assets, net	40	36
Derivative liabilities	(197)	(189)
Gross amounts offset in the Consolidated Statements of Financial Position, Liabilities	158	163
Derivative liabilities, net	(39)	(26)
Other
Offsetting Assets [Line Items]
Derivative assets	1	2
Gross amounts offset in the Consolidated Statements of Financial Position, Assets	0	0
Derivative assets, net	1	2
Derivative liabilities	(3)	(3)
Gross amounts offset in the Consolidated Statements of Financial Position, Liabilities	3	2
Derivative liabilities, net	0	(1)
Foreign currency exchange contracts
Offsetting Assets [Line Items]
Derivative assets	5	6
Gross amounts offset in the Consolidated Statements of Financial Position, Assets	(3)	(5)
Derivative assets, net	2	1
Derivative liabilities	(2)	(3)
Gross amounts offset in the Consolidated Statements of Financial Position, Liabilities	2	3
Derivative liabilities, net	$ 0	$ 0

XML

Financial and Other Derivative Instruments (Netting Offsets Reconciliation to Balance Sheet) (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Derivative Assets
Derivative assets	$ 496	$ 549
Collateral adjustment	(3)	(7)
Derivative assets, current	68	47
Derivative assets, noncurrent	73	34
Derivative Liabilities
Derivative liabilities	(491)	(656)
Collateral adjustment	13	28
Derivative liabilities, current	(33)	(69)
Derivative liabilities, noncurrent	(93)	(98)
Current derivative assets
Derivative Assets
Derivative assets	349	447
Counterparty netting	(278)	(396)
Collateral adjustment	(3)	(4)
Derivative assets, current	68	47
Noncurrent derivative assets
Derivative Assets
Derivative assets	147	102
Counterparty netting	(74)	(65)
Collateral adjustment	0	(3)
Derivative assets, noncurrent	73	34
Current derivative liabilities
Derivative Liabilities
Derivative liabilities	(312)	(493)
Counterparty netting	278	396
Collateral adjustment	1	28
Derivative liabilities, current	(33)	(69)
Noncurrent derivative liabilities
Derivative Liabilities
Derivative liabilities	(179)	(163)
Counterparty netting	74	65
Collateral adjustment	12	0
Derivative liabilities, noncurrent	$ (93)	$ (98)

XML

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
	Mar. 31, 2017	Mar. 31, 2016
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	$ 111	$ (46)
Natural Gas | Operating Revenues — Non-utility operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	57	(56)
Natural Gas | Fuel, purchased power, and gas — non-utility
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	61	41
Electricity | Operating Revenues — Non-utility operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	(7)	(24)
Other | Operating Revenues — Non-utility operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	0	(2)
Foreign currency exchange contracts | Operating Revenues — Non-utility operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	$ 0	$ (5)

XML

Financial and Other Derivative Instruments (Cumulative Gross Volume of Derivative Contracts Outstanding) (Details)	3 Months Ended
	Mar. 31, 2017 CAD MWh MMBTU gal
Natural Gas (MMBtu)
Derivative [Line Items]
Commodity | MMBTU	1,781,816,780
Electricity (MWh)
Derivative [Line Items]
Commodity | MWh	35,032,431
Oil (Gallons)
Derivative [Line Items]
Oil (Gallons) | gal	12,936,000
Foreign currency exchange contracts (Canadian dollars)
Derivative [Line Items]
Foreign Currency Exchange (Canadian dollars) | CAD	CAD 73,633,072

XML

Long-Term Debt (Details)	3 Months Ended
	Mar. 31, 2017 USD ($)
Debt Instrument [Line Items]
Debt issued	$ 500,000,000
Debt redeemed	$ 5,000,000
Senior Notes | DTE Energy | March 2017 Senior Notes 3.80% due 2027
Debt Instrument [Line Items]
Interest rate	3.80%
Debt issued	$ 500,000,000
Other Long-Term Debt | DTE Energy
Debt Instrument [Line Items]
Debt redeemed	$ 5,000,000

XML

Short-Term Credit Arrangements and Borrowings (Details) - USD ($)	Mar. 31, 2017	Feb. 28, 2017
Availability under combined facilities
Maximum borrowing capacity	$ 2,120,000,000
Amounts outstanding	198,000,000
Net availability	1,922,000,000
DTE Energy
Availability under combined facilities
Maximum borrowing capacity	1,420,000,000
Amounts outstanding	139,000,000
Net availability	1,281,000,000
DTE Electric
Availability under combined facilities
Maximum borrowing capacity	400,000,000
Amounts outstanding	59,000,000
Net availability	341,000,000
DTE Gas
Availability under combined facilities
Maximum borrowing capacity	300,000,000
Amounts outstanding	0
Net availability	300,000,000
Letter of credit
Availability under combined facilities
Amounts outstanding	139,000,000
Letter of credit | DTE Energy
Availability under combined facilities
Amounts outstanding	139,000,000
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 | Unsecured letter of credit facility, expiring in February 2019
Availability under combined facilities
Maximum borrowing capacity	150,000,000
Letter of credit | Unsecured letter of credit facility, expiring in February 2019 | DTE Energy
Availability under combined facilities
Maximum borrowing capacity	150,000,000
Letter of credit | Unsecured letter of credit facility, expiring in February 2019 | DTE Electric
Availability under combined facilities
Maximum borrowing capacity	0
Letter of credit | Unsecured letter of credit facility, expiring in February 2019 | DTE Gas
Availability under combined facilities
Maximum borrowing capacity	0
Letter of credit | Unsecured letter of credit facility, expiring in September 2017
Availability under combined facilities
Maximum borrowing capacity	70,000,000
Letter of credit | Unsecured letter of credit facility, expiring in September 2017 | DTE Energy
Availability under combined facilities
Maximum borrowing capacity	70,000,000
Letter of credit | Unsecured letter of credit facility, expiring in September 2017 | DTE Electric
Availability under combined facilities
Maximum borrowing capacity	0
Letter of credit | Unsecured letter of credit facility, expiring in September 2017 | DTE Gas
Availability under combined facilities
Maximum borrowing capacity	0
Letter of credit | Unsecured letter of credit facility, expiring in February 2017 | DTE Energy
Availability under combined facilities
Maximum borrowing capacity		$ 100,000,000
Revolving credit facility | Unsecured revolving credit facility, expiring in April 2021
Availability under combined facilities
Maximum borrowing capacity	1,900,000,000
Revolving credit facility | Unsecured revolving credit facility, expiring in April 2021 | DTE Energy
Availability under combined facilities
Maximum borrowing capacity	1,200,000,000
Revolving credit facility | Unsecured revolving credit facility, expiring in April 2021 | DTE Electric
Availability under combined facilities
Maximum borrowing capacity	400,000,000
Revolving credit facility | Unsecured revolving credit facility, expiring in April 2021 | DTE Gas
Availability under combined facilities
Maximum borrowing capacity	300,000,000
Commercial paper issuances
Availability under combined facilities
Amounts outstanding	59,000,000
Commercial paper issuances | DTE Energy
Availability under combined facilities
Amounts outstanding	0
Commercial paper issuances | DTE Electric
Availability under combined facilities
Amounts outstanding	59,000,000
Commercial paper issuances | DTE Gas
Availability under combined facilities
Amounts outstanding	$ 0

XML

Short-Term Credit Arrangements and Borrowings (Details Textuals)	Mar. 31, 2017 USD ($)	Dec. 31, 2016 USD ($)
Short-term Debt [Line Items]
Other outstanding letters of credit	$ 198,000,000
Maximum
Short-term Debt [Line Items]
Ratio of indebtedness to net capital	0.65
DTE Energy
Short-term Debt [Line Items]
Ratio of indebtedness to net capital	0.53
Other outstanding letters of credit	$ 139,000,000
DTE Electric
Short-term Debt [Line Items]
Ratio of indebtedness to net capital	0.50
Other outstanding letters of credit	$ 59,000,000
DTE Gas
Short-term Debt [Line Items]
Ratio of indebtedness to net capital	0.45
Other outstanding letters of credit	$ 0
Letter of credit
Short-term Debt [Line Items]
Other outstanding letters of credit	139,000,000
Letter of credit | DTE Energy
Short-term Debt [Line Items]
Other outstanding letters of credit	139,000,000
Letter of credit | DTE Electric
Short-term Debt [Line Items]
Other outstanding letters of credit	0
Letter of credit | DTE Gas
Short-term Debt [Line Items]
Other outstanding letters of credit	0
Demand financing agreement | DTE Energy
Short-term Debt [Line Items]
Maximum borrowing capacity, financing agreement	100,000,000
Maximum additional margin financing	50,000,000
Amount outstanding	16,000,000	$ 50,000,000
Demand financing agreement plus letter of credit | DTE Energy
Short-term Debt [Line Items]
Maximum borrowing capacity, financing agreement	135,000,000
Other outstanding letters of credit | Letter of credit | DTE Energy
Short-term Debt [Line Items]
Other outstanding letters of credit	17,000,000
Demand financing agreement | Letter of credit | DTE Energy
Short-term Debt [Line Items]
Maximum borrowing capacity, financing agreement	$ 35,000,000

XML

Commitments and Contingencies (Details Textuals) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2017 USD ($) employee facility NOV	Dec. 31, 2016 USD ($) facilities	Sep. 07, 2016 state	Jul. 31, 2009 facility
Loss Contingencies [Line Items]
Unrecorded unconditional purchase obligation	$ 3,000
Synthetic fuel
Loss Contingencies [Line Items]
Number of days after expiration of statutes of limitations	90 days
Maximum potential liability	$ 620
Reduced emissions fuel guarantees
Loss Contingencies [Line Items]
Number of days after expiration of statutes of limitations	90 days
Maximum potential liability	$ 308
Other guarantees
Loss Contingencies [Line Items]
Maximum potential liability	55
Performance surety bonds
Loss Contingencies [Line Items]
Performance bonds outstanding	$ 56
DTE Electric
Loss Contingencies [Line Items]
Number of states with NOX emissions from power plants | state			22
Number of power plants in violation | facility				5
Number of NOVs/FOVs | NOV	2
Environmental capital expenditures through prior year end		$ 2,400
Number of former Mgp sites | facilities		3
Accrued for remediation	$ 8	$ 8
Number of permitted engineered coal ash storage facilities owned | facility	3
Time period to comply with coal combustion residual requirements and effluent limitations guidelines	6 years
Unrecorded unconditional purchase obligation	$ 1,500
DTE Gas
Loss Contingencies [Line Items]
Number of former Mgp sites | facility	14
Accrued for remediation	$ 41	$ 43
Amortization period (in years)	10 years
DTE Gas | NEXUS pipeline
Loss Contingencies [Line Items]
Maximum potential liability	$ 53
Lease agreement term	15 years
Percentage of payment obligations due	50.00%
Texas Eastern Transmission, LP | NEXUS pipeline
Loss Contingencies [Line Items]
Maximum potential liability	$ 8
Lease agreement term	15 years
Percentage of payment obligations due	50.00%
Yolo Solano County Health Department in California and the District Attorney Subpoena
Loss Contingencies [Line Items]
Loss accrual	$ 4
Coal combustion residual rule | DTE Electric
Loss Contingencies [Line Items]
Estimated costs associated with building new facilities	$ 309
Clean up completed and site closed | DTE Gas
Loss Contingencies [Line Items]
Number of former Mgp sites | facility	6
Partial closure complete | DTE Gas
Loss Contingencies [Line Items]
Number of former Mgp sites | facility	4
Labor force concentration risk | Workforce subject to collective bargaining arrangements
Loss Contingencies [Line Items]
Number of employees | employee	4,800
Labor force concentration risk | Workforce subject to collective bargaining arrangements | DTE Electric
Loss Contingencies [Line Items]
Number of employees | employee	2,600

XML

Retirement Benefits and Trusteed Assets (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Pension Benefits
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost	$ 24	$ 23
Interest cost	54	54
Expected return on plan assets	(78)	(77)
Amortization of net actuarial loss	43	40
Amortization of prior service cost (credit)	0	0
Net periodic benefit cost (credit)	43	40
Pension Benefits | DTE Electric
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost	18	18
Interest cost	41	41
Expected return on plan assets	(55)	(55)
Amortization of net actuarial loss	31	29
Amortization of prior service cost (credit)	0	0
Net periodic benefit cost (credit)	35	33
Other Postretirement Benefits
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost	7	6
Interest cost	18	20
Expected return on plan assets	(33)	(32)
Amortization of net actuarial loss	3	8
Amortization of prior service cost (credit)	(3)	(30)
Net periodic benefit cost (credit)	(8)	(28)
Other Postretirement Benefits | DTE Electric
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost	5	5
Interest cost	14	15
Expected return on plan assets	(23)	(23)
Amortization of net actuarial loss	2	6
Amortization of prior service cost (credit)	(2)	(22)
Net periodic benefit cost (credit)	$ (4)	$ (19)

XML

Retirement Benefits and Trusteed Assets (Details Textuals)	3 Months Ended
	Mar. 31, 2017 USD ($)
Pension Benefits
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Contributions by employer	$ 126,000,000
Maximum contribution amount	180,000,000
Pension Benefits | DTE Electric
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Contributions by employer	125,000,000
Maximum contribution amount	145,000,000
Other Postretirement Benefits
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Maximum contribution amount	$ 0

XML

Segment and Related Information (Details Textuals) customer in Millions	Mar. 31, 2017 customer
Segment Reporting [Abstract]
Number of electric utility customers	2.2
Number of gas utility customers	1.3

XML

Segment and Related Information (Financial Data - Operating Revenues including Inter-segment Revenues) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Segment Reporting, Revenue Reconciling Item [Line Items]
Utility operations	$ 1,718	$ 1,664
Non-utility operations	(1,518)	(902)
Revenues	(3,236)	(2,566)
Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Non-utility operations	(202)	(169)
Electric | Operating segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Utility operations	1,175	1,153
Gas | Operating segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Utility operations	557	520
Gas Storage and Pipelines | Operating segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Non-utility operations	(105)	(67)
Power and Industrial Projects | Operating segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Non-utility operations	(548)	(446)
Energy Trading | Operating segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Non-utility operations	(1,052)	(549)
Corporate and Other | Operating segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Non-utility operations	(1)	0
Continuing operations | Electric | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Revenues	12	9
Continuing operations | Gas | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Revenues	3	0
Continuing operations | Gas Storage and Pipelines | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Revenues	7	2
Continuing operations | Power and Industrial Projects | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Revenues	168	148
Continuing operations | Energy Trading | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Revenues	11	10
Continuing operations | Corporate and Other | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Revenues	1	0
Discontinued operations | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Revenues	$ 202	$ 169

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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
	Mar. 31, 2017	Mar. 31, 2016
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net income attributable to DTE Energy Company	$ 400	$ 247
Electric
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net income attributable to DTE Energy Company	106	127
Gas
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net income attributable to DTE Energy Company	107	87
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	45	30
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	30	17
Energy Trading
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net income attributable to DTE Energy Company	96	(7)
Corporate and Other
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net income attributable to DTE Energy Company	$ 16	$ (7)