10-Q

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

___________________________________

FORM 10-Q

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the Quarterly Period ended June 30, 2016

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, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer,” and “smaller reporting 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)
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)

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 June 30, 2016:

Registrant	Description	Shares
DTE Energy	Common Stock, without par value	179,435,004
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	19
	Note 3 — New Accounting Pronouncements	20
	Note 4 — Regulatory Matters	22
	Note 5 — Earnings Per Share	23
	Note 6 — Fair Value	23
	Note 7 — Financial and Other Derivative Instruments	31
	Note 8 — Long-Term Debt	35
	Note 9 — Short-Term Credit Arrangements and Borrowings	35
	Note 10 — Commitments and Contingencies	36
	Note 11 — Retirement Benefits and Trusteed Assets	40
	Note 12 — Segment and Related Information	41
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	43
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	57
Item 4.	Controls and Procedures	60
PART II - OTHER INFORMATION
Item 1.	Legal Proceedings	61
Item 1A.	Risk Factors	61
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	61
Item 6.	Exhibits	61
	Signatures	64

DEFINITIONS

ARO	Asset Retirement Obligation
ASU	Accounting Standards Update issued by the FASB
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
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
IRM	Infrastructure Recovery Mechanism
MDEQ	Michigan Department of Environmental Quality
MGP	Manufactured Gas Plant
MPSC	Michigan Public Service Commission
MTM	Mark-to-market
NAV	Net Asset Value
NEXUS	NEXUS Gas Transmission, LLC
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
NRC	U.S. Nuclear Regulatory Commission
PLD	City of Detroit's Public Lighting Department
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
Retail access	Michigan legislation provided customers the option of access to alternative suppliers for electricity and natural gas.
Securitization	DTE Electric financed specific stranded costs at lower interest rates through the sale of rate reduction bonds by a wholly-owned special purpose entity, The Detroit Edison Securitization Funding LLC.

1

DEFINITIONS

Shenango	Shenango Incorporated is a coke battery plant located in Pittsburgh, PA, that was closed in January 2016 and is included in the Power and Industrial Projects 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 PLD customers to DTE Electric's distribution system.
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 2015 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, FERC, MPSC, NRC, and 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;

3

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

• the timing and extent of changes in interest rates;

• the level of borrowings;

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

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

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

• unplanned outages;

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

• 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; 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.

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Part I — Financial Information

Item 1. Financial Statements

DTE Energy Company

Consolidated Statements of Operations (Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(In millions, except per share amounts)
Operating Revenues
Utility operations	$	1,435		$	1,357		$	3,099		$	3,198
Non-utility operations	827			911			1,729			2,054
	2,262			2,268			4,828			5,252
Operating Expenses
Fuel, purchased power, and gas — utility	414			434			979			1,127
Fuel, purchased power, and gas — non-utility	717			769			1,493			1,774
Operation and maintenance	542			532			1,058			1,058
Depreciation and amortization	243			220			472			429
Taxes other than income	91			91			190			191
Asset (gains) losses and impairments, net	(1		)	18			(1		)	8
	2,006			2,064			4,191			4,587
Operating Income	256			204			637			665
Other (Income) and Deductions
Interest expense	114			115			227			225
Interest income	(3		)	(2		)	(14		)	(6		)
Other income	(57		)	(49		)	(109		)	(100		)
Other expenses	7			9			15			19
	61			73			119			138
Income Before Income Taxes	195			131			518			527
Income Tax Expense	50			26			133			148
Net Income	145			105			385			379
Less: Net Loss Attributable to Noncontrolling Interests	(7		)	(4		)	(14		)	(3		)
Net Income Attributable to DTE Energy Company	$	152		$	109		$	399		$	382
Basic Earnings per Common Share
Net Income Attributable to DTE Energy Company	$	0.84		$	0.61		$	2.22		$	2.13
Diluted Earnings per Common Share
Net Income Attributable to DTE Energy Company	$	0.84		$	0.61		$	2.22		$	2.13
Weighted Average Common Shares Outstanding
Basic	179			179			179			179
Diluted	180			179			180			179
Dividends Declared per Common Share	$	0.73		$	0.69		$	1.46		$	1.38

See Combined Notes to Consolidated Financial Statements (Unaudited)

5

DTE Energy Company

Consolidated Statements of Comprehensive Income (Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(In millions)
Net Income	$	145		$	105		$	385		$	379
Other comprehensive income (loss), net of tax:
Benefit obligations, net of taxes of $(1), $2, $1, and $4, respectively	(1		)	3			2			6
Foreign currency translation	(1		)	1			1			(2		)
Other comprehensive income (loss)	(2		)	4			3			4
Comprehensive income	143			109			388			383
Less comprehensive loss attributable to noncontrolling interests	(7		)	(4		)	(14		)	(3		)
Comprehensive Income Attributable to DTE Energy Company	$	150		$	113		$	402		$	386

See Combined Notes to Consolidated Financial Statements (Unaudited)

6

DTE Energy Company

Consolidated Statements of Financial Position (Unaudited)

	June 30,			December 31,
	2016			2015
	(In millions)
ASSETS
Current Assets
Cash and cash equivalents	$	32		$	37
Restricted cash	22			23
Accounts receivable (less allowance for doubtful accounts of $42 and $49, respectively)
Customer	1,180			1,276
Other	82			72
Inventories
Fuel and gas	385			480
Materials and supplies	332			323
Derivative assets	53			129
Regulatory assets	11			32
Other	161			203
	2,258			2,575
Investments
Nuclear decommissioning trust funds	1,275			1,236
Investments in equity method investees	633			514
Other	193			186
	2,101			1,936
Property
Property, plant, and equipment	28,371			28,121
Less accumulated depreciation and amortization	(10,076		)	(10,087		)
	18,295			18,034
Other Assets
Goodwill	2,018			2,018
Regulatory assets	3,729			3,692
Intangible assets	97			89
Notes receivable	77			85
Derivative assets	35			54
Other	159			179
	6,115			6,117
Total Assets	$	28,769		$	28,662

See Combined Notes to Consolidated Financial Statements (Unaudited)

7

DTE Energy Company

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

	June 30,			December 31,
	2016			2015
	(In millions, except shares)
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	745		$	809
Accrued interest	91			89
Dividends payable	269			131
Short-term borrowings	175			499
Current portion long-term debt, including capital leases	165			473
Derivative liabilities	47			57
Gas inventory equalization	46			—
Regulatory liabilities	37			41
Other	308			429
	1,883			2,528
Long-Term Debt (net of current portion)
Mortgage bonds, notes, and other	8,551			8,265
Junior subordinated debentures	780			480
Capital lease obligations	12			15
	9,343			8,760
Other Liabilities
Deferred income taxes	4,026			3,923
Regulatory liabilities	572			569
Asset retirement obligations	2,238			2,194
Unamortized investment tax credit	93			62
Derivative liabilities	94			86
Accrued pension liability	1,136			1,133
Accrued postretirement liability	175			228
Nuclear decommissioning	184			177
Other	226			207
	8,744			8,579
Commitments and Contingencies (Notes 4 and 10)
Equity
Common stock, without par value, 400,000,000 shares authorized, and 179,435,004 and 179,470,213 shares issued and outstanding, respectively	4,129			4,123
Retained earnings	4,791			4,794
Accumulated other comprehensive loss	(142		)	(145		)
Total DTE Energy Company Equity	8,778			8,772
Noncontrolling interests	21			23
Total Equity	8,799			8,795
Total Liabilities and Equity	$	28,769		$	28,662

See Combined Notes to Consolidated Financial Statements (Unaudited)

8

DTE Energy Company

Consolidated Statements of Cash Flows (Unaudited)

	Six Months Ended June 30,
	2016			2015
Operating Activities	(In millions)
Net Income	$	385		$	379
Adjustments to reconcile Net Income to net cash from operating activities:
Depreciation and amortization	472			429
Nuclear fuel amortization	29			28
Allowance for equity funds used during construction	(10		)	(10		)
Deferred income taxes	134			148
Equity earnings of equity method investees	(35		)	(32		)
Dividends from equity method investees	33			30
Asset (gains) losses and impairments, net	—			8
Changes in assets and liabilities:
Accounts receivable, net	81			234
Inventories	86			73
Accounts payable	(10		)	(119		)
Gas inventory equalization	46			56
Accrued pension liability	3			(96		)
Accrued postretirement liability	(53		)	(192		)
Derivative assets and liabilities	93			48
Regulatory assets and liabilities	71			89
Other current and noncurrent assets and liabilities	(53		)	107
Net cash from operating activities	1,272			1,180
Investing Activities
Plant and equipment expenditures — utility	(797		)	(781		)
Plant and equipment expenditures — non-utility	(64		)	(114		)
Acquisition	—			(241		)
Proceeds from sale of assets	—			16
Restricted cash for debt redemption, principally Securitization, net	1			99
Proceeds from sale of nuclear decommissioning trust fund assets	741			440
Investment in nuclear decommissioning trust funds	(744		)	(446		)
Distributions from equity method investees	7			9
Contributions to equity method investees	(121		)	(32		)
Other	39			14
Net cash used for investing activities	(938		)	(1,036		)
Financing Activities
Issuance of long-term debt, net of issuance costs	588			793
Redemption of long-term debt	(313		)	(118		)
Short-term borrowings, net	(324		)	(398		)
Issuance of common stock	—			9
Repurchase of common stock	(33		)	—
Dividends on common stock	(262		)	(246		)
Other	5			(2		)
Net cash from (used for) financing activities	(339		)	38
Net Increase (Decrease) in Cash and Cash Equivalents	(5		)	182
Cash and Cash Equivalents at Beginning of Period	37			48
Cash and Cash Equivalents at End of Period	$	32		$	230
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	$	154		$	206

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, 2015	179,470		$	4,123		$	4,794		$	(145	)	$	23		$	8,795
Net Income (Loss)	—		—			399			—			(14		)	385
Dividends declared on common stock	—		—			(400		)	—			—			(400		)
Repurchase of common stock	(394	)	(33		)	—			—			—			(33		)
Benefit obligations, net of tax	—		—			—			2			—			2
Foreign currency translation	—		—			—			1			—			1
Stock-based compensation, net contributions from noncontrolling interests, and other	359		39			(2		)	—			12			49
Balance, June 30, 2016	179,435		$	4,129		$	4,791		$	(142	)	$	21		$	8,799

See Combined Notes to Consolidated Financial Statements (Unaudited)

10

DTE Electric Company

Consolidated Statements of Operations (Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(In millions)
Operating Revenues — Utility operations	$	1,215		$	1,147		$	2,368		$	2,350
Operating Expenses
Fuel and purchased power — utility	361			381			696			771
Operation and maintenance	332			319			656			636
Depreciation and amortization	187			165			363			320
Taxes other than income	70			68			143			141
	950			933			1,858			1,868
Operating Income	265			214			510			482
Other (Income) and Deductions
Interest expense	65			67			130			130
Interest income	—			—			(8		)	—
Other income	(17		)	(13		)	(33		)	(28		)
Other expenses	6			8			13			17
	54			62			102			119
Income Before Income Taxes	211			152			408			363
Income Tax Expense	76			53			146			127
Net Income	$	135		$	99		$	262		$	236

See Combined Notes to Consolidated Financial Statements (Unaudited)

11

DTE Electric Company

Consolidated Statements of Comprehensive Income (Unaudited)

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(In millions)
Net Income	$	135	$	99	$	262	$	236
Other comprehensive income, net of tax:
Transfer of benefit obligations, net of taxes of $— and $18 in 2015, respectively	—		—		—		28
Comprehensive income	$	135	$	99	$	262	$	264

See Combined Notes to Consolidated Financial Statements (Unaudited)

12

DTE Electric Company

Consolidated Statements of Financial Position (Unaudited)

	June 30,			December 31,
	2016			2015
	(In millions)
ASSETS
Current Assets
Cash and cash equivalents	$	13		$	15
Accounts receivable (less allowance for doubtful accounts of $24 and $28, respectively)
Customer	694			657
Affiliates	9			14
Other	34			40
Inventories
Fuel	233			271
Materials and supplies	264			251
Notes receivable
Affiliates	62			—
Other	5			—
Regulatory assets	9			17
Other	58			66
	1,381			1,331
Investments
Nuclear decommissioning trust funds	1,275			1,236
Other	31			35
	1,306			1,271
Property
Property, plant, and equipment	21,479			21,391
Less accumulated depreciation and amortization	(7,577		)	(7,646		)
	13,902			13,745
Other Assets
Regulatory assets	2,998			2,969
Intangible assets	47			34
Prepaid postretirement costs — affiliates	24			24
Other	121			144
	3,190			3,171
Total Assets	$	19,779		$	19,518

See Combined Notes to Consolidated Financial Statements (Unaudited)

13

DTE Electric Company

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

	June 30,		December 31,
	2016		2015
	(In millions, except shares)
LIABILITIES AND SHAREHOLDER’S EQUITY
Current Liabilities
Accounts payable
Affiliates	$	50	$	40
Other	313		329
Accrued interest	63		62
Accrued vacation	46		44
Current portion long-term debt, including capital leases	148		157
Regulatory liabilities	34		19
Short-term borrowings
Affiliates	108		75
Other	—		272
Other	74		94
	836		1,092
Long-Term Debt (net of current portion)
Mortgage bonds, notes, and other	5,735		5,437
Capital lease obligations	12		15
	5,747		5,452
Other Liabilities
Deferred income taxes	3,605		3,498
Regulatory liabilities	214		199
Asset retirement obligations	2,057		2,020
Unamortized investment tax credit	89		58
Nuclear decommissioning	184		177
Accrued pension liability — affiliates	981		976
Accrued postretirement liability — affiliates	273		307
Other	68		66
	7,471		7,301
Commitments and Contingencies (Notes 4 and 10)
Shareholder’s Equity
Common stock, $10 par value, 400,000,000 shares authorized, and 138,632,324 shares issued and outstanding	4,086		4,086
Retained earnings	1,637		1,585
Accumulated other comprehensive income	2		2
Total Shareholder’s Equity	5,725		5,673
Total Liabilities and Shareholder’s Equity	$	19,779	$	19,518

See Combined Notes to Consolidated Financial Statements (Unaudited)

14

DTE Electric Company

Consolidated Statements of Cash Flows (Unaudited)

	Six Months Ended June 30,
	2016			2015
	(In millions)
Operating Activities
Net Income	$	262		$	236
Adjustments to reconcile Net Income to net cash from operating activities:
Depreciation and amortization	363			320
Nuclear fuel amortization	29			28
Allowance for equity funds used during construction	(9		)	(10		)
Deferred income taxes	146			127
Changes in assets and liabilities:
Accounts receivable, net	(32		)	(43		)
Inventories	25			(15		)
Accounts payable	32			(28		)
Accrued pension liability — affiliates	5			(183		)
Accrued postretirement liability — affiliates	(34		)	(150		)
Regulatory assets and liabilities	82			38
Other current and noncurrent assets and liabilities	(44		)	48
Net cash from operating activities	825			368
Investing Activities
Plant and equipment expenditures	(640		)	(665		)
Acquisition	—			(241		)
Proceeds from the sale of assets	6			—
Restricted cash for debt redemption, principally Securitization, net	—			96
Notes receivable from affiliate	(62		)	8
Proceeds from sale of nuclear decommissioning trust fund assets	741			440
Investment in nuclear decommissioning trust funds	(744		)	(446		)
Transfer of Rabbi Trust assets to affiliate	—			137
Other	36			14
Net cash used for investing activities	(663		)	(657		)
Financing Activities
Issuance of long-term debt, net of issuance costs	297			495
Redemption of long-term debt	(10		)	(115		)
Capital contribution by parent company	—			300
Short-term borrowings, net — affiliate	33			(30		)
Short-term borrowings, net — other	(272		)	(50		)
Dividends on common stock	(210		)	(199		)
Other	(2		)	(3		)
Net cash from (used for) financing activities	(164		)	398
Net Increase (Decrease) in Cash and Cash Equivalents	(2		)	109
Cash and Cash Equivalents at Beginning of the Period	15			14
Cash and Cash Equivalents at End of the Period	$	13		$	123
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	$	112		$	154

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, 2015	138,632	$	1,386	$	2,700	$	1,585		$	2	$	5,673
Net Income	—	—		—		262			—		262
Dividends declared on common stock	—	—		—		(210		)	—		(210		)
Balance, June 30, 2016	138,632	$	1,386	$	2,700	$	1,637		$	2	$	5,725

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	Regulatory Matters	DTE Energy and DTE Electric
Note 5	Earnings per Share	DTE Energy
Note 6	Fair Value	DTE Energy and DTE Electric
Note 7	Financial and Other Derivative Instruments	DTE Energy and DTE Electric
Note 8	Long-Term Debt	DTE Energy and DTE Electric
Note 9	Short-Term Credit Arrangements and Borrowings	DTE Energy and DTE Electric
Note 10	Commitments and Contingencies	DTE Energy and DTE Electric
Note 11	Retirement Benefits and Trusteed Assets	DTE Energy and DTE Electric
Note 12	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 1.2 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 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 2015 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, 2016.

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. Such revisions include amounts reclassified to separate Operating Revenues and Fuel, purchased power, and gas between Utility operations and Non-utility operations and from Operations and maintenance to Fuel, purchased power, and gas — non-utility related to the Power and Industrial Projects segment. The reclassifications did not affect DTE Energy's Net Income for the prior periods, as such, they are not deemed material to the previously issued Consolidated Financial Statements. For reclassifications of debt issuance costs arising from ASU 2015-03, see Note 3 to the Consolidated Financial Statements, "New Accounting Pronouncements."

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 has variable interests in VIEs through certain of its long-term purchase and sale contracts. DTE Electric has variable interests in VIEs through certain of its long-term purchase contracts. As of June 30, 2016, the carrying amount of assets and liabilities in DTE Energy's Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase and sale contracts are predominantly related to working capital accounts and generally represent the amounts owed by or to DTE Energy for the deliveries associated with the current billing cycle under the contracts. As of June 30, 2016, 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 June 30, 2016 and December 31, 2015. 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.

	June 30, 2016		December 31, 2015
	(In millions)
ASSETS
Cash and cash equivalents	$	11	$	14
Restricted cash	6		8
Accounts receivable	29		18
Inventories	101		82
Property, plant, and equipment, net	59		66
Other current and long-term assets	2		4
	$	208	$	192
LIABILITIES
Accounts payable and accrued current liabilities	$	21	$	13
Current portion long-term debt, including capital leases	6		8
Mortgage bonds, notes, and other	7		10
Other current and long-term liabilities	6		6
	$	40	$	37

Amounts for DTE Energy's non-consolidated VIEs as of June 30, 2016 and December 31, 2015 are as follows:

	June 30, 2016		December 31, 2015
	(In millions)
Investment in equity method investees	$	195	$	136
Notes receivable	$	15	$	15
Future funding commitments	$	8	$	—

NOTE 2 — SIGNIFICANT ACCOUNTING POLICIES

Other Income

Other income for the Registrants is recognized for non-operating income such as equity earnings, allowance for equity funds used during construction, and contract services. DTE Energy's Power and Industrial Projects segment also recognizes Other income in connection with the sale of membership interests in reduced emissions fuel facilities to investors. In exchange for the cash received, the investors will receive a portion of the economic attributes of the facilities, including income tax attributes. The transactions are not treated as a sale of membership interests for financial reporting purposes. Other income is considered earned when refined coal is produced and tax credits are generated. Power and Industrial Projects recognized approximately $20 million of Other income for the three months ended June 30, 2016 and 2015, respectively, and approximately $39 million of Other income for the six months ended June 30, 2016 and 2015, respectively.

Changes in Accumulated Other Comprehensive Income (Loss)

For the three and six months endedJune 30, 2016 and 2015, 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.

19

DTE Energy Company — DTE Electric Company

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

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 June 30,				Six Months Ended June 30,				June 30,
	2016		2015		2016		2015		2016
									(In millions)
DTE Energy	26	%	20	%	26	%	28	%	$	3
DTE Electric	36	%	35	%	36	%	35	%	$	4

The 6%increase in DTE Energy's effective tax rate for the three months ended June 30, 2016 is primarily due to higher production tax credits in the second quarter of 2015.

DTE Energy had $2 million of unrecognized tax benefits that, if recognized, would favorably impact its effective tax rate. DTE Electric had $3 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 $8 million and $6 million at June 30, 2016 and December 31, 2015, respectively.

Unrecognized Compensation Costs

As of June 30, 2016, DTE Energy had $77 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 1.56 years.

Allocated Stock-Based Compensation

DTE Electric received an allocation of costs from DTE Energy associated with stock-based compensation of $9 million and $8 million for the three months ended June 30, 2016 and 2015, respectively while such allocation was $19 million and $12 million for the six months ended June 30, 2016 and 2015, respectively.

NOTE 3 — NEW ACCOUNTING PRONOUNCEMENTS

Recently Adopted Pronouncements

In February 2015, the FASB issued ASU No. 2015-02, Amendments to the Consolidation Analysis, which changes the analysis that a reporting entity must perform to determine whether it should consolidate certain types of legal entities. The ASU affects (1) limited partnerships and similar legal entities, (2) evaluating fees paid to a decision maker or a service provider as a variable interest, (3) the effect of fee arrangements on the primary beneficiary determination, (4) the effect of related parties on the primary beneficiary determination, and (5) certain investment funds. It is effective for the Registrants for the first interim period within annual reporting periods beginning after December 15, 2015. The Registrants adopted this ASU at January 1, 2016. The implementation of this guidance is reflected in Note 1 of the Consolidated Financial Statements, "Organization and Basis of Presentation." Certain entities are now deemed to be VIEs and are included in DTE Energy's non-consolidated VIE table. This implementation did not have a significant impact on the Registrants' Consolidated Financial Statements.

In April 2015, the FASB issued ASU No. 2015-03, Simplifying the Presentation of Debt Issuance Costs. This ASU requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. This ASU is effective for reporting periods beginning after December 15, 2015, and interim periods therein. It is to be applied retrospectively. The Registrants adopted this ASU at January 1, 2016. The effect of the adoption decreased assets and liabilities on DTE Energy’s and DTE Electric’s Consolidated Statements of Financial Position by $75 million and $36 million, respectively, at December 31, 2015.

20

DTE Energy Company — DTE Electric Company

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

In May 2015, the FASB issued ASU 2015-07, Fair Value Measurement (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent). This guidance removes the requirement to categorize within the fair value hierarchy all investments for which fair value is measured using the net asset value per share (or its equivalent) practical expedient. The guidance applies to investments for which there is not a readily determinable fair value (market quote) or the investment is in a mutual fund without a publicly available net asset value. It is effective for the Registrants for the first interim period within annual reporting periods beginning after December 15, 2015. It is to be applied retrospectively. The Registrants adopted this ASU at January 1, 2016. The implementation of this guidance is reflected in Note 6 of the Consolidated Financial Statements, "Fair Value." This implementation 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 are currently assessing the impact of the ASU, as amended on their Consolidated Financial Statements.

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 to be applied prospectively and early adoption is permitted. The ASU will not have a significant impact on the Registrants' Consolidated Financial Statements.

In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments — Overall: Recognition and Measurement of Financial Assets and Financial Liabilities. The new guidance is intended to improve the recognition and measurement of financial instruments. The ASU primarily impacts accounting for equity investments in unconsolidated entities (other than those accounted for using the equity method of accounting) and financial liabilities under the fair value option. Under the new guidance, equity investments will generally be measured at fair value, with subsequent changes in fair value recognized in net income. The ASU is effective for fiscal years and interim periods within those years beginning after December 15, 2017. Upon adoption, entities will be required to make a cumulative-effect adjustment to the Statements of Financial Position as of the beginning of the first reporting period in which the guidance is effective. Changes to the accounting for equity securities without a readily determinable fair value will be applied prospectively. The ASU will not have a significant impact on the Registrants' 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 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 March 2016, the FASB issued ASU No. 2016-09, Compensation— Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting. The ASU simplifies several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the Statements of Cash Flows. Under the new standard, income tax benefits and deficiencies are to be recognized in the income statement and the tax effects of exercised or vested awards should be treated as discrete items in the reporting period in which they occur. This provision is to be applied prospectively. Excess tax benefits should be recognized regardless of whether the benefit reduces taxes payable in the current period, along with any valuation allowance, on a modified retrospective basis as a cumulative-effect adjustment to the retained earnings as of the date of adoption. Excess tax benefits should be classified along with other income tax cash flows as an operating activity. This provision can be applied prospectively or retrospectively for all periods presented. The standard is effective for public entities for annual reporting periods beginning after December 15, 2016, and interim periods therein. Early adoption is permitted. The ASU will not have a significant impact on DTE Energy's 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.

NOTE 4 — 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. 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 10.3% to 10.5% on a capital structure of 50% equity and 50% debt. On July 1, 2016, DTE Electric filed an application with the MPSC for a $245 million self-implemented base rate increase effective August 1, 2016. A final MPSC order in this case is expected by February 2017.

2015 DTE Gas Rate Case Filing

DTE Gas filed a rate case with the MPSC on December 18, 2015 requesting an increase in base rates of $183 million, inclusive of $41 million of existing IRM surcharges which are expected to be converted into base rates, based on a projected twelve-month period ending October 31, 2017. The requested increase in base rates is due primarily to an increase in net plant, inclusive of IRM capital investments being recovered through approved IRM surcharge filings. 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 10.5% to 10.75% on a capital structure of 52% equity and 48% debt. Concurrent with the MPSC order in this rate case, the existing IRM surcharge being billed will be terminated. However, DTE Gas requested to implement a new IRM surcharge of approximately $9 million to become effective in January 2017. On May 11, 2016, DTE Gas filed an application with the MPSC for a $103 million self-implemented base rate increase effective November 1, 2016. A final MPSC order in this case is expected by December 2016.

22

DTE Energy Company — DTE Electric Company

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

NOTE 5 — 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. 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 for the three and six months endedJune 30:

	Three Months Ended June 30,					Six Months Ended June 30,
	2016		2015			2016		2015
	(In millions, except per share amounts)
Basic Earnings per Share
Net Income Attributable to DTE Energy Company	$	152	$	109		$	399	$	382
Average number of common shares outstanding	179		179			179		179
Dividends declared — common shares	$	131	$	124		$	261	$	247
Dividends declared — net restricted shares	—		—			1		1
Total distributed earnings	$	131	$	124		$	262	$	248
Net Income less distributed earnings	$	21	$	(15	)	$	137	$	134
Distributed (dividends per common share)	$	0.73	$	0.69		$	1.46	$	1.38
Undistributed	0.11		(0.08		)	0.76		0.75
Total Basic Earnings per Common Share	$	0.84	$	0.61		$	2.22	$	2.13
Diluted Earnings per Share
Net Income Attributable to DTE Energy Company	$	152	$	109		$	399	$	382
Average number of common shares outstanding	179		179			179		179
Average incremental shares from assumed exercise of options	1		—			1		—
Common shares for dilutive calculation	180		179			180		179
Dividends declared — common shares	$	131	$	124		$	261	$	247
Dividends declared — net restricted shares	—		—			1		1
Total distributed earnings	$	131	$	124		$	262	$	248
Net Income less distributed earnings	$	21	$	(15	)	$	137	$	134
Distributed (dividends per common share)	$	0.73	$	0.69		$	1.46	$	1.38
Undistributed	0.11		(0.08		)	0.76		0.75
Total Diluted Earnings per Common Share	$	0.84	$	0.61		$	2.22	$	2.13

NOTE 6 — FAIR VALUE

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable inputs. The Registrants make certain assumptions they believe that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. Credit risk of the Registrants and their counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at June 30, 2016 and December 31, 2015. The Registrants believe they use valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.

23

DTE Energy Company — DTE Electric Company

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

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.

24

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 as of June 30, 2016 and December 31, 2015:

	June 30, 2016																	December 31, 2015
	Level 1			Level 2			Level 3			Other (a)		Netting (b)			Net Balance			Level 1			Level 2			Level 3			Other (a)		Netting (b)			Net Balance
	(In millions)
Assets:
Cash equivalents (c)	$	6		$	3		$	—		$	—	$	—		$	9		$	13		$	3		$	—		$	—	$	—		$	16
Nuclear decommissioning trusts	853			422			—			—		—			1,275			759			473			—			4		—			1,236
Other investments (d)	159			—			—			—		—			159			149			—			—			—		—			149
Derivative assets:
Commodity Contracts:
Natural Gas	171			65			62			—		(248		)	50			193			91			103			—		(285		)	102
Electricity	—			196			43			—		(207		)	32			—			239			68			—		(232		)	75
Other	1			2			4			—		(2		)	5			2			—			3			—		(2		)	3
Foreign currency exchange contracts	—			6			—			—		(5		)	1			—			12			—			—		(9		)	3
Total derivative assets	172			269			109			—		(462		)	88			195			342			174			—		(528		)	183
Total	$	1,190		$	694		$	109		$	—	$	(462	)	$	1,531		$	1,116		$	818		$	174		$	4	$	(528	)	$	1,584
Liabilities:
Derivative liabilities:
Commodity Contracts:
Natural Gas	$	(193	)	$	(58	)	$	(124	)	$	—	$	263		$	(112	)	$	(218	)	$	(57	)	$	(108	)	$	—	$	294		$	(89	)
Electricity	—			(191		)	(49		)	—		212			(28		)	—			(243		)	(62		)	—		253			(52		)
Other	(3		)	(3		)	(5		)	—		10			(1		)	(2		)	—			(8		)	—		8			(2		)
Foreign currency exchange contracts	—			(3		)	—			—		3			—			—			(7		)	—			—		7			—
Total derivative liabilities	(196		)	(255		)	(178		)	—		488			(141		)	(220		)	(307		)	(178		)	—		562			(143		)
Total	$	(196	)	$	(255	)	$	(178	)	$	—	$	488		$	(141	)	$	(220	)	$	(307	)	$	(178	)	$	—	$	562		$	(143	)
Net Assets (Liabilities) at the end of the period	$	994		$	439		$	(69	)	$	—	$	26		$	1,390		$	896		$	511		$	(4	)	$	4	$	34		$	1,441
Assets:
Current	$	151		$	220		$	67		$	—	$	(376	)	$	62		$	174		$	284		$	128		$	—	$	(441	)	$	145
Noncurrent	1,039			474			42			—		(86		)	1,469			942			534			46			4		(87		)	1,439
Total Assets	$	1,190		$	694		$	109		$	—	$	(462	)	$	1,531		$	1,116		$	818		$	174		$	4	$	(528	)	$	1,584
Liabilities:
Current	$	(166	)	$	(204	)	$	(72	)	$	—	$	395		$	(47	)	$	(174	)	$	(260	)	$	(87	)	$	—	$	464		$	(57	)
Noncurrent	(30		)	(51		)	(106		)	—		93			(94		)	(46		)	(47		)	(91		)	—		98			(86		)
Total Liabilities	$	(196	)	$	(255	)	$	(178	)	$	—	$	488		$	(141	)	$	(220	)	$	(307	)	$	(178	)	$	—	$	562		$	(143	)
Net Assets (Liabilities) at the end of the period	$	994		$	439		$	(69	)	$	—	$	26		$	1,390		$	896		$	511		$	(4	)	$	4	$	34		$	1,441

_______________________________________

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

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

(c) At June 30, 2016, available-for-sale securities of $9 million included $6 million and $3 million of cash equivalents included in Restricted cash and Other investments on DTE Energy's Consolidated Statements of Financial Position, respectively. At December 31, 2015, available-for-sale securities of $16 million, included $8 million and $8 million of cash equivalents included in Restricted cash and Other investments on DTE Energy's Consolidated Statements of Financial Position, respectively.

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

25

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 June 30, 2016 and December 31, 2015:

	June 30, 2016										December 31, 2015
	Level 1		Level 2		Level 3		Other (a)		Net Balance		Level 1		Level 2		Level 3		Other (a)		Net Balance
	(In millions)
Assets:
Cash equivalents (b)	$	—	$	3	$	—	$	—	$	3	$	5	$	3	$	—	$	—	$	8
Nuclear decommissioning trusts	853		422		—		—		1,275		759		473		—		4		1,236
Other investments	8		—		—		—		8		8		—		—		—		8
Derivative assets — FTRs	—		—		4		—		4		—		—		3		—		3
Total	$	861	$	425	$	4	$	—	$	1,290	$	772	$	476	$	3	$	4	$	1,255
Assets:
Current	$	—	$	3	$	4	$	—	$	7	$	5	$	3	$	3	$	—	$	11
Noncurrent	861		422		—		—		1,283		767		473		—		4		1,244
Total Assets	$	861	$	425	$	4	$	—	$	1,290	$	772	$	476	$	3	$	4	$	1,255

_______________________________________

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

(b) At June 30, 2016, available-for-sale securities of $3 million consisted of cash equivalents included in Other investments on DTE Electric's Consolidated Statements of Financial Position. At December 31, 2015, available-for-sale securities of $8 million consisted of cash equivalents included in Other investments on DTE Electric's Consolidated Statements of Financial Position.

Cash Equivalents

Cash equivalents include investments with maturities of three months or less when purchased. The cash equivalents shown in the fair value table are comprised of short-term investments and money market funds.

Nuclear Decommissioning Trusts and Other Investments

The nuclear decommissioning trusts and other investments hold debt and equity securities directly and indirectly through 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. The commingled funds hold exchange-traded equity or debt securities (exchange and non-exchange traded) and are valued based on a calculated NAV as a practical expedient. 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.

26

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 tables present the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for DTE Energy for the three and six months endedJune 30, 2016 and 2015:

	Three Months Ended June 30, 2016												Three Months Ended June 30, 2015
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of March 31	$	(34	)	$	(16	)	$	(7	)	$	(57	)	$	—		$	(7	)	$	(5	)	$	(12	)
Transfers into Level 3 from Level 2	—			—			—			—			—			—			—			—
Transfers from Level 3 into Level 2	—			—			—			—			—			—			—			—
Total gains (losses):
Included in earnings	(36		)	12			2			(22		)	(5		)	18			1			14
Recorded in Regulatory liabilities	—			—			6			6			—			—			13			13
Purchases, issuances, and settlements:
Purchases	—			1			—			1			—			1			—			1
Settlements	8			(3		)	(2		)	3			(3		)	(9		)	(8		)	(20		)
Net Assets (Liabilities) as of June 30	$	(62	)	$	(6	)	$	(1	)	$	(69	)	$	(8	)	$	3		$	1		$	(4	)
The amount of total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at June 30, 2016 and 2015 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	$	(41	)	$	(4	)	$	2		$	(43	)	$	(20	)	$	15		$	1		$	(4	)

27

DTE Energy Company — DTE Electric Company

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

	Six Months Ended June 30, 2016												Six Months Ended June 30, 2015
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of December 31	$	(5	)	$	6		$	(5	)	$	(4	)	$	30		$	(5	)	$	(1	)	$	24
Transfers into Level 3 from Level 2	—			—			—			—			—			—			—			—
Transfers from Level 3 into Level 2	(1		)	—			—			(1		)	—			—			—			—
Total gains (losses):
Included in earnings	(56		)	(46		)	1			(101		)	(35		)	24			(2		)	(13		)
Recorded in Regulatory liabilities	—			—			4			4			—			—			11			11
Purchases, issuances, and settlements:
Purchases	—			1			—			1			—			2			—			2
Settlements	—			33			(1		)	32			(3		)	(18		)	(7		)	(28		)
Net Assets (Liabilities) as of June 30	$	(62	)	$	(6	)	$	(1	)	$	(69	)	$	(8	)	$	3		$	1		$	(4	)
The amount of total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at June 30, 2016 and 2015 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	$	(113	)	$	(7	)	$	1		$	(119	)	$	(112	)	$	11		$	(1	)	$	(102	)

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 for the three and six months endedJune 30, 2016 and 2015:

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(In millions)
Net Assets as of beginning of period	$	1		$	1		$	3		$	3
Change in fair value recorded in Regulatory liabilities	6			13			4			11
Purchases, issuances, and settlements:
Settlements	(3		)	(9		)	(3		)	(9		)
Net Assets as of June 30	$	4		$	5		$	4		$	5
The amount of total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets held at June 30, 2016 and 2015 and reflected in DTE Electric's Consolidated Statements of Financial Position	$	4		$	5		$	4		$	5

Derivatives are transferred between levels primarily due to changes in the source data used to construct price curves as a result of changes in market liquidity. Transfers in and transfers out are reflected as if they had occurred at the beginning of the period.

There were no transfers between Levels 1 and 2 for the Registrants during the three and six months endedJune 30, 2016 and 2015, and there were no transfers from or into Level 3 for DTE Electric during the same periods.

28

DTE Energy Company — DTE Electric Company

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

The following tables present the unobservable inputs related to DTE Energy's Level 3 assets and liabilities as of June 30, 2016 and December 31, 2015:

	June 30, 2016
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range						Weighted Average
	(In millions)
Natural Gas	$	62	$	(124	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.36	) —	$	3.68	/MMBtu	$	(0.10	)/MMBtu
Electricity	$	43	$	(49	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(14	) —	$	13	/MWh	$	1	/MWh

	December 31, 2015
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range						Weighted Average
	(In millions)
Natural Gas	$	103	$	(108	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.50	) —	$	2.77	/MMBtu	$	(0.19	)/MMBtu
Electricity	$	68	$	(62	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(11	) —	$	14	/MWh	$	2	/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, 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.

The following table presents the carrying amount and fair value of financial instruments for DTE Energy as of June 30, 2016 and December 31, 2015:

	June 30, 2016								December 31, 2015
	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	$	32	$	—	$	—	$	32	$	32	$	—	$	—	$	32
Dividends payable	$	269	$	269	$	—	$	—	$	131	$	131	$	—	$	—
Short-term borrowings	$	175	$	—	$	175	$	—	$	499	$	—	$	499	$	—
Long-term debt, excluding capital leases	$	9,488	$	807	$	8,538	$	1,438	$	9,210	$	496	$	8,136	$	1,203

29

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 Electric as of June 30, 2016 and December 31, 2015:

	June 30, 2016								December 31, 2015
	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	$	5	$	—	$	—	$	5
Notes receivable — affiliates	$	62	$	—	$	—	$	62	$	—	$	—	$	—	$	—
Short-term borrowings — affiliates	$	108	$	—	$	—	$	108	$	75	$	—	$	—	$	75
Short-term borrowings — other	$	—	$	—	$	—	$	—	$	272	$	—	$	272	$	—
Long-term debt, excluding capital leases	$	5,877	$	—	$	5,999	$	755	$	5,588	$	—	$	5,432	$	545

For further fair value information on financial and derivative instruments, see Note 7 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 ARO on DTE Electric's Consolidated Statements of Financial Position. Rates approved by the MPSC provide for the recovery of decommissioning costs of Fermi 2 and the disposal of low-level radioactive waste.

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

	June 30, 2016		December 31, 2015
	(In millions)
Fermi 2	$	1,247	$	1,211
Fermi 1	3		3
Low-level radioactive waste	25		22
Total	$	1,275	$	1,236

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

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(In millions)
Realized gains	$	37		$	13		$	46		$	22
Realized losses	$	(25	)	$	(5	)	$	(40	)	$	(12	)
Proceeds from sales of securities	$	481		$	194		$	741		$	440

30

DTE Energy Company — DTE Electric Company

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

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:

	June 30, 2016							December 31, 2015
	Fair Value		Unrealized Gains		Unrealized Losses			Fair Value		Unrealized Gains		Unrealized Losses
	(In millions)
Equity securities	$	831	$	180	$	(53	)	$	731	$	195	$	(68	)
Debt securities	438		29		(2		)	499		16		(4		)
Cash and cash equivalents	6		—		—			6		—		—
	$	1,275	$	209	$	(55	)	$	1,236	$	211	$	(72	)

The debt securities at June 30, 2016 and December 31, 2015 had an average maturity of approximately 7 and 6 years, respectively. 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 June 30, 2016 and December 31, 2015, 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 and six months endedJune 30, 2016 and 2015. Gains related to trading securities held at June 30, 2016 and June 30, 2015 were $10 million and $1 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.

NOTE 7 — 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.

31

DTE Energy Company — DTE Electric Company

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

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 2019. 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 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 June 30, 2016 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.

32

DTE Energy Company — DTE Electric Company

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

• 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 as of June 30, 2016 and December 31, 2015 for DTE Energy:

	June 30, 2016					December 31, 2015
	Derivative Assets		Derivative Liabilities			Derivative Assets		Derivative Liabilities
	(In millions)
Derivatives not designated as hedging instruments:
Commodity Contracts:
Natural Gas	$	298	$	(375	)	$	387	$	(383	)
Electricity	239		(240		)	307		(305		)
Other	7		(11		)	5		(10		)
Foreign currency exchange contracts	6		(3		)	12		(7		)
Total derivatives not designated as hedging instruments:	$	550	$	(629	)	$	711	$	(705	)
Current	$	429	$	(442	)	$	570	$	(521	)
Noncurrent	121		(187		)	141		(184		)
Total derivatives	$	550	$	(629	)	$	711	$	(705	)

The following table presents the fair value of derivative instruments as of June 30, 2016 and December 31, 2015 for DTE Electric:

	June 30, 2016		December 31, 2015
	(In millions)
FTRs — Other current assets	$	4	$	3
Total derivatives not designated as hedging instrument	$	4	$	3

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

DTE Energy also provides and receives collateral in the form of letters of credit which can be offset against net Derivative assets and liabilities as well as Accounts receivable and payable. DTE Energy had issued letters of credit of approximately $5 million and $7 million outstanding at June 30, 2016 and December 31, 2015, respectively, which could be used to offset net Derivative liabilities. Letters of credit received from third parties which could be used to offset net Derivative assets were $1 million and $2 million at June 30, 2016 and December 31, 2015, 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.

33

DTE Energy Company — DTE Electric Company

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

For DTE Energy, the total cash collateral posted, net of cash collateral received, was $40 million and $37 million as of June 30, 2016 and December 31, 2015, respectively. DTE Energy had $6 million of cash collateral related to unrealized positions to net against Derivative assets while Derivative liabilities are shown net of cash collateral of $32 million as of June 30, 2016. DTE Energy had $2 million of cash collateral related to unrealized positions to net against Derivative assets while Derivative liabilities are shown net of cash collateral of $36 million as of December 31, 2015. DTE Energy recorded cash collateral paid of $16 million and cash collateral received of $2 million not related to unrealized derivative positions as of June 30, 2016. DTE Energy recorded cash collateral paid of $6 million and cash collateral received of $3 million not related to unrealized derivative positions as of December 31, 2015. 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 at June 30, 2016 and December 31, 2015:

	June 30, 2016									December 31, 2015
	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	$	298		$	(248	)	$	50		$	387		$	(285	)	$	102
Electricity	239			(207		)	32			307			(232		)	75
Other	7			(2		)	5			5			(2		)	3
Foreign currency exchange contracts	6			(5		)	1			12			(9		)	3
Total derivative assets	$	550		$	(462	)	$	88		$	711		$	(528	)	$	183
Derivative liabilities:
Commodity Contracts:
Natural Gas	$	(375	)	$	263		$	(112	)	$	(383	)	$	294		$	(89	)
Electricity	(240		)	212			(28		)	(305		)	253			(52		)
Other	(11		)	10			(1		)	(10		)	8			(2		)
Foreign currency exchange contracts	(3		)	3			—			(7		)	7			—
Total derivative liabilities	$	(629	)	$	488		$	(141	)	$	(705	)	$	562		$	(143	)

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 at June 30, 2016 and December 31, 2015:

	June 30, 2016												December 31, 2015
	Derivative Assets						Derivative Liabilities						Derivative Assets						Derivative Liabilities
	Current			Noncurrent			Current			Noncurrent			Current			Noncurrent			Current			Noncurrent
	(In millions)
Total fair value of derivatives	$	429		$	121		$	(442	)	$	(187	)	$	570		$	141		$	(521	)	$	(184	)
Counterparty netting	(372		)	(84		)	372			84			(441		)	(85		)	441			85
Collateral adjustment	(4		)	(2		)	23			9			—			(2		)	23			13
Total derivatives as reported	$	53		$	35		$	(47	)	$	(94	)	$	129		$	54		$	(57	)	$	(86	)

34

DTE Energy Company — DTE Electric Company

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

The effect of derivatives not designated as hedging instruments on DTE Energy's Consolidated Statements of Operations for the three and six months endedJune 30, 2016 and 2015 for DTE Energy 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 June 30,						Gain (Loss) Recognized in Income on Derivatives for the Six Months Ended June 30,
		2016			2015			2016			2015
		(In millions)
Commodity Contracts:
Natural Gas	Operating Revenues — Non-utility operations	$	(30	)	$	(4	)	$	(86	)	$	(130	)
Natural Gas	Fuel, purchased power, and gas — non-utility	(9		)	12			32			33
Electricity	Operating Revenues — Non-utility operations	19			15			(5		)	46
Other	Operating Revenues — Non-utility operations	—			2			(2		)	—
Foreign currency exchange contracts	Operating Revenues — Non-utility operations	1			—			(4		)	1
Total		$	(19	)	$	25		$	(65	)	$	(50	)

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

The following represents the cumulative gross volume of DTE Energy's derivative contracts outstanding as of June 30, 2016:

Commodity	Number of Units
Natural Gas (MMBtu)	1,838,453,487
Electricity (MWh)	37,370,289
Oil (Gallons)	18,102,000
Foreign Currency Exchange (Canadian dollars)	80,449,368

Various subsidiaries of DTE Energy have entered into contracts which contain ratings triggers and are guaranteed by DTE Energy. These contracts contain provisions which allow the counterparties to require that DTE Energy post cash or letters of credit as collateral in the event that DTE Energy’s credit rating is downgraded below investment grade. Certain of these provisions (known as “hard triggers”) state specific circumstances under which DTE Energy can be required to post collateral upon the occurrence of a credit downgrade, while other provisions (known as “soft triggers”) are not as specific. For contracts with soft triggers, it is difficult to estimate the amount of collateral which may be requested by counterparties and/or which DTE Energy may ultimately be required to post. The amount of such collateral which could be requested fluctuates based on commodity prices (primarily natural gas, power, and coal) and the provisions and maturities of the underlying transactions. As of June 30, 2016, 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 $322 million.

As of June 30, 2016, DTE Energy had approximately $482 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 $425 million. The net remaining amount of approximately $57 million is derived from the $322 million noted above.

NOTE 8 — LONG-TERM DEBT

Debt Issuances

In 2016, the following debt was issued:

Company	Month	Type	Interest Rate	Maturity	Amount
					(In millions)
DTE Electric	May	Mortgage Bonds	3.70%	2046	$	300
DTE Energy	May	Junior Subordinated Debentures	5.375%	2076	300
					$	600

Debt Redemptions

In 2016, the following debt was redeemed:

Company	Month	Type	Interest Rate	Maturity	Amount
					(In millions)
DTE Electric	March	Mortgage Bonds	7.904%	2016	$	10
DTE Energy	June	Senior Notes	6.35%	2016	300
DTE Energy	Various	Other Long-Term Debt	Various	2016	3
					$	313

NOTE 9 — SHORT-TERM CREDIT ARRANGEMENTS AND BORROWINGS

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

The agreements require DTE Energy, DTE Electric, and DTE Gas to maintain a total funded debt to capitalization ratio of no more than 0.65 to 1. In the agreements, “total funded debt” means all indebtedness of each respective company and their consolidated subsidiaries, including capital lease obligations, hedge agreements, and guarantees of third parties’ debt, but excluding contingent obligations, nonrecourse and junior subordinated debt, and certain equity-linked securities and, except for calculations at the end of the second quarter, certain DTE Gas short-term debt. “Capitalization” means the sum of (a) total funded debt plus (b) “consolidated net worth,” which is equal to consolidated total equity of each respective company and their consolidated subsidiaries (excluding pension effects under certain FASB statements), as determined in accordance with accounting principles generally accepted in the United States of America. At June 30, 2016, the total funded debt to total capitalization ratios for DTE Energy, DTE Electric, and DTE Gas were 0.50 to 1, 0.51 to 1, and 0.44 to 1, respectively, and were in compliance with this financial covenant.

35

DTE Energy Company — DTE Electric Company

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

The availability under the facilities in place at June 30, 2016 is shown in the following table:

	DTE Energy		DTE Electric		DTE Gas		Total
	(In millions)
Unsecured letter of credit facility, expiring in February 2017	$	100	$	—	$	—	$	100
Unsecured letter of credit facility, expiring in September 2017	70		—		—		70
Unsecured revolving credit facility, expiring April 2021	1,200		400		300		1,900
	1,370		400		300		2,070
Amounts outstanding at June 30, 2016
Commercial paper issuances	175		—		—		175
Letters of credit	139		—		—		139
	314		—		—		314
Net availability at June 30, 2016	$	1,056	$	400	$	300	$	1,756

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 June 30, 2016, 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 $63 million and $103 million at June 30, 2016 and December 31, 2015, respectively, and was fully offset by the posted collateral.

NOTE 10 — 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 sulfur dioxide and nitrogen oxides. The EPA and the State of Michigan have 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 nitrogen oxide, sulfur dioxide, mercury and other emissions. Additional rulemakings are expected over the next few years which could require additional controls for sulfur dioxide, nitrogen oxides, and hazardous air pollutants.

The Mercury and Air Toxics Standards (MATS) rule, formerly known as the Electric Generating Unit Maximum Achievable Control Technology (EGU MACT) Rule was finalized in December 2011. The MATS rule required reductions of mercury and other hazardous air pollutants beginning in April 2015. DTE Electric requested and was granted compliance date extensions for all relevant units to April 2016. In November 2014, the U.S. Supreme Court agreed to review a challenge to the MATS rule based on a narrowly focused question of how the EPA considered costs in regulating air pollutants emitted by electric utilities. In June 2015, the U.S. Supreme Court reversed the decision of the Court of Appeals for the D.C. District and remanded the MATS rule to the Court of Appeals for further consideration based on their decision that the EPA must consider costs prior to deciding to regulate under the provisions of the Clean Air Act. Subsequently, in December 2015, the Court of Appeals ordered a remand of the MATS rule back to the EPA without staying the rule. A petition to the U.S. Supreme Court for review of the D.C. Circuit’s remand of the rule was denied in April 2016, leaving the MATS rule in place. DTE Electric is currently operating in compliance with the rule at all regulated units. Although various issues surrounding the MATS rule remain subject to litigation in the D.C. Circuit, at this time DTE Electric does not expect future decisions to have a material effect on its compliance program.

36

DTE Energy Company — DTE Electric Company

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

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 are 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.

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 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 is implementing 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 electric generating units (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. 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.

To comply with air pollution requirements, DTE Electric spent approximately $2.3 billion through 2015. DTE Electric estimates making capital expenditures of approximately $45 million in 2016.

Coal Combustion Residuals and Effluent Limitations Guidelines — A final EPA rule for the disposal of coal combustion residuals, commonly known as coal ash, became effective in October 2015. 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. At other facilities, the rule requires ash laden waters be moved from earthen basins to steel and concrete tanks.

37

DTE Energy Company — DTE Electric Company

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

In November 2015, the EPA finalized effluent limitations guidelines 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. No new permits have been issued, consequently no compliance timelines have been established. Certain effluent limitations guidelines requirements will be required to be performed in conjunction with the coal combustion residuals requirements. Costs associated with the building of new facilities over the next seven years to comply with coal combustion residuals requirements and effluent limitations guidelines are estimated to be approximately $280 million.

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 five of the MGP sites is complete and the sites are closed. DTE Gas has also completed partial closure of three additional sites. Cleanup activities associated with the remaining sites will continue over the next several years. The MPSC has established a cost deferral and rate recovery mechanism for investigation and remediation costs incurred at former MGP sites. In addition to the MGP sites, DTE Gas is also in the process of cleaning up other contaminated sites, including gate stations, gas pipeline releases, and underground storage tank locations. As of June 30, 2016 and December 31, 2015, DTE Gas had $38 million and $22 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.

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 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.

In January 2016, the Yolo Solano County Health Department in California with the District Attorney issued subpoenas to investigate 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 power generation facility. We are currently working with the County Health Department and District Attorney's office to sample the beneficially reused ash and appropriately manage it according to the results. Additional reviews are being conducted to verify if biomass ash sent to landfills was properly characterized and managed. The Woodland Companies are currently negotiating a settlement with the District Attorney. As of June 30, 2016, DTE Energy had $3 million accrued for this matter. Changes in estimated remediation and settlement costs, if any, that occur upon completion of the investigation are not expected to have a material impact on DTE Energy’s Consolidated Financial Statements.

Riverview Energy Systems, LLC, a 50% owned landfill gas recovery facility, received a NOV in May 2015 due to stack test and landfill gas sample results exceeding permitting levels for sulfur.  A permit application to correct issues has been submitted, and a consent order was negotiated with the MDEQ. The consent order requires Riverview Energy Systems to pay $375,000 and install a sulfur control system.

The Shenango coke battery received two NOVs from the Pennsylvania Department of Environmental Protection (PADEP) in 2010 alleging violations of the permit for the Pennsylvania coke battery facility in connection with coal pile storm water runoff. DTE Energy settled the alleged violations by implementing best management practices to address the issues and repair/upgrade its wastewater treatment plant. DTE Energy received a construction permit to upgrade its existing waste water treatment system. Due to the December 2015 decision to close the Shenango coke battery in January 2016, DTE Energy will not proceed with the upgrade to its wastewater treatment system.

38

DTE Energy Company — DTE Electric Company

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

The decision to close the Shenango facility has prompted the PADEP, the EPA, and the Allegheny County, PA Health Department to submit demand letters under the 2012 consent decree for stipulated penalties related to water and air matters since 2012. The stipulated penalties totaling $534,000 have been accrued of which $190,000 remained unpaid as of June 30, 2016. DTE Energy is currently working with the respective regulatory agencies to settle all matters.

Nuclear Operations

Nuclear Fuel Disposal Costs

DTE Electric currently employs a spent nuclear fuel storage strategy utilizing a fuel pool and a newly completed dry cask storage facility. The dry cask storage facility is expected to provide sufficient spent fuel storage capability for the life of the plant as defined by the original operating license.

The federal government continues to maintain its legal obligation to accept spent nuclear fuel from Fermi 2 for permanent storage. Issues relating to long-term waste disposal policy and to the disposition of funds contributed by DTE Electric ratepayers to the federal waste fund await future governmental action.

Synthetic Fuel Guarantees

DTE Energy discontinued the operations of its synthetic fuel production facilities throughout the United States as of December 31, 2007. DTE Energy provided certain guarantees and indemnities in conjunction with the sales of interests in its synfuel facilities. The guarantees cover potential commercial, environmental, oil price, and tax-related obligations that will survive until 90 days after expiration of all applicable statutes of limitations. DTE Energy estimates that its maximum potential liability under these guarantees at June 30, 2016 is approximately $850 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 June 30, 2016 is approximately $323 million. Payment under these guarantees is 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 June 30, 2016. 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 June 30, 2016, DTE Energy had approximately $54 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.

Bankruptcies

Certain of the Registrants' customers and suppliers have filed for bankruptcy protection under the U.S. Bankruptcy Code. The Registrants regularly review contingent matters relating to these customers and suppliers and their purchase and sale 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.

39

DTE Energy Company — DTE Electric Company

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

Other Contingencies

The Registrants are involved in certain other legal, regulatory, administrative, and environmental proceedings before various courts, arbitration panels, and governmental agencies concerning claims arising in the ordinary course of business. These proceedings include certain contract disputes, additional environmental reviews and investigations, audits, inquiries from various regulators, and pending judicial matters. The Registrants cannot predict the final disposition of such proceedings. The Registrants regularly review legal matters and record provisions for claims that they can estimate and are considered probable of loss. The resolution of these pending proceedings is not expected to have a material effect on the Registrants' Consolidated Financial Statements in the periods they are resolved.

For a discussion of contingencies related to regulatory matters and derivatives, see Notes 4 and 7 to the Consolidated Financial Statements, "Regulatory Matters" and "Financial and Other Derivative Instruments," respectively.

NOTE 11 — 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
	2016			2015			2016			2015
Three Months Ended June 30,	(In millions)
Service cost	$	23		$	24		$	7		$	8
Interest cost	55			53			20			21
Expected return on plan assets	(78		)	(74		)	(32		)	(32		)
Amortization of:
Net actuarial loss	41			52			8			11
Prior service credit	—			—			(29		)	(32		)
Net periodic benefit cost (credit)	$	41		$	55		$	(26	)	$	(24	)

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
Six Months Ended June 30,	(In millions)
Service cost	$	46		$	49		$	13		$	17
Interest cost	109			106			40			41
Expected return on plan assets	(155		)	(148		)	(64		)	(65		)
Amortization of:
Net actuarial loss	81			103			16			22
Prior service credit	—			—			(59		)	(63		)
Net periodic benefit cost (credit)	$	81		$	110		$	(54	)	$	(48	)

40

DTE Energy Company — DTE Electric Company

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

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
	2016			2015			2016			2015
Three Months Ended June 30,	(In millions)
Service cost	$	17		$	18		$	5		$	6
Interest cost	42			41			16			15
Expected return on plan assets	(55		)	(52		)	(22		)	(22		)
Amortization of:
Net actuarial loss	28			36			5			8
Prior service cost (credit)	1			1			(22		)	(23		)
Net periodic benefit cost (credit)	$	33		$	44		$	(18	)	$	(16	)

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
Six Months Ended June 30,	(In millions)
Service cost	$	35		$	38		$	10		$	13
Interest cost	83			81			31			31
Expected return on plan assets	(110		)	(105		)	(45		)	(45		)
Amortization of:
Net actuarial loss	57			74			11			16
Prior service cost (credit)	1			1			(44		)	(47		)
Net periodic benefit cost (credit)	$	66		$	89		$	(37	)	$	(32	)

Pension and Other Postretirement Contributions

At the discretion of management, DTE Energy may make contributions up to $175 million, including contributions from DTE Electric of $145 million, to its pension plans in 2016.

At the discretion of management, DTE Energy may make contributions up to $20 million, through contributions from DTE Gas, to its other postretirement benefit plans in 2016.

NOTE 12 — 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 1.2 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, and holds certain non-utility debt and energy-related investments.

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DTE Energy Company — DTE Electric Company

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

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

Inter-segment billing for goods and services exchanged between segments is based upon tariffed or market-based prices of the provider and primarily consists of the sale of reduced emissions fuel, power sales, and natural gas sales in the following segments:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(In millions)
Inter-segment Revenues
Electric	$	8	$	9	$	17	$	18
Gas	3		—		3		1
Gas Storage and Pipelines	3		5		5		6
Power and Industrial Projects	150		215		298		395
Energy Trading	8		7		18		16
Corporate and Other	2		—		2		1
	$	174	$	236	$	343	$	437

Financial data of the DTE Energy business segments follows:

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(In millions)
Operating Revenues — Utility operations
Electric	$	1,215		$	1,148		$	2,368		$	2,351
Gas	231			218			751			865
Operating Revenues — Non-utility operations
Gas Storage and Pipelines	69			57			136			114
Power and Industrial Projects	444			556			890			1,123
Energy Trading	476			524			1,025			1,235
Corporate and Other	1			1			1			1
Reconciliation and Eliminations	(174		)	(236		)	(343		)	(437		)
Total	$	2,262		$	2,268		$	4,828		$	5,252

Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	135		$	99		$	262		$	235
Gas	13			(7		)	100			104
Gas Storage and Pipelines	35			25			65			52
Power and Industrial Projects	15			8			32			41
Energy Trading	(23		)	(3		)	(30		)	(12		)
Corporate and Other	(23		)	(13		)	(30		)	(38		)
Net Income Attributable to DTE Energy Company	$	152		$	109		$	399		$	382

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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.

Net Income attributable to DTE Energy in the second quarter of 2016 was $152 million, or $0.84 per diluted share, compared to Net Income attributable to DTE Energy of $109 million, or $0.61 per diluted share, in the second quarter of 2015. Net Income attributable to DTE Energy in the six months ended June 30, 2016 was $399 million, or $2.22 per diluted share, compared to Net Income attributable to DTE Energy of $382 million, or $2.13 per diluted share, in the six months ended June 30, 2015. The increase in net income in the second quarter is primarily due to increased earnings in the Electric, Gas, and Gas Storage and Pipeline segments, partially offset by decreased earnings in the Energy Trading segment. The increase in Net Income for the six months ended June 30, 2016 is primarily due to increased earnings in the Electric and Gas Storage and Pipelines segments, partially offset by decreased earnings in the Power and Industrial Projects and Energy Trading segments.

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

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

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

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 2016-2020 period are estimated at $8.2 billion comprised of $3.8 billion for maintenance and other projects, $3.2 billion for distribution infrastructure, and $1.2 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 seek regulatory approval in general rate case filings and renewable energy plan filings for capital expenditures consistent with prior ratemaking treatment.

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DTE Gas' capital investments over the 2016-2020 period are estimated at $1.6 billion comprised of $800 million for base infrastructure, $600 million for gas main renewal, meter move out, and pipeline integrity programs, and $200 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 2016-2020 period are estimated at $2.0 billion to $2.6 billion for gathering and pipeline investments and expansions, including the NEXUS Pipeline. Power and Industrial Projects' capital investments over the 2016-2020 period are estimated at $600 million to $900 million 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.

DTE Electric is subject to the EPA ozone and fine particulate transport and acid rain regulations that limit power plant emissions of sulfur dioxide and nitrogen oxides. The EPA and the State of Michigan have issued emission reduction regulations relating to ozone, fine particulate, regional haze, mercury, and other air pollution. These rules have led to additional emission controls on fossil-fueled power plants to reduce nitrogen oxide, sulfur dioxide, mercury, and other emissions. These rulemakings could require additional controls for sulfur dioxide, nitrogen oxides, and other hazardous air pollutants over the next few years. To comply with these requirements, DTE Electric spent approximately $2.3 billion through 2015. It is estimated that DTE Electric will make capital expenditures of approximately $45 million in 2016.

The EPA is implementing 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 electric generating units (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. 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 10 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.

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

• electric and gas customer satisfaction;

• electric reliability;

• rate competitiveness and affordability;

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

• growth of utility asset base;

• employee engagement;

• cost structure optimization across all business segments;

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

• investments that integrate assets and leverage skills and expertise.

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

RESULTS OF OPERATIONS

The following sections provide a detailed discussion of the operating performance and future outlook of DTE Energy's segments.

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(In millions)
Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	135		$	99		$	262		$	235
Gas	13			(7		)	100			104
Gas Storage and Pipelines	35			25			65			52
Power and Industrial Projects	15			8			32			41
Energy Trading	(23		)	(3		)	(30		)	(12		)
Corporate and Other	(23		)	(13		)	(30		)	(38		)
Net Income Attributable to DTE Energy Company	$	152		$	109		$	399		$	382

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.

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The Electric segment consists principally of DTE Electric. Results for Electric segment with a reconciliation to DTE Electric are discussed below:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(In millions)
Operating Revenues — Utility operations	$	1,215	$	1,148	$	2,368	$	2,351
Fuel and purchased power — utility	361		381		696		771
Gross Margin	854		767		1,672		1,580
Operation and maintenance	332		319		656		636
Depreciation and amortization	187		166		363		323
Taxes other than income	70		68		143		141
Operating Income	265		214		510		480
Other (Income) and Deductions	54		62		102		119
Income Tax Expense	76		53		146		126
Segment Net Income Attributable to DTE Energy Company	$	135	$	99	$	262	$	235
Reconciliation of Segment Net Income Attributable to DTE Energy Company to DTE Electric Net Income	—		—		—		1
DTE Electric Net Income Attributable to DTE Energy Company	$	135	$	99	$	262	$	236

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

Gross Marginincreased$87 million and $92 million in the three and six months endedJune 30, 2016, respectively. Revenues associated with certain mechanisms and surcharges are offset by related expenses elsewhere in the Registrants' Consolidated Statements of Operations.

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

	Three Months			Six Months
	(In millions)
Base rates	$	60		$	120
Weather	25			(4		)
PSCR disallowance in 2015	19			19
Amortization of refundable revenue decoupling/deferred gain in 2015	(31		)	(63		)
Regulatory mechanisms and other	14			20
Increase in gross margin	$	87		$	92

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	Three Months Ended June 30,		Six Months Ended June 30,
	2016	2015	2016	2015
	(In thousands of MWh)
DTE Electric Sales
Residential	3,569	3,324	7,187	7,176
Commercial	4,233	4,278	8,342	8,438
Industrial	2,557	2,534	4,978	4,998
Other	58	62	136	147
	10,417	10,198	20,643	20,759
Interconnection sales (a)	843	1,699	1,536	2,645
Total DTE Electric Sales	11,260	11,897	22,179	23,404
DTE Electric Deliveries
Retail and wholesale	10,417	10,198	20,643	20,759
Electric retail access, including self generators (b)	1,331	1,230	2,490	2,486
Total DTE Electric Sales and Deliveries	11,748	11,428	23,133	23,245

______________________________

(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$13 million and $20 million in the three and six months endedJune 30, 2016, respectively. The increase in the second quarter was due primarily to increased power plant generation expenses of $10 million, higher line clearance expenses of $9 million, and higher employee benefits expenses of $7 million, partially offset by lower restoration expenses of $9 million, lower energy optimization expenses of $2 million, and lower expenses related to the transition of PLD customers to DTE Electric's distribution system of $2 million. The increase in the six month period was due primarily to higher line clearance expenses of $19 million and higher employee benefits expenses of $18 million, partially offset by lower corporate administrative expenses of $8 million, lower expenses related to the transition of PLD customers to DTE Electric's distribution system of $6 million, and lower energy optimization expenses of $2 million. The MPSC approved a TRM that provides for recovery of the deferred net incremental revenue requirement associated with the transition of PLD customers that is reflected in the Depreciation and amortization line in DTE Energy's and DTE Electric's Consolidated Statements of Operations.

Depreciation and amortization expense increased$21 million and $40 million in the three and six months endedJune 30, 2016, respectively. The increase in the second quarter was due primarily to $12 million associated with the TRM and $10 million of increased expenses due to an increased depreciable base. The increase in the six month period was due primarily to $20 million of increased expenses due to an increased depreciable base and $18 million associated with the TRM.

Other (Income) and Deductionsdecreased$8 million and $17 million in the three and six months endedJune 30, 2016, respectively. The decrease in the second quarter was due primarily to $5 million of higher investment earnings and $2 million of lower interest expense. The decrease in the six month period was due primarily to $9 million of higher investment earnings and $8 million of interest income related to a sales and use tax settlement.

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. Looking forward, additional factors may impact earnings such as weather, the outcome of regulatory proceedings, benefit plan design changes, investment returns and changes in discount rate assumptions in benefit plans and health care costs, uncertainty of legislative or regulatory actions regarding climate change and electric retail access, and effects of energy efficiency programs. DTE Electric expects to continue its efforts to improve productivity and decrease costs while improving customer satisfaction with consideration of customer rate affordability.

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.

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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. 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 includes projected changes in sales, operation and maintenance expenses, and working capital. The rate filing also requests an increase in return on equity from 10.3% to 10.5% on a capital structure of 50% equity and 50% debt. On July 1, 2016, DTE Electric filed an application with the MPSC for a $245 million self-implemented base rate increase effective August 1, 2016. A final MPSC order in this case is expected by February 2017.

GAS

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

	Three Months Ended June 30,					Six Months Ended June 30,
	2016		2015			2016		2015
	(In millions)
Operating Revenues — Utility operations	$	231	$	218		$	751	$	865
Cost of gas — utility	58		61			291		368
Gross Margin	173		157			460		497
Operation and maintenance	98		111			194		222
Depreciation and amortization	26		26			52		51
Taxes other than income	17		17			36		36
Operating Income	32		3			178		188
Other (Income) Deductions	11		13			22		25
Income Tax Expense (Benefit)	8		(3		)	56		59
Net Income (Loss) Attributable to DTE Energy Company	$	13	$	(7	)	$	100	$	104

Gross Marginincreased$16 million and decreased$37 million in the three and six months endedJune 30, 2016, respectively. 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			Six Months
	(In millions)
Weather	$	8		$	(48	)
Midstream storage and transportation revenues	1			(3		)
Infrastructure recovery mechanism	3			6
Revenue decoupling mechanism	(3		)	—
Energy optimization revenue	(1		)	(3		)
Other	8			11
Increase (decrease) in gross margin	$	16		$	(37	)

	Three Months Ended June 30,		Six Months Ended June 30,
	2016	2015	2016	2015
Gas Markets (in Bcf)
Gas sales	18	16	73	85
End user transportation	42	35	98	97
	60	51	171	182
Intermediate transportation	53	59	120	162
	113	110	291	344

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Operation and maintenance expense decreased$13 million and $28 million in the three and six months endedJune 30, 2016, respectively. The decrease in the second quarter was due primarily to decreased employee benefit expenses of $5 million, decreased uncollectible expenses of $4 million, decreased gas operations expenses of $2 million, and decreased transmission expenses of $1 million. The decrease in the six month period was due primarily to decreased uncollectible expenses of $9 million, decreased employee benefit expenses of $6 million, decreased gas operations expenses of $5 million, decreased transmission expenses of $3 million, decreased corporate administrative expenses of $3 million, and decreased energy optimization expenses of $2 million. The decreased uncollectible, gas operations and transmission expenses for the three and six months ended June 30, 2016 were primarily the result of weather-related impacts of warm weather in the first quarter of 2016. Additionally, DTE Gas took actions to reduce costs to partially offset the negative impacts to revenue and gross margin resulting from the warm weather in the first quarter of 2016.

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.

DTE Gas filed a rate case with the MPSC on December 18, 2015 requesting an increase in base rates of $183 million, inclusive of $41 million of existing IRM surcharges which are expected to be converted into base rates, based on a projected twelve-month period ending October 31, 2017. The requested increase in base rates is due primarily to an increase in net plant, inclusive of IRM capital investments being recovered through approved IRM surcharge filings. The rate filing includes projected changes in sales, operation and maintenance expenses, and working capital. The rate filing also requests an increase in return on equity from 10.5% to 10.75% on a capital structure of 52% equity and 48% debt. Concurrent with the MPSC order in this rate case, the existing IRM surcharge being billed will be terminated. However, DTE Gas requested to implement a new IRM surcharge of approximately $9 million to become effective in January 2017. On May 11, 2016, DTE Gas filed an application with the MPSC for a $103 million self-implemented base rate increase effective November 1, 2016. A final MPSC order in this case is expected by December 2016.

GAS STORAGE AND PIPELINES

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

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(In millions)
Operating Revenues — Non-utility operations	$	69		$	57		$	136		$	114
Operation and maintenance	16			13			32			25
Depreciation and amortization	11			7			19			14
Taxes other than income	1			1			2			2
Operating Income	41			36			83			73
Other (Income) and Deductions	(11		)	(6		)	(19		)	(14		)
Income Tax Expense	17			16			36			34
Net Income	35			26			66			53
Less: Net Income Attributable to Noncontrolling Interests	—			1			1			1
Net Income Attributable to DTE Energy Company	$	35		$	25		$	65		$	52

Operating Revenues — Non-utility operationsincreased$12 million and $22 million in the three and six months endedJune 30, 2016, respectively. The increases were due primarily to increased volumes on the Bluestone Pipeline and Susquehanna gathering systems.

Net Income Attributable to DTE Energy Companyincreased$10 million and $13 million in the three and six months endedJune 30, 2016, respectively. The increases were due primarily to increased volumes on the Bluestone Pipeline and Susquehanna gathering systems and increased earnings from pipeline investments.

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Outlook — 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. Procurement activities are underway for Bluestone Pipeline's 2016 expansion in Broome County, New York. Additionally, the Susquehanna gathering system is being expanded with additional compression facilities and gathering lines. Despite recent pressure on producers from low commodity prices, 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 approximately $205 million at June 30, 2016. A FERC application was filed in the fourth quarter of 2015 and an order is expected in the first quarter of 2017. The NEXUS Pipeline has an estimated in service date in the fourth quarter of 2017.

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 June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(In millions)
Operating Revenues — Non-utility operations	$	444		$	556		$	890		$	1,123
Fuel, purchased power, and gas — non-utility	384			468			767			944
Gross Margin	60			88			123			179
Operation and maintenance	83			89			158			174
Depreciation and amortization	18			20			36			40
Taxes other than income	2			4			7			9
Asset (gains) losses and impairments, net	—			18			—			8
Operating Loss	(43		)	(43		)	(78		)	(52		)
Other (Income) and Deductions	(18		)	(17		)	(32		)	(34		)
Income Taxes
Benefit	(7		)	(8		)	(12		)	(7		)
Production Tax Credits	(26		)	(21		)	(51		)	(48		)
	(33		)	(29		)	(63		)	(55		)
Net Income	8			3			17			37
Less: Net Loss Attributable to Noncontrolling Interests	(7		)	(5		)	(15		)	(4		)
Net Income Attributable to DTE Energy Company	$	15		$	8		$	32		$	41

Gross Margindecreased$28 million and $56 million in the three and six months endedJune 30, 2016, respectively. The decrease in the second quarter was due primarily to a $29 million decrease due to lower demand in the steel business, including a $15 million decrease associated with the closure of the Shenango coke battery. The decrease in the six month period was due primarily to a $58 million decrease due to lower demand in the steel business, including $29 million associated with the closure of the Shenango coke battery, partially offset by a $3 million increase primarily associated with higher sales in the on-site business.

Operation and maintenance expense decreased$6 million and $16 million in the three and six months endedJune 30, 2016, respectively. The decrease in the second quarter was due primarily to $13 million of lower spending as a result of the closure of the Shenango coke battery and cost control due to lower demand in the steel business, partially offset by a $7 million increase associated with a new project in the REF business. The decrease in the six month period was due primarily to $22 million of lower spending as a result of the closure of the Shenango coke battery and cost control due to lower demand in the steel business and $2 million of lower general and administrative expenses in the steel business, partially offset by a $10 million increase associated with a new project in the REF business.

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Asset (gains) losses and impairments, netincreased$18 million and $8 million in the three and six months endedJune 30, 2016, respectively. The increases were due primarily to 2015 asset impairments resulting from contract terminations, partially offset by a gain associated with the sale of a landfill gas project in 2015.

Net Loss Attributable to Noncontrolling Interests increased by $2 million and $11 million in the three and six months endedJune 30, 2016, respectively. The loss allocated to noncontrolling interests is primarily due to lease arrangements with investors at various REF facilities.

Outlook— Power and Industrial Projects has constructed and placed in service REF facilities at nine sites including facilities located at six 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 relocating underutilized facility equipment at an existing site to a new third-party owned coal-fired power plant. In addition, DTE Energy has entered into an agreement to operate an REF facility owned by an outside party located at a third-party owned coal-fired power plant.

DTE Energy expects decreased production levels of metallurgical coke and pulverized coal supplied to steel industry customers for 2016. A downturn in the steel industry in the United States will negatively impact the volume and pricing of metallurgical coke sales for the near term. 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 June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(In millions)
Operating Revenues — Non-utility operations	$	476		$	524		$	1,025		$	1,235
Purchased power and gas — non-utility	496			509			1,037			1,216
Gross Margin	(20		)	15			(12		)	19
Operation and maintenance	16			17			32			34
Depreciation and amortization	—			—			1			—
Taxes other than income	—			1			1			3
Operating Loss	(36		)	(3		)	(46		)	(18		)
Other (Income) and Deductions	2			2			3			2
Income Tax Benefit	(15		)	(2		)	(19		)	(8		)
Net Loss Attributable to DTE Energy Company	$	(23	)	$	(3	)	$	(30	)	$	(12	)

Operating Revenues — Non-utility operations were primarily impacted by a decrease in gas prices, partially offset by an increase in volumes, mainly in Energy Trading's gas structured strategy in the three and six months endedJune 30, 2016.

Gross Margindecreased$35 million and $31 million in the three and six months endedJune 30, 2016, respectively. The decrease in the second quarter was due to a decrease in unrealized margins of $36 million, partially offset by an increase in realized margins of $1 million. The decrease in unrealized margins of $36 million is due to unfavorable results of $59 million, primarily in the gas structured and gas storage strategies, offset by favorable results of $23 million, primarily in the gas trading, power full requirements, and power trading strategies. The increase in realized margins of $1 million is due to favorable results of $22 million, primarily in the gas structured and gas storage strategies, partially offset by unfavorable results of $21 million, primarily in the gas and power trading strategies.

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The decrease in the six month period was due to a decrease in realized margins of $27 million, and a decrease in unrealized margins of $4 million. The decrease in realized margins of $27 million is due to unfavorable results of $56 million, primarily in the power full requirements, gas transportation, gas storage, and gas structured strategies, offset by favorable results of $29 million, primarily in the power, gas, and environmental trading strategies. The decrease in unrealized margins of $4 million is due to unfavorable results of $18 million, primarily in the gas transportation, gas trading, and environmental trading strategies, partially offset by favorable results of $14 million, primarily in the gas storage and gas structured strategies.

Natural gas structured transactions typically involve a physical purchase or sale of natural gas in the future and/or natural gas basis financial instruments which are derivatives and a related non-derivative pipeline transportation contract. These gas structured transactions can result in significant earnings volatility as the derivative components are marked-to-market without revaluing the related non-derivative contracts. Included in the unfavorable unrealized results of $59 million in the three months ended June 30, 2016 are timing related losses related to gas strategies of $42 million which will reverse in future periods as the underlying contracts settle. Included in the favorable realized results of $22 million in the three months ended June 30, 2016 are timing related losses related to gas strategies of $9 million recognized in previous periods that reversed as the underlying contracts were settled.

Included in the favorable unrealized results of $14 million in the six months ended June 30, 2016 are timing related gains related to gas strategies of $1 million. The timing related items of $1 million include the variance of timing losses of $35 million in the six months ended June 30, 2015, and timing losses of $34 million in the six months ended June 30, 2016 which will reverse in future periods as the underlying contracts settle. Included in the unfavorable realized results of $56 million in the six months ended June 30, 2016 are timing related gains related to gas strategies of $20 million recognized in previous periods that reversed as the underlying contracts were settled.

Outlook — In the near-term, Energy Trading expects market conditions to remain challenging and the profitability of this segment may be impacted by the volatility in commodity prices and the uncertainty of impacts associated with financial reform, regulatory changes, and changes in operating rules of regional transmission organizations. Significant portions of the Energy Trading portfolio are economically hedged. Most financial instruments and physical power and natural gas contracts are deemed derivatives, whereas natural gas inventory, pipeline transportation, renewable energy credits, and storage assets are not derivatives. As a result, Energy Trading will experience earnings volatility as derivatives are marked-to-market without revaluing the underlying non-derivative contracts and assets. Energy Trading's strategy is to economically manage the price risk of these underlying non-derivative contracts and assets with futures, forwards, swaps, and options. This results in gains and losses that are recognized in different interim and annual accounting periods.

See Notes 6 and 7 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, and holds certain non-utility debt and energy-related investments. The net losses of $23 million and $30 million in the three and six months endedJune 30, 2016, represents an increase of $10 million and a decrease of $8 million from the net losses of $13 million and $38 million in the comparable 2015 periods. The changes in losses were due primarily to effective income tax rate adjustments.

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 2016 will be approximately $1.8 billion, or approximately $100 million lower than 2015, due primarily to higher working capital requirements. 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 2016 of approximately $2.7 billion. DTE Energy plans to seek regulatory approval to include utility capital expenditures in regulatory rate base consistent with prior treatment. Capital spending for growth of existing or new non-utility businesses will depend on the existence of opportunities that meet strict risk-return and value creation criteria.

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	Six Months Ended June 30,
	2016			2015
Cash and Cash Equivalents	(In millions)
Cash Flow From (Used For)
Operating Activities:
Net Income	$	385		$	379
Adjustments to reconcile Net Income to Net cash from operating activities:
Depreciation and amortization	472			429
Nuclear fuel amortization	29			28
Allowance for equity funds used during construction	(10		)	(10		)
Deferred income taxes	134			148
Asset (gains) losses and impairments, net	—			8
Working capital and other	262			198
Net cash from operating activities	1,272			1,180
Investing Activities:
Plant and equipment expenditures — utility	(797		)	(781		)
Plant and equipment expenditures — non-utility	(64		)	(114		)
Acquisition	—			(241		)
Proceeds from sale of assets	—			16
Restricted cash for debt redemption, principally Securitization, net	1			99
Contributions to equity method investees	(121		)	(32		)
Other	43			17
Net cash used for investing activities	(938		)	(1,036		)
Financing Activities:
Issuance of long-term debt, net of issuance costs	588			793
Redemption of long-term debt	(313		)	(118		)
Short-term borrowings, net	(324		)	(398		)
Issuance of common stock	—			9
Repurchase of common stock	(33		)	—
Dividends on common stock and other	(257		)	(248		)
Net cash from (used for) financing activities	(339		)	38
Net Increase (Decrease) in Cash and Cash Equivalents	$	(5	)	$	182

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 in the six months ended June 30, 2016increased by $92 million compared to the six months ended June 30, 2015. The operating cash flow comparison reflects an increase in Net Income and adjustments for non-cash and non-operating items as well as cash from working capital items partially offset by decreases in Deferred income taxes and asset impairments.

Cash used for Investing Activities

Cash inflows associated with investing activities are primarily generated from the sale of assets, while cash outflows are the result of plant and equipment expenditures and acquisitions. In any given year, DTE Energy looks to realize cash from under-performing or non-strategic assets or matured fully valued assets.

Capital spending within the utility businesses is primarily to maintain and improve the electric generation, the electric and natural gas distribution infrastructure, and to comply with environmental regulations and renewable energy requirements.

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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. In any given year, the amount of growth capital will be determined by the underlying cash flows of DTE Energy, with a clear understanding of any potential impact on its credit ratings.

Net cash used for investing activities decreased by $98 million in 2016 due to an acquisition in 2015 and lower capital expenditures by the non-utility business, partially offset by the decrease in restricted cash for the redemption of Securitization bonds and higher contributions to equity method investees, primarily the NEXUS Pipeline as it continues to develop.

Cash from (used for) Financing Activities

DTE Energy relies on both short-term borrowing and long-term financing as a source of funding for capital requirements not satisfied by its operations.

DTE Energy's strategy is to have a targeted debt portfolio blend of fixed and variable interest rates and maturity. DTE Energy 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 increased by $377 million in 2016 due primarily to decreased issuances coupled with increased redemptions of long-term debt and increased repurchases of common stock, partially offset by decreased short-term borrowings.

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 $170 million in long-term debt 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 $1.8 billion of available liquidity at June 30, 2016, consisting of cash and amounts available under unsecured revolving credit agreements.

DTE Energy expects to issue up to $100 million of common stock in 2016 through its pension and other employee benefit plans.

Various subsidiaries of DTE Energy have entered into contracts which contain ratings triggers and are guaranteed by DTE Energy. These contracts contain provisions which allow the counterparties to require that DTE Energy post cash or letters of credit as collateral in the event that DTE Energy's credit rating is downgraded below investment grade. Certain of these provisions (known as “hard triggers”) state specific circumstances under which DTE Energy can be required to post collateral upon the occurrence of a credit downgrade, while other provisions (known as “soft triggers”) are not as specific. For contracts with soft triggers, it is difficult to estimate the amount of collateral which may be requested by counterparties and/or which DTE Energy may ultimately be required to post. The amount of such collateral which could be requested fluctuates based on commodity prices (primarily natural gas, power, and coal) and the provisions and maturities of the underlying transactions. As of June 30, 2016, 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 $322 million.

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DTE Energy believes it will have sufficient operating flexibility, cash resources, and funding sources to maintain adequate amounts of liquidity and to meet future operating cash and capital expenditure needs. However, virtually all of DTE Energy's businesses are capital intensive, or require access to capital, and the inability to access adequate capital could adversely impact earnings and cash flows.

See Notes 4, 8, 9, 10, and 11 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 6 and 7 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 6 to the Consolidated Financial Statements, "Fair Value."

The following tables provide details on changes in DTE Energy's MTM net asset (or liability) position during the six months ended June 30, 2016:

	Total
	(In millions)
MTM at December 31, 2015	$	40
Reclassified to realized upon settlement	(24		)
Changes in fair value recorded to income	(65		)
Amounts recorded to unrealized income	(89		)
Changes in fair value recorded in regulatory liabilities	4
Change in collateral held by (for) others	(8		)
MTM at June 30, 2016	$	(53	)

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The table below shows the maturity of DTE Energy's MTM positions. The positions from 2019 and beyond principally represent longer tenor gas structured transactions:

Source of Fair Value	2016			2017			2018			2019 and Beyond			Total Fair Value
	(In millions)
Level 1	$	(11	)	$	(16	)	$	(1	)	$	4		$	(24	)
Level 2	16			(4		)	3			(1		)	14
Level 3	(10		)	(3		)	3			(59		)	(69		)
MTM before collateral adjustments	$	(5	)	$	(23	)	$	5		$	(56	)	(79		)
Collateral adjustments													26
MTM at June 30, 2016													$	(53	)

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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 and transportation. DTE Energy manages its exposure through the use of short, medium, and long-term storage and transportation contracts.

DTE Energy's Power and Industrial Projects business segment is subject to electricity, natural gas, and coal product price risk. DTE Energy manages its exposure to commodity price risk through the use of long-term contracts.

DTE Energy's Energy Trading business segment has exposure to electricity, natural gas, coal, crude oil, heating oil, and foreign currency exchange price fluctuations. These risks are managed by the energy marketing and trading operations through the use of forward energy, capacity, storage, options, and futures contracts, within pre-determined risk parameters.

Credit Risk

Bankruptcies

Certain of the Registrants' customers and suppliers have filed for bankruptcy protection under the U.S. Bankruptcy Code. The Registrants regularly review contingent matters relating to these customers and suppliers and their purchase and sale contracts and record provisions for amounts considered at risk of probable loss in the allowance for doubtful accounts. The Registrants believe their accrued amounts are adequate for probable loss.

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Trading Activities

DTE Energy is exposed to credit risk through trading activities. Credit risk is the potential loss that may result if the trading counterparties fail to meet their contractual obligations. DTE Energy utilizes both external and internal credit assessments when determining the credit quality of trading counterparties.

The following table displays the credit quality of DTE Energy's trading counterparties as of June 30, 2016:

	Credit Exposure Before Cash Collateral		Cash Collateral			Net Credit Exposure
	(In millions)
Investment Grade (a)
A− and Greater	$	162	$	(2	)	$	160
BBB+ and BBB	175		—			175
BBB−	47		—			47
Total Investment Grade	384		(2		)	382
Non-investment grade (b)	21		(4		)	17
Internally Rated — investment grade (c)	233		—			233
Internally Rated — non-investment grade (d)	9		—			9
Total	$	647	$	(6	)	$	641

_______________________________________

(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 22% of the total gross credit exposure.

(b) This category includes counterparties with credit ratings that are below investment grade. The five largest counterparty exposures, combined, for this category represented less than 3% 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 17% 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 1% of the total gross credit exposure.

Other

The Registrants engage in business with customers that are non-investment grade. The Registrants closely monitor the credit ratings of these customers and, when deemed necessary and permitted under the tariffs, request collateral or guarantees from such customers to secure their obligations.

Interest Rate Risk

DTE Energy is subject to interest rate risk in connection with the issuance of debt. In order to manage interest costs, DTE Energy may use treasury locks and interest rate swap agreements. DTE Energy's exposure to interest rate risk arises primarily from changes in U.S. Treasury rates, commercial paper rates, and London Inter-Bank Offered Rates (LIBOR). As of June 30, 2016, DTE Energy had a floating rate debt-to-total debt ratio of approximately 1.9%.

Foreign Currency Exchange Risk

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

Summary of Sensitivity Analyses

The Registrants performed sensitivity analyses on the fair values of commodity contracts, long-term debt obligations, and foreign currency exchange forward contracts. The commodity contracts and foreign currency exchange risk listed below principally relate to energy marketing and trading activities. The sensitivity analysis involved increasing and decreasing forward prices and rates at June 30, 2016 and 2015 by a hypothetical 10% and calculating the resulting change in the fair values.

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The results of the sensitivity analysis calculations as of June 30, 2016 and 2015:

	Assuming a 10% Increase in Prices/Rates						Assuming a 10% Decrease in Prices/Rates
	As of June 30,						As of June 30,
Activity	2016			2015			2016			2015			Change in the Fair Value of
	(In millions)
Natural gas contracts	$	12		$	(2	)	$	(12	)	$	2		Commodity contracts
Electricity contracts	$	15		$	15		$	(15	)	$	(17	)	Commodity contracts
Oil contracts	$	1		$	2		$	(1	)	$	(2	)	Commodity contracts
Interest rate risk	$	(389	)	$	(372	)	$	408		$	394		Long-term debt

For further discussion of market risk, see Note 7 to the Consolidated Financial Statements, "Financial and Other Derivative Instruments."

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Item 4.Controls and Procedures

DTE Energy

(a) Evaluation of disclosure controls and procedures

Management of DTE Energy carried out an evaluation, under the supervision and with the participation of DTE Energy's Chief Executive Officer (CEO) and Chief Financial Officer (CFO), of the effectiveness of the design and operation of DTE Energy's disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of June 30, 2016, which is the end of the period covered by this report. Based on this evaluation, DTE Energy's CEO and CFO have concluded that such disclosure controls and procedures are effective in providing reasonable assurance that information required to be disclosed by DTE Energy in reports that it files or submits under the Exchange Act (i) is recorded, processed, summarized, and reported within the time periods specified in the U.S. Securities and Exchange Commission's rules and forms and (ii) is accumulated and communicated to DTE Energy's management, including its CEO and CFO, as appropriate to allow timely decisions regarding required disclosure. Due to the inherent limitations in the effectiveness of any disclosure controls and procedures, management cannot provide absolute assurance that the objectives of its disclosure controls and procedures will be attained.

(b) Changes in internal control over financial reporting

There have been no changes in DTE Energy's internal control over financial reporting during the quarter ended June 30, 2016 that have materially affected, or are reasonably likely to materially affect, DTE Energy's internal control over financial reporting.

DTE Electric

(a) Evaluation of disclosure controls and procedures

Management of DTE Electric carried out an evaluation, under the supervision and with the participation of DTE Electric's Chief Executive Officer (CEO) and Chief Financial Officer (CFO), of the effectiveness of the design and operation of DTE Electric's disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of June 30, 2016, which is the end of the period covered by this report. Based on this evaluation, DTE Electric's CEO and CFO have concluded that such disclosure controls and procedures are effective in providing reasonable assurance that information required to be disclosed by DTE Electric in reports that it files or submits under the Exchange Act (i) is recorded, processed, summarized, and reported within the time periods specified in the U.S. Securities and Exchange Commission's rules and forms and (ii) is accumulated and communicated to DTE Electric's management, including its CEO and CFO, as appropriate to allow timely decisions regarding required disclosure. Due to the inherent limitations in the effectiveness of any disclosure controls and procedures, management cannot provide absolute assurance that the objectives of its disclosure controls and procedures will be attained.

(b) Changes in internal control over financial reporting

There have been no changes in DTE Electric's internal control over financial reporting during the quarter ended June 30, 2016 that have materially affected, or are reasonably likely to materially affect, DTE Electric's internal control over financial reporting.

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Part II — Other Information

Item 1. Legal Proceedings

For more information on material legal proceedings and matters related to the Registrants, see Notes 4 and 10 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 2015 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

The following table provides information about DTE Energy purchases of equity securities that are registered by DTE Energy pursuant to Section 12 of the Exchange Act of 1934 for the quarter ended June 30, 2016:

	Number of Shares Purchased (a)	Average Price Paid per Share (a)		Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Average Price Paid per Share	Maximum Dollar Value that May Yet Be Purchased Under the Plans or Programs
04/01/2016 — 04/30/2016	4,500	$	86.51	—	—	—
05/01/2016 — 05/31/2016	500	$	86.27	—	—	—
06/01/2016 — 06/30/2016	3,220	$	84.20	—	—	—
Total	8,220			—

_______________________________________

(a) Represents shares of DTE Energy 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:
4.293	Supplemental Indenture, dated as of May 1, 2016, between DTE Electric Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (2016 Series A)	X	X
4.294	Supplemental Indenture, dated as of June 1, 2016, between DTE Energy Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (2015 Series BR)	X
10.101	Request for Extension of Termination Date, dated as of March 17, 2016, to the Third Amended and Restated Five-Year Credit Agreement, dated as of October 21, 2011, amended and restated as of April 5, 2013, and amended and restated as of April 16, 2015, by and among DTE Energy, the lenders party thereto, Citibank, N.A., as Administrative Agent, and Barclays Bank PLC, The Bank of Nova Scotia and JPMorgan Chase Bank, N.A, as Co-Syndication Agents	X
10.102	Request for Extension of Termination Date, dated as of March 17, 2016, to the Third Amended and Restated Five-Year Credit Agreement, dated as of October 21, 2011, amended and restated as of April 5, 2013, and amended and restated as of April 16, 2015, by and among DTE Gas the lenders party thereto, JPMorgan Chase Bank, N.A., as Administrative Agent, and Barclays Bank PLC, Citibank, N.A. and Bank of America, N.A., as Co-Syndication Agents	X
10.103	Request for Extension of Termination Date, dated as of March 17, 2016, to the Third Amended and Restated Five-Year Credit Agreement, dated as of October 21, 2011, amended and restated as of April 5, 2013, and further amended and restated as of April 16, 2015, by and among DTE Electric Company, the lenders party thereto, Barclays Bank PLC., as Administrative Agent, and Citibank, N.A., JPMorgan Chase Bank, N.A. and Wells Fargo Bank, National Association as Co-Syndication Agents	X	X
12.69	Computation of Ratio of Earnings to Fixed Charges	X
12.70	Computation of Ratio of Earnings to Fixed Charges		X
31.117	Chief Executive Officer Section 302 Form 10-Q Certification of Periodic Report	X
31.118	Chief Financial Officer Section 302 Form 10-Q Certification of Periodic Report	X
31.119	Chief Executive Officer Section 302 Form 10-Q Certification of Periodic Report		X
31.120	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:
32.117	Chief Executive Officer Section 906 Form 10-Q Certification of Periodic Report	X
32.118	Chief Financial Officer Section 906 Form 10-Q Certification of Periodic Report	X
32.119	Chief Executive Officer Section 906 Form 10-Q Certification of Periodic Report		X
32.120	Chief Financial Officer Section 906 Form 10-Q Certification of Periodic Report		X

62

	(iii) Exhibits incorporated by reference:
4.295	Supplemental Indenture, dated as of May 15, 2016, between DTE Energy Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4.1 to DTE Energy’s Form 8-K dated May 27, 2016) (2016 Series B)	X

63

Signatures

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

Date:	July 26, 2016
			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)

64

EX-4.293

EXHIBIT 4.293

INDENTURE

DATED AS OF May 1, 2016

_______________

DTE ELECTRIC COMPANY

formerly known as

The Detroit Edison Company

(One Energy Plaza, Detroit, Michigan 48226)

TO

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

(719 Griswold Street, Suite 930, Detroit, Michigan 48226)

AS TRUSTEE

_______________

SUPPLEMENTAL TO MORTGAGE AND DEED OF TRUST

DATED AS OF OCTOBER 1, 1924

PROVIDING FOR

(A) GENERAL AND REFUNDING MORTGAGE BONDS,

2016 SERIES A

AND

(B) RECORDING AND FILING DATA

1

TABLE OF CONTENTS*

	PAGE
PARTIES	3
RECITALS	3
Original Indenture and Supplemental Indentures	3
Issue of Bonds Under Indenture	4
Bonds Heretofore Issued	4
Reason for Creation of New Series	11
Bonds to be 2016 Series A	11
Further Assurance	12
Authorization of Supplemental Indenture	12
Consideration for Supplemental Indenture	12
PART I. CREATION OF THREE HUNDRED SEVENTY SIXTH SERIES OF BONDS, GENERAL AND REFUNDING MORTGAGE BONDS, 2016 SERIES A	13
Sec. 1. Terms of Bonds of 2016 Series A	13
Sec. 2. Redemption of Bonds of 2016 Series A	15
Sec. 3. Exchange and Transfer	17
Sec. 4. Form of Bonds of 2016 Series A	17
Form of Trustee’s Certificate	21
PART II. RECORDING AND FILING DATA	22
Recording and Filing of Original Indenture	22
Recording and Filing of Supplemental Indentures	22
Recording and Filing of Supplemental Indenture Dated as of March 1, 2015	27
Recording of Certificates of Provision for Payment	27
PART III. THE TRUSTEE	28
Terms and Conditions of Acceptance of Trust by Trustee	28
PART IV. MISCELLANEOUS	28
Confirmation of Section 318(c) of Trust Indenture Act	28
Execution in Counterparts	28
EXECUTION	28
Testimonium	28
Execution by Company	29
Acknowledgment of Execution by Company	30
Execution by Trustee	31
Acknowledgment of Execution by Trustee	32
Affidavit as to Consideration and Good Faith	33

—————————

* This Table of Contents shall not have any bearing upon the interpretation of any of the terms or provisions of this Indenture.

2

PARTIES.		SUPPLEMENTAL INDENTURE, dated as of the 1st day of May, in the year 2016, between DTE ELECTRIC COMPANY, formerly known as The Detroit Edison Company, a corporation organized and existing under the laws of the State of Michigan and a public utility (hereinafter called the “Company”), party of the first part, and The Bank of New York Mellon Trust Company, N.A., a trust company organized and existing under the laws of the United States, having a corporate trust agency office at 719 Griswold Street, Suite 930, Detroit, Michigan 48226, as successor Trustee under the Mortgage and Deed of Trust hereinafter mentioned (hereinafter called the “Trustee”), party of the second part.
ORIGINAL INDENTURE AND SUPPLEMENTAL INDENTURES.		WHEREAS, the Company has heretofore executed and delivered its Mortgage and Deed of Trust (hereinafter referred to as the “Original Indenture”), dated as of October 1, 1924, to the Trustee, for the security of all bonds of the Company outstanding thereunder, and pursuant to the terms and provisions of the Original Indenture, indentures dated as of, respectively, June 1, 1925, August 1, 1927, February 1, 1931, June 1, 1931, October 1, 1932, September 25, 1935, September 1, 1936, November 1, 1936, February 1, 1940, December 1, 1940, September 1, 1947, March 1, 1950, November 15, 1951, January 15, 1953, May 1, 1953, March 15, 1954, May 15, 1955, August 15, 1957, June 1, 1959, December 1, 1966, October 1, 1968, December 1, 1969, July 1, 1970, December 15, 1970, June 15, 1971, November 15, 1971, January 15, 1973, May 1, 1974, October 1, 1974, January 15, 1975, November 1, 1975, December 15, 1975, February 1, 1976, June 15, 1976, July 15, 1976, February 15, 1977, March 1, 1977, June 15, 1977, July 1, 1977, October 1, 1977, June 1, 1978, October 15, 1978, March 15, 1979, July 1, 1979, September 1, 1979, September 15, 1979, January 1, 1980, April 1, 1980, August 15, 1980, August 1, 1981, November 1, 1981, June 30, 1982, August 15, 1982, June 1, 1983, October 1, 1984, May 1, 1985, May 15, 1985, October 15, 1985, April 1, 1986, August 15, 1986, November 30, 1986, January 31, 1987, April 1, 1987, August 15, 1987, November 30, 1987, June 15, 1989, July 15, 1989, December 1, 1989, February 15, 1990, November 1, 1990, April 1, 1991, May 1, 1991, May 15, 1991, September 1, 1991, November 1, 1991, January 15, 1992, February 29, 1992, April 15, 1992, July 15, 1992, July 31, 1992, November 30, 1992, December 15, 1992, January 1, 1993, March 1, 1993, March 15, 1993, April 1, 1993, April 26, 1993, May 31, 1993, June 30, 1993, June 30, 1993, September 15, 1993, March 1, 1994, June 15, 1994, August 15, 1994, December 1, 1994, August 1, 1995, August 1, 1999, August 15, 1999, January 1, 2000, April 15, 2000, August 1, 2000, March 15, 2001, May 1, 2001, August 15, 2001, September 15, 2001, September 17, 2002, October 15, 2002, December 1, 2002, August 1, 2003, March 15, 2004, July 1, 2004, February 1, 2005, April 1, 2005, August 1, 2005, September 15, 2005, September 30, 2005, May 15, 2006, December 1, 2006, December 1, 2007, April 1, 2008, May 1, 2008, June 1, 2008, July 1, 2008, October 1, 2008, December 1, 2008, March 15, 2009, November 1, 2009, August 1, 2010, September 1, 2010, December 1, 2010, March 1, 2011, May 15, 2011, August 1, 2011, August 15, 2011, September 1, 2011, June 20, 2012, March 15, 2013, August 1, 2013, June 1, 2014, July 1, 2014 and March 1, 2015 supplemental to the Original Indenture, have heretofore been entered into between the Company and the Trustee (the Original Indenture and all indentures supplemental thereto together being hereinafter sometimes referred to as the “Indenture”); and
ISSUE OF BONDS UNDER INDENTURE.		WHEREAS, the Indenture provides that said bonds shall be issuable in one or more series, and makes provision that the rates of interest and dates for the payment thereof, the date of maturity or dates of maturity, if of serial maturity, the terms and rates of optional redemption (if redeemable), the forms of registered bonds without coupons of any series and any other provisions and agreements in respect thereof, in the Indenture provided and permitted, as the Board of Directors may determine, may be expressed in a supplemental indenture to be made by the Company to the Trustee thereunder; and
BONDS HERETOFORE ISSUED.		WHEREAS, bonds in the principal amount of Seventeen billion, four hundred eighty-eight million, fifty-seven thousand dollars ($17,488,057,000) have heretofore been issued under the indenture as follows, viz:
	(1)	Bonds of Series A	— Principal Amount $26,016,000,
	(2)	Bonds of Series B	— Principal Amount $23,000,000,
	(3)	Bonds of Series C	— Principal Amount $20,000,000,

3

(4)	Bonds of Series D	— Principal Amount $50,000,000,
(5)	Bonds of Series E	— Principal Amount $15,000,000,
(6)	Bonds of Series F	— Principal Amount $49,000,000,
(7)	Bonds of Series G	— Principal Amount $35,000,000,
(8)	Bonds of Series H	— Principal Amount $50,000,000,
(9)	Bonds of Series I	— Principal Amount $60,000,000,
(10)	Bonds of Series J	— Principal Amount $35,000,000,
(11)	Bonds of Series K	— Principal Amount $40,000,000,
(12)	Bonds of Series L	— Principal Amount $24,000,000,
(13)	Bonds of Series M	— Principal Amount $40,000,000,
(14)	Bonds of Series N	— Principal Amount $40,000,000,
(15)	Bonds of Series O	— Principal Amount $60,000,000,
(16)	Bonds of Series P	— Principal Amount $70,000,000,
(17)	Bonds of Series Q	— Principal Amount $40,000,000,
(18)	Bonds of Series W	— Principal Amount $50,000,000,
(19)	Bonds of Series AA	— Principal Amount $100,000,000,
(20)	Bonds of Series BB	— Principal Amount $50,000,000,

4

(21)	Bonds of Series CC	— Principal Amount $50,000,000,
(22)	Bonds of Series UU	— Principal Amount $100,000,000,
(54)	Bonds of Series DDP Nos. 1-9	— Principal Amount $14,305,000,
(77)	Bonds of Series FFR Nos. 1-14	— Principal Amount $45,600,000,
(113)	Bonds of Series GGP Nos. 1-22	— Principal Amount $42,300,000,
(68)	Bonds of Series HH	— Principal Amount $50,000,000,
(159)	Bonds of Series IIP Nos. 1-22	— Principal Amount $3,750,000,
(189)	Bonds of Series JJP Nos. 1-8	— Principal Amount $6,850,000,
(206)	Bonds of Series KKP Nos. 1-9	— Principal Amount $34,890,000,
(230)	Bonds of Series LLP Nos. 1-15	— Principal Amount $8,850,000,
(266)	Bonds of Series NNP Nos. 1-21	— Principal Amount $47,950,000,
(305)	Bonds of Series OOP Nos. 1-18	— Principal Amount $18,880,000,
(342)	Bonds of Series QQP Nos. 1-19	— Principal Amount $13,650,000,
(376)	Bonds of Series TTP Nos. 1-15	— Principal Amount $3,800,000,
(196)	Bonds of 1980 Series A	— Principal Amount $50,000,000,
(418)	Bonds of 1980 Series CP Nos. 1-25	— Principal Amount $35,000,000,
(454)	Bonds of 1980 Series DP Nos. 1-11	— Principal Amount $10,750,000,
(481)	Bonds of 1981 Series AP Nos. 1-16	— Principal Amount $124,000,000,
(249)	Bonds of 1985 Series A	— Principal Amount $35,000,000,
(250)	Bonds of 1985 Series B	— Principal Amount $50,000,000,
(251)	Bonds of Series PP	— Principal Amount $70,000,000,
(252)	Bonds of Series RR	— Principal Amount $70,000,000,
(253)	Bonds of Series EE	— Principal Amount $50,000,000,
(509)	Bonds of Series MMP and MMP No. 2	— Principal Amount $5,430,000,

5

(256)	Bonds of Series T	— Principal Amount $75,000,000,
(257)	Bonds of Series U	— Principal Amount $75,000,000,
(258)	Bonds of 1986 Series B	— Principal Amount $100,000,000,
(259)	Bonds of 1987 Series D	— Principal Amount $250,000,000,
(260)	Bonds of 1987 Series E	— Principal Amount $150,000,000,
(261)	Bonds of 1987 Series C	— Principal Amount $225,000,000,
(262)	Bonds of Series V	— Principal Amount $100,000,000,
(263)	Bonds of Series SS	— Principal Amount $150,000,000,
(264)	Bonds of 1980 Series B	— Principal Amount $100,000,000,
(265)	Bonds of 1986 Series C	— Principal Amount $200,000,000,
(266)	Bonds of 1986 Series A	— Principal Amount $200,000,000,
(267)	Bonds of 1987 Series B	— Principal Amount $175,000,000,
(268)	Bonds of Series X	— Principal Amount $100,000,000,
(269)	Bonds of 1987 Series F	— Principal Amount $200,000,000,
(270)	Bonds of 1987 Series A	— Principal Amount $300,000,000,
(271)	Bonds of Series Y	— Principal Amount $60,000,000,
(272)	Bonds of Series Z	— Principal Amount $100,000,000,
(273)	Bonds of 1989 Series A	— Principal Amount $300,000,000,
(274)	Bonds of 1984 Series AP	— Principal Amount $2,400,000,
(275)	Bonds of 1984 Series BP	— Principal Amount $7,750,000,
(276)	Bonds of Series R	— Principal Amount $100,000,000,
(277)	Bonds of Series S	— Principal Amount $150,000,000,
(278)	Bonds of 1993 Series D	— Principal Amount $100,000,000,
(279)	Bonds of 1992 Series E	— Principal Amount $50,000,000,
(280)	Bonds of 1993 Series B	— Principal Amount $50,000,000,
(281)	Bonds of 1989 Series BP	— Principal Amount $66,565,000,

6

(282)	Bonds of 1990 Series A	— Principal Amount $194,649,000,
(283)	Bonds of 1990 Series D	— Principal Amount $0,
(284)	Bonds of 1993 Series G	— Principal Amount $225,000,000,
(285)	Bonds of 1993 Series K	— Principal Amount $160,000,000,
(286)	Bonds of 1991 Series EP	— Principal Amount $41,480,000,
(287)	Bonds of 1993 Series H	— Principal Amount $50,000,000,
(288)	Bonds of 1999 Series D	— Principal Amount $40,000,000,
(289)	Bonds of 1991 Series FP	— Principal Amount $98,375,000,
(290)	Bonds of 1992 Series BP	— Principal Amount $20,975,000,
(291)	Bonds of 1992 Series D	— Principal Amount $300,000,000,
(292)	Bonds of 1992 Series CP	— Principal Amount $35,000,000,
(293)	Bonds of 1993 Series C	— Principal Amount $225,000,000,
(294)	Bonds of 1993 Series E	— Principal Amount $400,000,000,
(295)	Bonds of 1993 Series J	— Principal Amount $300,000,000,
(597)	Bonds of Series KKP Nos. 10-15	— Principal Amount $179,590,000,
(302)	Bonds of 1989 Series BP No. 2	— Principal Amount $36,000,000,
(303)	Bonds of 1993 Series FP	— Principal Amount $5,685,000,
(304)	Bonds of 1993 Series IP	— Principal Amount $5,825,000,
(305)	Bonds of 1994 Series AP	— Principal Amount $7,535,000,
(306)	Bonds of 1994 Series BP	— Principal Amount $12,935,000,
(307)	Bonds of 1994 Series DP	— Principal Amount $23,700,000,
(308)	Bonds of 1994 Series C	— Principal Amount $200,000,000,
(309)	Bonds of 2000 Series A	— Principal Amount $220,000,000,
(310)	Bonds of 2005 Series A	— Principal Amount $200,000,000,
(311)	Bonds of 1995 Series AP	— Principal Amount $97,000,000,
(312)	Bonds of 1995 Series BP	— Principal Amount $22,175,000,

(313)	Bonds of 2001 Series D	— Principal Amount $200,000,000,
(314)	Bonds of 2005 Series B	— Principal Amount $200,000,000,
(315)	Bonds of 2006 Series CT	— Principal Amount $68,500,000,
(316)	Bonds of 2005 Series DT	— Principal Amount $119,175,000,
(317)	Bonds of 1991 Series AP	— Principal Amount $32,375,000,
(318)	Bonds of 2008 Series DT	— Principal Amount $68,500,000,
(319)	Bonds of 1993 Series AP	— Principal Amount $65,000,000,
(320)	Bonds of 2001 Series E	— Principal Amount $500,000,000,
(321)	Bonds of 2001 Series AP	— Principal Amount $31,000,000,
(322)	Bonds of 1991 Series BP	— Principal Amount $25,910,000,
(323)	Bonds of 2001 Series BP	— Principal Amount $82,350,000,
(324)	Bonds of 1999 Series AP	— Principal Amount $118,360,000,
(325)	Bonds of 1999 Series CP	— Principal Amount $66,565,000,
(326)	Bonds of 1999 Series BP	— Principal Amount $39,745,000,
(327)	Bonds of 2001 Series CP	— Principal Amount $139,855,000,

7

(328)	Bonds of 2000 Series B	— Principal Amount $50,745,000,
(329)	Bonds of 2002 Series A	— Principal Amount $225,000,000,
(330)	Bonds of 2002 Series C	— Principal Amount $64,300,000,
(331)	Bonds of 2002 Series D	— Principal Amount $55,975,000,
(332)	Bonds of 2009 Series CT	— Principal Amount $65,000,000,
(333)	Bonds of 2003 Series A	— Principal Amount $49,000,000,
(334)	Bonds of 2008 Series J	— Principal Amount $250,000,000,
(335)	Bonds of 2008 Series LT	— Principal Amount $50,000,000
(336) (337)	Bonds of 1990 Series C Bonds of 1990 Series F	— Principal Amount $85,475,000, — Principal Amount $0
(338)	Bonds of 2011 Series AT	— Principal Amount $31,000,000,
(339)	Bonds of 2004 Series B	— Principal Amount $31,980,000,
(340)	Bonds of 2004 Series A	— Principal Amount $36,000,000,
(341)	Bonds of 2009 Series BT	— Principal Amount $68,500,000,
(342)	Bonds of 2004 Series D	— Principal Amount $200,000,000,
(343)	Bonds of 2005 Series AR	— Principal Amount $200,000,000,
(344)	Bonds of 2010 Series CT	— Principal Amount $19,855,000,
(345)	Bonds of 1990 Series B	— Principal Amount $256,932,000, and
(346)	Bonds of 1990 Series E	— Principal Amount $0
	all of which have either been retired and cancelled, or no longer represent obligations of the Company, having matured or having been called for redemption and funds necessary to effect the payment, redemption and retirement thereof having been deposited with the Trustee as a special trust fund to be applied for such purpose;
(347)	Bonds of 1991 Series CP in the principal amount of Thirty-two million eight hundred thousand dollars ($32,800,000), all of which are outstanding at the date hereof;
(348)	Bonds of 1991 Series DP in the principal amount of Thirty-seven million six hundred thousand dollars ($37,600,000), all of which are outstanding at the date hereof;
(349)	Bonds of 1992 Series AP in the principal amount of Sixty-six million dollars ($66,000,000), all of which are outstanding at the date hereof;
(350)	Bonds of 2002 Series B in the principal amount of Two hundred twenty-fifty million dollars ($225,000,000) all of which are outstanding at the date hereof;
(351)	Bonds of 2005 Series BR in the principal amount of Two hundred million dollars ($200,000,000) all of which are outstanding at the date hereof;
(352)	Bonds of 2005 Series C in the principal amount of One hundred million dollars ($100,000,000) all of which are outstanding at the date hereof;
(353)	Bonds of 2005 Series E in the principal amount of Two hundred fifty million dollars ($250,000,000) all of which are outstanding at the date hereof;
(354)	Bonds of 2006 Series A in the principal amount of Two hundred fifty million dollars ($250,000,000) all of which are outstanding at the date hereof;
(355)	Bonds of 2007 Series A in the principal amount of Fifty million dollars ($50,000,000) all of which are outstanding at the date hereof;

8

(356)	Bonds of 2008 Series ET in the principal amount of One hundred nineteen million one hundred seventy five thousand dollars ($119,175,000) of which fifty-nine million one hundred seventy-five thousand dollars ($59,175,000) are outstanding at the date hereof;
(357)	Bonds of 2008 Series G in the principal amount of Three hundred million dollars ($300,000,000) all of which are outstanding at the date hereof;
(358)	Bonds of 2008 Series KT in the principal amount of Thirty-two million three hundred seventy-five thousand dollars ($32,375,000) all of which are outstanding at the date hereof;
(359)	Bonds of 2010 Series B in the principal amount of Three hundred million dollars ($300,000,000) all of which are outstanding at the date hereof;
(360)	Bonds of 2010 Series A in the principal amount of Three hundred million dollars ($300,000,000) all of which are outstanding at the date hereof;
(361)	Bonds of 2011 Series B in the principal amount of Two hundred and fifty million dollars ($250,000,000) all of which are outstanding at the date hereof;
(362)	Bonds of 2011 Series D in the principal amount of One hundred two million dollars ($102,000,000) all of which are outstanding at the date hereof;
(363)	Bonds of 2011 Series E in the principal amount of Seventy seven million dollars ($77,000,000) all of which are outstanding at the date hereof;
(364)	Bonds of 2011 Series F in the principal amount of Forty six million dollars ($46,000,000) all of which are outstanding at the date hereof;
(365)	Bonds of 2011 Series GT in the principal amount of Eighty two million three hundred fifty thousand dollars ($82,350,000) all of which are outstanding at the date hereof;
(366)	Bonds of 2011 Series H in the principal amount of One hundred forty million dollars ($140,000,000) all of which are outstanding at the date hereof;
(367)	Bonds of 2012 Series A in the principal amount of Two hundred fifty million dollars ($250,000,000) all of which are outstanding at the date hereof;
(368)	Bonds of 2012 Series B in the principal amount of Two hundred fifty million dollars ($250,000,000) all of which are outstanding at the date hereof;
(369)	Bonds of 2013 Series A in the principal amount of Three hundred seventy five million dollars ($375,000,000) all of which are outstanding at the date hereof;
(370)	Bonds of 2013 Series B in the principal amount of Four hundred million dollars ($400,000,000) all of which are outstanding at the date hereof;
(371)	Bonds of 2014 Series A in the principal amount of one hundred million dollars ($100,000,000) all of which are outstanding at the date hereof;
(372)	Bonds of 2014 Series B in the principal amount of one hundred and fifty million dollars ($150,000,000) all of which are outstanding at the date hereof;
(373)	Bonds of 2014 Series D in the principal amount of one hundred and fifty million dollars ($350,000,000) all of which are outstanding at the date hereof;
(374)	Bonds of 2014 Series E in the principal amount of one hundred and fifty million dollars ($350,000,000) all of which are outstanding at the date hereof; and
(375)	Bonds of 2015 Series A in the principal amount of five hundred million dollars ($500,000,000) all of which are outstanding at the date hereof
	accordingly, the Company has issued and has presently outstanding Five billion six hundred twenty-five million, three hundred thousand dollars ($5,625,300,000) aggregate principal amount of its General and Refunding Mortgage Bonds (the “Bonds”) at the date hereof.

9

REASON FOR CREATION OF NEW SERIES.	WHEREAS, the Company desires to issue a new series of bonds pursuant to the Indenture; and
BONDS TO BE 2016 SERIES A.	WHEREAS, the Company desires by this Supplemental Indenture to create a new series of bonds, to be designated “General and Refunding Mortgage Bonds, 2016 Series A,” in the aggregate principal amount of three hundred million dollars ($300,000,000), to be authenticated and delivered pursuant to Section 8 of Article III of the Indenture; and
FURTHER ASSURANCE.	WHEREAS, the Original Indenture, by its terms, includes in the property subject to the lien thereof all of the estates and properties, real, personal and mixed, rights, privileges and franchises of every nature and kind and wheresoever situate, then or thereafter owned or possessed by or belonging to the Company or to which it was then or at any time thereafter might be entitled in law or in equity (saving and excepting, however, the property therein specifically excepted or released from the lien thereof), and the Company therein covenanted that it would, upon reasonable request, execute and deliver such further instruments as may be necessary or proper for the better assuring and confirming unto the Trustee all or any part of the trust estate, whether then or thereafter owned or acquired by the Company (saving and excepting, however, property specifically excepted or released from the lien thereof); and
AUTHORIZATION OF SUPPLEMENTAL INDENTURE.	WHEREAS, the Company in the exercise of the powers and authority conferred upon and reserved to it under and by virtue of the provisions of the Indenture, and pursuant to resolutions of its Board of Directors, has duly resolved and determined to make, execute and deliver to the Trustee a supplemental indenture in the form hereof for the purposes herein provided; and
	WHEREAS, all conditions and requirements necessary to make this Supplemental Indenture a valid and legally binding instrument in accordance with its terms have been done, performed and fulfilled, and the execution and delivery hereof have been in all respects duly authorized;
CONSIDERATION FOR SUPPLEMENTAL INDENTURE.	NOW, THEREFORE, THIS INDENTURE WITNESSETH: That DTE Electric Company, in consideration of the premises and of the covenants contained in the Indenture and of the sum of One Dollar ($1.00) and other good and valuable consideration to it duly paid by the Trustee at or before the ensealing and delivery of these presents, the receipt whereof is hereby acknowledged, hereby covenants and agrees to and with the Trustee and its successors in the trusts under the Original Indenture and in said indentures supplemental thereto as follows:

10

	PART I. CREATION OF THREE HUNDRED SEVENTY SIXTH SERIES OF BONDS, GENERAL AND REFUNDING MORTGAGE BONDS, 2016 SERIES A
TERMS OF BONDS OF 2016 SERIES A.	SECTION 1. The Company hereby creates the three hundred seventy sixth series of bonds to be issued under and secured by the Original Indenture as amended to date and as further amended by this Supplemental Indenture, to be designated, and to be distinguished from the bonds of all other series, by the title “General and Refunding Mortgage Bonds, 2016 Series A” (elsewhere herein referred to as the “bonds of 2016 Series A”). The aggregate principal amount of bonds of 2016 Series A shall be limited to three hundred million dollars ($300,000,000), except as provided in Sections 7 and 13 of Article II of the Original Indenture with respect to exchanges and replacements of bonds, and except further that the Company may, without the consent of any holder of the bonds of 2016 Series A, “reopen” the bonds of 2016 Series A, so long as any additional bonds of 2016 Series A have the same tenor and terms as the bonds of 2016 Series A established hereby.
	The bonds of 2016 Series A shall be issued as registered bonds without coupons in denominations of $2,000 and any larger amount that is an integral multiple of $1,000. The bonds of 2016 Series A shall be issued in the aggregate principal amount of $300,000,000, shall mature on June 1, 2046 (subject to earlier redemption or release) and shall bear interest, payable semi-annually on June 1 and December 1 of each year (commencing December 1, 2016), at the rate of three and seventy hundredths percent (3.70%) per annum until the principal thereof shall have become due and payable and thereafter until the Company’s obligation with respect to the payment of said principal shall have been discharged as provided in the Indenture. The bonds of 2016 Series A will be issued in book-entry form through the facilities of The Depository Trust Company. Except as otherwise specifically provided in this Supplemental Indenture, the bonds of 2016 Series A shall be payable, as to principal, premium, if any, and interest, at the office or agency of the Company in the Borough of Manhattan, the City and State of New York, in any coin or currency of the United States of America which at the time of payment is legal tender for public and private debts.
	Except as provided herein, each bond of 2016 Series A shall be dated the date of its authentication and interest shall be payable on the principal represented thereby from the June 1 or December 1 next preceding the date to which interest has been paid on bonds of 2016 Series A, unless the bond is authenticated on a date prior to December 1, 2016 in which case interest shall be payable from May 17, 2016.

The bonds of 2016 Series A in definitive form shall be, at the election of the Company, fully engraved or shall be lithographed or printed in authorized denominations as aforesaid and numbered R-1 and upwards (with such further designation as may be appropriate and desirable to indicate by such designation the form, series and denomination of bonds of 2016 Series A). Until bonds of 2016 Series A in definitive form are ready for delivery, the Company may execute, and upon its request in writing the Trustee shall authenticate and deliver in lieu thereof, bonds of 2016 Series A in temporary form, as provided in Section 10 of Article II of the Indenture. Temporary bonds of 2016 Series A if any, may be printed and may be issued in authorized denominations in substantially the form of definitive bonds of 2016 Series A, but without a recital of redemption prices and with such omissions, insertions and variations as may be appropriate for temporary bonds, all as may be determined by the Company.

Interest on any bond of 2016 Series A that is payable on any interest payment date and is punctually paid or duly provided for shall be paid to the person in whose name that bond, or any previous bond to the extent evidencing the same debt as that evidenced by that bond, is registered at the close of business on the regular record date for such interest, which regular record date shall be the fifteenth calendar day (whether or not such day is a business day) immediately preceding the applicable interest payment date. If the Company shall default in the payment of the interest due on any interest payment date on the principal represented by any bond of 2016 Series A, such defaulted interest shall forthwith cease to be payable to the registered holder of that bond on the relevant regular record date by virtue of his having been such holder, and such defaulted interest may be paid to the registered holder of that bond (or any bond or bonds of 2016 Series A issued upon transfer or exchange thereof) on the date of payment of such defaulted interest or, at the election of the Company, to the person in whose name that bond (or any bond or bonds of 2016 Series A issued upon transfer or exchange thereof) is registered on a subsequent record date established by notice given by mail by or on behalf of the Company to the holders of bonds of 2016 Series A not less than ten (10) days preceding such subsequent record date, which subsequent record date shall be at least five (5) days prior to the payment date of such defaulted interest. Interest will be computed on the basis of a 360-day year of twelve 30-day months.

Bonds of 2016 Series A, in definitive and temporary form, may bear such legends as may be necessary to comply with any law or with any rules or regulations made pursuant thereto.

If any interest payment date, date of redemption or the stated maturity for the bonds of 2016 Series A would otherwise be a day that is not a business day, payment of principal and/or interest or premium, if any, with respect to the bonds of 2016 Series A will be paid on the next succeeding business day with the same force and effect as if made on such date and no interest on such payment will accrue from and after such date.

“Business day” means any day other than a day on which banking institutions in the State of New York or the State of Michigan are authorized or obligated pursuant to law or executive order to close.

REDEMPTION OF BONDS OF 2016 SERIES A.	SECTION 2. Bonds of 2016 Series A will be redeemable at the option of the Company, in whole at any time or in part from time to time at the redemption prices set forth below.
	At any time prior to December 1. 2045, the optional redemption price will be equal to the greater of (i) 100% of the principal amount of the bonds of 2016 Series A to be redeemed on the redemption date and (ii) the sum of the present values of the remaining scheduled payments of principal and interest of the bonds of 2016 Series A to be redeemed on the redemption date (not including any portion of any payments of interest accrued to the redemption date) until stated maturity, in each case discounted from their respective scheduled payment dates to such 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 each case, accrued and unpaid interest thereon to the redemption date.
	At any time on or after December 1, 2045, the optional redemption price will be equal to 100% of the principal amount of the bonds of 2016 Series A to be redeemed on the redemption date plus accrued and unpaid interest thereon to the redemption date.
	Notwithstanding the foregoing, installments of interest on the bonds of 2016 Series A 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 redemption date assuming a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such redemption date.
	“Comparable Treasury Issue” means the United States Treasury security selected by the Quotation Agent as having a maturity comparable to the remaining term of the bonds of 2016 Series A that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term of the bonds of 2016 Series A.
	“Comparable Treasury Price” means, with respect to any optional redemption date, (i) the average of the Reference Treasury Dealer Quotations for such redemption date, after excluding the highest and lowest such Reference Treasury Dealer Quotations, or (ii) if the Quotation Agent obtains fewer than three such Reference Treasury Dealer Quotations, the average of all such quotations, or (iii) if only one Reference Treasury Dealer Quotation is received, such quotation.
	“Quotation Agent” means one of the Reference Treasury Dealers appointed by the Company.

	“Reference Treasury Dealer” means (i) each of Barclays Capital Inc., BNP Paribas Securities Corp., Mizuho Securities USA Inc. and Scotia Capital (USA) Inc. (or their respective affiliates which are Primary Treasury Dealers), or their respective successors; provided, however, that if any of the foregoing shall cease to be a primary U.S. government securities dealer in the United States (a “Primary Treasury Dealer”), the Company will substitute therefor another Primary Treasury Dealer, and (ii) any other Primary Treasury Dealer(s) the Company selects.
	“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 redemption date.
	The bonds of 2016 Series A shall be redeemable as aforesaid upon giving notice of such redemption by first class mail, postage prepaid, by or on behalf of the Company at least thirty (30) days, but not more than sixty (60) days, prior to the date fixed for redemption to the registered holders of bonds of 2016 Series A so called for redemption at their last respective addresses appearing on the register thereof, but failure to mail such notice to the registered holders of any bonds of 2016 Series A designated for redemption shall not affect the validity of any such redemption of any other bonds of such series. Interest shall cease to accrue on any bonds of 2016 Series A (or any portion thereof) so called for redemption from and after the date fixed for redemption if payment sufficient to redeem the bonds of 2016 Series A (or such portion) designated for redemption has been duly provided for. Bonds of 2016 Series A redeemed in part only shall be in amounts of $2,000 or any larger amount that is an integral multiple of $1,000.
	If the giving of the notice of redemption shall have been completed, or if provision satisfactory to the Trustee for the giving of such notice shall have been made, and if the Company shall have deposited with the Trustee in trust funds (which shall have become available for payment to the holders of the bonds of 2016 Series A so to be redeemed) sufficient to redeem bonds of 2016 Series A in whole or in part, on the date fixed for redemption, then all obligations of the Company in respect of such bonds (or portions thereof) so to be redeemed and interest due or to become due thereon shall cease and be discharged and the holders of such bonds of 2016 Series A (or portions thereof) shall thereafter be restricted exclusively to such funds for any and all claims of whatsoever nature on their part under the Indenture or in respect of such bonds (or portions thereof) and interest.
	The bonds of 2016 Series A shall not be entitled to or subject to any sinking fund and shall not be redeemable other than as provided in Section 2 hereof.
EXCHANGE AND TRANSFER.	SECTION 3. At the option of the registered holder, any bonds of 2016 Series A, upon surrender thereof for cancellation at the office or agency of the Company in the Borough of Manhattan, the City and State of New York, together with a written instrument of transfer (if so required by the Company or by the Trustee) in form approved by the Company duly executed by the holder or by its duly authorized attorney, shall be exchangeable for a like aggregate principal amount of bonds of 2016 Series A upon the terms and conditions specified herein and in Section 7 of Article II of the Indenture. The Company waives its rights under Section 7 of Article II of the Indenture not to make exchanges or transfers of bonds of 2015 Series A during any period of ten (10) days next preceding any redemption date for such bonds.
	Bonds of 2016 Series A, in definitive and temporary form, may bear such legends as may be necessary to comply with any law or with any rules or regulations made pursuant thereto.
FORM OF BONDS OF 2016 SERIES A.	SECTION 4. The bonds of 2016 Series A and the form of Trustee’s Certificate to be endorsed on such bonds shall be substantially in the following forms, respectively:
	DTE ELECTRIC COMPANY GENERAL AND REFUNDING MORTGAGE BOND 2016 SERIES A
	[This bond is a global security within the meaning of the indenture hereinafter referred to and is registered in the name of a depository or a nominee of a depository. Unless and until it is exchanged in whole or in part for bonds in certificated form, this bond 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 any such nominee to a successor of DTC or a nominee of such successor. Unless this bond is presented by an authorized representative of DTC to the issuer or its agent for registration of transfer, exchange or payment, and any bond 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
	$______________ No. R-___
	DTE ELECTRIC COMPANY (hereinafter called the “Company”), a corporation of the State of Michigan, for value received, hereby promises to pay to [Cede & Co.], or registered assigns, at the Company’s office or agency in the Borough of Manhattan, the City and State of New York, the principal sum of _____________ dollars ($_______) in lawful money of the United States of America on June 1, 2046 (subject to earlier redemption or release) and interest thereon at the rate of 3.70% per annum, in like lawful money, from May 17, 2016 and after the first payment of interest on bonds of this Series has been made or otherwise provided for, from the most recent date to which interest has been paid or otherwise provided for, semi-annually on June 1 and December 1 of each year (commencing December 1, 2016), until the Company’s obligation with respect to payment of said principal shall have been discharged, all as provided, to the extent and in the manner specified in the Indenture hereinafter mentioned and in the supplemental indenture pursuant to which this bond has been issued.
	This bond is one of an authorized issue of bonds of the Company, unlimited as to amount except as provided in the Indenture hereinafter mentioned or any indentures supplemental thereto, and is one of a series of General and Refunding Mortgage Bonds known as 2016 Series A, limited to an aggregate principal amount of $300,000,000, except as otherwise provided in the Indenture hereinafter mentioned. This bond and all other bonds of said series are issued and to be issued under, and are all equally and ratably secured (except insofar as any sinking, amortization, improvement or analogous fund, established in accordance with the provisions of the Indenture hereinafter mentioned, may afford additional security for the bonds of any particular series and except as provided in Section 3 of Article VI of said Indenture) by an Indenture, dated as of October 1, 1924, duly executed by the Company to The Bank of New York Mellon Trust Company, N.A., as successor Trustee, to which Indenture and all indentures supplemental thereto (including the Supplemental Indenture dated as of May 1, 2016) reference is hereby made for a description of the properties and franchises mortgaged and conveyed, the nature and extent of the security, the terms and conditions upon which the bonds are issued and under which additional bonds may be issued, and the rights of the holders of the bonds and of the Trustee in respect of such security (which Indenture and all indentures supplemental thereto, including the Supplemental Indenture dated as of May 1, 2016, are hereinafter collectively called the “Indenture”). As provided in the Indenture, said bonds may be for various principal sums and are issuable in series, which may mature at different times, may bear interest at different rates and may otherwise vary as in said Indenture provided. With the consent of the Company and to the extent permitted by and as provided in the Indenture, the rights and obligations of the Company and of the holders of the bonds and the terms and provisions of the Indenture, or of any indenture supplemental thereto, may be modified or altered in certain respects by affirmative vote of at least eighty-five percent (85%) in amount of the bonds then outstanding, and, if the rights of one or more, but less than all, series of bonds then outstanding are to be affected by the action proposed to be taken, then also by affirmative vote of at least eighty-five percent (85%) in amount of the series of bonds so to be affected (excluding in every instance bonds disqualified from voting by reason of the Company’s interest therein as specified in the Indenture); provided, however, that, without the consent of the holder hereof, no such modification or alteration shall, among other things, affect the terms of payment of the principal of or the interest on this bond, which in those respects is unconditional.
	This bond is not subject to repayment at the option of the holder hereof. Except as provided below, this bond is not redeemable by the Company prior to maturity and is not subject to any sinking fund.

This bond will be redeemable at the option of the Company, in whole at any time or in part from time to time at the redemption prices set forth below. At any time prior to December 1, 2045, the optional redemption price will be equal to the greater of (i) 100% of the principal amount of this bond to be redeemed on the redemption date and (ii) the sum of the present values of the remaining scheduled payments of principal and interest of this bond to be redeemed on the redemption date (not including any portion of any payments of interest accrued to the redemption date) until stated maturity, in each case discounted from their respective scheduled payment dates to such 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 each case, accrued and unpaid interest thereon to the redemption date. At any time on or after December 1, 2045, the optional redemption price will be equal to 100% of the principal amount of this bond to be redeemed on the redemption date plus accrued and unpaid interest thereon to the redemption date.

Notwithstanding the foregoing, installments of interest on this bond 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 redemption date assuming a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such redemption date.

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

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

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

“Reference Treasury Dealer” means (i) each of Barclays Capital Inc., BNP Paribas Securities Corp., Mizuho Securities USA Inc. and Scotia Capital (USA) Inc. (or their respective affiliates which are Primary Treasury Dealers), or their respective successors; provided, however, that if any of the foregoing shall cease to be a primary U.S. government securities dealer in the United States (a “Primary Treasury Dealer”), the Company will substitute therefor another Primary Treasury Dealer, and (ii) any other Primary Treasury Dealer(s) the Company selects.

“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 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 notice has been provided in accordance with the Indenture and funds for the redemption of this bond called for redemption have been made available on the redemption date, this bond will cease to bear interest on the date fixed for redemption. Thereafter, the only right of the holder hereof will be to receive payment of the redemption price.

Under the Indenture, funds may be deposited with the Trustee (which shall have become available for payment), in advance of the redemption date of any of the bonds of 2016 Series A (or portions thereof), in trust for the redemption of such bonds (or portions thereof) and the interest due or to become due thereon, and thereupon all obligations of the Company in respect of such bonds (or portions thereof) so to be redeemed and such interest shall cease and be discharged, and the holders thereof shall thereafter be restricted exclusively to such funds for any and all claims of whatsoever nature on their part under the Indenture or with respect to such bonds (or portions thereof) and interest.

In case an event of default, as defined in the Indenture, shall occur, the principal of all the bonds issued thereunder may become or be declared due and payable, in the manner, with the effect and subject to the conditions provided in the Indenture.

The bonds of this series are issuable only in fully registered form without coupons in denominations of $2,000 and any larger amount that is an integral multiple of $1,000. This Global Security is exchangeable for bonds in definitive form only under certain limited circumstances set forth in the Indenture. As provided in the Indenture and subject to certain limitations therein set forth, bonds of this series are exchangeable for a like aggregate principal amount of bonds of this series of a different authorized denomination, as requested by the registered holder surrendering the same.

This bond is transferable by the registered holder hereof, in person or by his attorney duly authorized in writing, on the books of the Company kept at its office or agency in the Borough of Manhattan, the City and State of New York, upon surrender and cancellation of this bond, and thereupon, a new registered bond of the same series of authorized denominations for a like aggregate principal amount will be issued to the transferee in exchange therefor, and this bond with others in like form may in like manner be exchanged for one or more new bonds of the same series of other authorized denominations, but of the same aggregate principal amount, all as provided and upon the terms and conditions set forth in the Indenture, and upon payment, in any event, of the charges prescribed in the Indenture.

		No recourse shall be had for the payment of the principal of or the interest on this bond, or for any claim based hereon or otherwise in respect hereof or of the Indenture, or of any indenture supplemental thereto, against any incorporator, or against any past, present or future stockholder, director or officer, as such, of the Company, or of any predecessor or successor corporation, either directly or through the Company or any such predecessor or successor corporation, whether for amounts unpaid on stock subscriptions or by virtue of any constitution, statute or rule of law, or by the enforcement of any assessment or penalty or otherwise howsoever; all such liability being, by the acceptance hereof and as part of the consideration for the issue hereof, expressly waived and released by every holder or owner hereof, as more fully provided in the Indenture.
		This bond shall not be valid or become obligatory for any purpose until The Bank of New York Mellon Trust Company, N.A., the Trustee under the Indenture, or its successor thereunder, shall have signed the form of certificate endorsed hereon.
	IN WITNESS WHEREOF, DTE ELECTRIC COMPANY has caused this instrument to be executed by an authorized officer, with his or her manual or facsimile signatures, and its corporate seal, or a facsimile thereof, to be impressed or imprinted hereon and the same to be attested by its Corporate Secretary or Assistant Corporate Secretary by manual or facsimile signature.
	Dated: _____________ DTE ELECTRIC COMPANY
	By: Name: Title:
	[Corporate Seal]
	Attest: By: Name: Title:
	[FORM OF TRUSTEE’S CERTIFICATE]
FORM OF TRUSTEE’S CERTIFICATE.	This bond is one of the bonds, of the series designated therein, described in the within-mentioned Indenture.
	THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A., as Trustee
	By:    Authorized Representative Date:

	PART II.
	RECORDING AND FILING DATA
RECORDING AND FILING OF ORIGINAL INDENTURE.	The Original Indenture and indentures supplemental thereto have been recorded and/or filed and Certificates of Provision for Payment have been recorded as hereinafter set forth.
	The Original Indenture has been recorded as a real estate mortgage and filed as a chattel Mortgage in the offices of the respective Registers of Deeds of certain counties in the State of Michigan as set forth in the Supplemental Indenture dated as of September 1, 1947, has been recorded as a real estate mortgage in the office of the Register of Deeds of Mason County, Michigan as set forth in the Supplemental Indenture dated as of June 15, 1971, has been recorded as a real estate mortgage in the office of the Register of Deeds of Genesee County, Michigan as set forth in the Supplemental Indenture dated as of May 1, 1974, has been recorded as a real estate mortgage in the office of the Register of Deeds of Gratiot County, Michigan on June 18, 2012 at Liber 923 Page 772, has been recorded as a real estate mortgage in the office of the Register of Deeds of Midland County, Michigan on June 18, 2012 at Liber 1555 Page 504, has been recorded as a real estate mortgage in the office of the Register of Deeds of Montcalm County, Michigan on March 6, 2015 at Document Number 2015R-03220 has been filed in the Office of the Secretary of State of Michigan on November 16, 1951 and has been filed and recorded in the office of the Interstate Commerce Commission on December 8, 1969.
RECORDING AND FILING OF SUPPLEMENTAL INDENTURES.	Pursuant to the terms and provisions of the Original Indenture, indentures supplemental thereto heretofore entered into have been Recorded as a real estate mortgage and/or filed as a chattel mortgage or as a financing statement in the offices of the respective Registers of Deeds of certain counties in the State of Michigan, the Office of the Secretary of State of Michigan and the Office of the Interstate Commerce Commission or the Surface Transportation Board, as set forth in supplemental indentures as follows:

SUPPLEMENTAL INDENTURE DATED AS OF	PURPOSE OF SUPPLEMENTAL INDENTURE	RECORDED AND/OR FILED AS SET FORTH IN SUPPLEMENTAL INDENTURE DATED AS OF
June 1, 1925(a)(b)	Series B Bonds	February 1, 1940
August 1, 1927(a)(b)	Series C Bonds	February 1, 1940
February 1, 1931(a)(b)	Series D Bonds	February 1, 1940
June 1, 1931(a)(b)	Subject Properties	February 1, 1940
October 1, 1932(a)(b)	Series E Bonds	February 1, 1940
September 25, 1935(a)(b)	Series F Bonds	February 1, 1940
September 1, 1936(a)(b)	Series G Bonds	February 1, 1940
November 1, 1936(a)(b)	Subject Properties	February 1, 1940
February 1, 1940(a)(b)	Subject Properties	September 1, 1947
December 1, 1940(a)(b)	Series H Bonds and Additional Provisions	September 1, 1947
September 1, 1947(a)(b)(c)	Series I Bonds, Subject Properties and Additional Provisions	November 15, 1951
March 1, 1950(a)(b)(c)	Series J Bonds and Additional Provisions	November 15, 1951
November 15, 1951(a)(b)(c)	Series K Bonds, Additional Provisions and Subject Properties	January 15, 1953
January 15, 1953(a)(b)	Series L Bonds	May 1, 1953
May 1, 1953(a)	Series M Bonds and Subject Properties	March 15, 1954
March 15, 1954(a)(c)	Series N Bonds and Subject Properties	May 15, 1955
May 15, 1955(a)(c)	Series O Bonds and Subject Properties	August 15, 1957
August 15, 1957(a)(c)	Series P Bonds, Additional Provisions and Subject Properties	June 1, 1959
June 1, 1959(a)(c)	Series Q Bonds and Subject Properties	December 1, 1966
December 1, 1966(a)(c)	Series R Bonds, Additional Provisions and Subject Properties	October 1, 1968
October 1, 1968(a)(c)	Series S Bonds and Subject Properties	December 1, 1969
December 1, 1969(a)(c)	Series T Bonds and Subject Properties	July 1, 1970
July 1, 1970(c)	Series U Bonds and Subject Properties	December 15, 1970
December 15, 1970(c)	Series V Bonds and Series W Bonds	June 15, 1971
June 15, 1971(c)	Series X Bonds and Subject Properties	November 15, 1971
November 15, 1971(c)	Series Y Bonds and Subject Properties	January 15, 1973
January 15, 1973(c)	Series Z Bonds and Subject Properties	May 1, 1974
May 1, 1974	Series AA Bonds and Subject Properties	October 1, 1974
October 1, 1974	Series BB Bonds and Subject Properties	January 15, 1975
January 15, 1975	Series CC Bonds and Subject Properties	November 1, 1975
November 1, 1975	Series DDP Nos. 1-9 Bonds and Subject Properties	December 15, 1975
December 15, 1975	Series EE Bonds and Subject Properties	February 1, 1976
February 1, 1976	Series FFR Nos. 1-13 Bonds	June 15, 1976
June 15, 1976	Series GGP Nos. 1-7 Bonds and Subject Properties	July 15, 1976
July 15, 1976	Series HH Bonds and Subject Properties	February 15, 1977
February 15, 1977	Series MMP Bonds and Subject Properties	March 1, 1977
March 1, 1977	Series IIP Nos. 1-7 Bonds, Series JJP Nos. 1-7 Bonds, Series KKP Nos. 1-7 Bonds and Series LLP Nos. 1-7 Bonds	June 15, 1977
June 15, 1977	Series FFR No. 14 Bonds and Subject Properties	July 1, 1977
July 1, 1977	Series NNP Nos. 1-7 Bonds and Subject Properties	October 1, 1977
October 1, 1977	Series GGP Nos. 8-22 Bonds and Series OOP Nos. 1-17 Bonds and Subject Properties	June 1, 1978
June 1, 1978	Series PP Bonds, Series QQP Nos. 1-9 Bonds and Subject Properties	October 15, 1978
October 15, 1978	Series RR Bonds and Subject Properties	March 15, 1979
March 15, 1979	Series SS Bonds and Subject Properties	July 1, 1979
July 1, 1979	Series IIP Nos. 8-22 Bonds, Series NNP Nos. 8-21 Bonds and Series TTP Nos. 1-15 Bonds and Subject Properties	September 1, 1979
September 1, 1979	Series JJP No. 8 Bonds, Series KKP No. 8 Bonds, Series LLP Nos. 8-15 Bonds, Series MMP No. 2 Bonds and Series OOP No. 18 Bonds and Subject Properties	September 15, 1979
September 15, 1979	Series UU Bonds	January 1, 1980
January 1, 1980	1980 Series A Bonds and Subject Properties	April 1, 1980
April 1, 1980	1980 Series B Bonds	August 15, 1980
August 15, 1980	Series QQP Nos. 10-19 Bonds, 1980 Series CP Nos. 1-12 Bonds and 1980 Series DP No. 1-11 Bonds and Subject Properties	August 1, 1981
August 1, 1981	1980 Series CP Nos. 13-25 Bonds and Subject Properties	November 1, 1981
November 1, 1981	1981 Series AP Nos. 1-12 Bonds	June 30, 1982
June 30, 1982	Article XIV Reconfirmation	August 15, 1982
August 15, 1982	1981 Series AP Nos. 13-14 Bonds and Subject Properties	June 1, 1983
June 1, 1983	1981 Series AP Nos. 15-16 Bonds and Subject Properties	October 1, 1984
October 1, 1984	1984 Series AP Bonds and 1984 Series BP Bonds and Subject Properties	May 1, 1985
May 1, 1985	1985 Series A Bonds	May 15, 1985
May 15, 1985	1985 Series B Bonds and Subject Properties	October 15, 1985
October 15, 1985	Series KKP No. 9 Bonds and Subject Properties	April 1, 1986
April 1, 1986	1986 Series A Bonds and Subject Properties	August 15, 1986
August 15, 1986	1986 Series B Bonds and Subject Properties	November 30, 1986
November 30, 1986	1986 Series C Bonds	January 31, 1987
January 31, 1987	1987 Series A Bonds	April 1, 1987
April 1, 1987	1987 Series B Bonds and 1987 Series C Bonds	August 15, 1987
August 15, 1987	1987 Series D Bonds, 1987 Series E Bonds and Subject Properties	November 30, 1987
November 30, 1987	1987 Series F Bonds	June 15, 1989
June 15, 1989	1989 Series A Bonds	July 15, 1989
July 15, 1989	Series KKP No. 10 Bonds	December 1, 1989
December 1, 1989	Series KKP No. 11 Bonds and 1989 Series BP Bonds	February 15, 1990
February 15, 1990	1990 Series A Bonds, 1990 Series B Bonds, 1990 Series C Bonds, 1990 Series D Bonds, 1990 Series E Bonds and 1990 Series F Bonds	November 1, 1990
November 1, 1990	Series KKP No. 12 Bonds	April 1, 1991
April 1, 1991	1991 Series AP Bonds	May 1, 1991
May 1, 1991	1991 Series BP Bonds and 1991 Series CP Bonds	May 15, 1991
May 15, 1991	1991 Series DP Bonds	September 1, 1991
September 1, 1991	1991 Series EP Bonds	November 1, 1991
November 1, 1991	1991 Series FP Bonds	January 15, 1992
January 15, 1992	1992 Series BP Bonds	February 29, 1992 and April 15, 1992
February 29, 1992	1992 Series AP Bonds	April 15, 1992
April 15, 1992	Series KKP No. 13 Bonds	July 15, 1992
July 15, 1992	1992 Series CP Bonds	November 30, 1992
July 31, 1992	1992 Series D Bonds	November 30, 1992
November 30, 1992	1992 Series E Bonds and 1993 Series B Bonds	March 15, 1993
December 15, 1992	Series KKP No. 14 Bonds and 1989 Series BP No. 2 Bonds	March 15, 1993
January 1, 1993	1993 Series C Bonds	April 1, 1993
March 1, 1993	1993 Series E Bonds	June 30, 1993
March 15, 1993	1993 Series D Bonds	September 15, 1993
April 1, 1993	1993 Series FP Bonds and 1993 Series IP Bonds	September 15, 1993
April 26, 1993	1993 Series G Bonds and Amendment of Article II, Section 5	September 15, 1993
May 31, 1993	1993 Series J Bonds	September 15, 1993
June 30, 1993	1993 Series AP Bonds	(d)
June 30, 1993	1993 Series H Bonds	(d)
September 15, 1993	1993 Series K Bonds	March 1, 1994
March 1, 1994	1994 Series AP Bonds	June 15, 1994
June 15, 1994	1994 Series BP Bonds	December 1, 1994
August 15, 1994	1994 Series C Bonds	December 1, 1994
December 1, 1994	Series KKP No. 15 Bonds and 1994 Series DP Bonds	August 1, 1995
August 1, 1995	1995 Series AP Bonds and 1995 Series BP Bonds	August 1, 1999
August 1, 1999	1999 Series AP Bonds, 1999 Series BP Bonds and 1999 Series CP Bonds	(d)
August 15, 1999	1999 Series D Bonds	(d)
January 1, 2000	2000 Series A Bonds	(d)
April 15, 2000	Appointment of Successor Trustee	(d)
August 1, 2000	2000 Series BP Bonds	(d)
March 15, 2001	2001 Series AP Bonds	(d)
May 1, 2001	2001 Series BP Bonds	(d)
August 15, 2001	2001 Series CP Bonds	(d)
September 15, 2001	2001 Series D Bonds and 2001 Series E Bonds	(d)
September 17, 2002	Amendment of Article XIII, Section 3 and Appointment of Successor Trustee	(d)
October 15, 2002	2002 Series A Bonds and 2002 Series B Bonds	(d)
December 1, 2002	2002 Series C Bonds and 2002 Series D Bonds	(d)
August 1, 2003	2003 Series A Bonds	(d)
March 15, 2004	2004 Series A Bonds and 2004 Series B Bonds	(d)
July 1, 2004	2004 Series D Bonds	(d)
February 1, 2005	2005 Series A Bonds and 2005 Series B Bonds	May 15, 2006
April 1, 2005	2005 Series AR Bonds and 2005 Series BR Bonds	May 15, 2006
August 1, 2005	2005 Series DT Bonds	May 15, 2006
September 15, 2005	2005 Series C Bonds	May 15, 2006
September 30, 2005	2005 Series E Bonds	May 15, 2006
May 15, 2006	2006 Series A Bonds	December 1, 2006
December 1, 2006	2006 Series CT Bonds	December 1, 2007
December 1, 2007	2007 Series A Bonds	April 1, 2008
April 1, 2008	2008 Series DT Bonds	May 1, 2008
May 1, 2008	2008 Series ET Bonds	July 1, 2008
June 1, 2008	2008 Series G Bonds	October 1, 2008
July 1, 2008	2008 Series KT Bonds	October 1, 2008
October 1, 2008	2008 Series J Bonds	December 1, 2008
December 1, 2008	2008 Series LT Bonds	March 15, 2009
March 15, 2009	2009 Series BT Bonds	November 1, 2009
November 1, 2009	2009 Series CT Bonds	August 1, 2010
August 1, 2010	2010 Series B Bonds	December 1, 2010
September 1, 2010	2010 Series A Bonds	December 1, 2010
December 1, 2010	2010 Series CT Bonds	March 1, 2011
March 1, 2011	2011 Series AT Bonds	May 15, 2011
May 15, 2011	2011 Series B Bonds	August 1, 2011
August 1, 2011	2011 Series GT Bonds	June 20, 2012
August 15, 2012	2011 Series D, 2011 Series E and 2011 Series F Bonds	June 20, 2012
September 1, 2012	2011 Series H Bonds	June 20, 2012
June 20, 2012	2012 Series A and B Bonds	March 15, 2013
March 15, 2013	2013 Series A Bonds	August 1, 2013
August 1, 2013	2013 Series B Bonds	June 1, 2014
June 1, 2014 July 1, 2014	2014 Series A and B Bonds 2014 Series D and E Bonds	July 1, 2014 March 1, 2015

(a) See Supplemental Indenture dated as of July 1, 1970 for Interstate Commerce Commission filing and recordation information.
(b) See Supplemental Indenture dated as of May 1, 1953 for Secretary of State of Michigan filing information.
(c) See Supplemental Indenture dated as of May 1, 1974 for County of Genesee, Michigan recording and filing information.
(d) Recording and filing information for this Supplemental Indenture has not been set forth in a subsequent Supplemental Indenture.
RECORDING AND FILING OF SUPPLEMENTAL INDENTURE DATED AS OF MARCH 1, 2015.	Further, pursuant to the terms and provisions of the Original Indenture, a Supplemental Indenture dated as of March 1, 2015 providing for the terms of bonds to be issued thereunder of 2015 Series A has heretofore been entered into between the Company and the Trustee and has been filed in the Office of the Secretary of State of Michigan as a financing statement on March 12, 2015 (Filing No. 2015032998-4), has been filed and recorded in the Office of the Surface Transportation Board on March 11, 2015 (Recordation No. 5485-LLLLLL), and has been recorded as a real estate mortgage in the offices of the respective Register of Deeds of certain counties in the State of Michigan, as follows:
COUNTY		RECORDED	LIBER/ INSTRUMENT NO.	PAGE
Genesee County Michigan		3/11/15	201504010034242
Gratiot County Michigan		3/11/15	970	116
Huron County Michigan		3/11/15	1522	568
Ingham County Michigan		3/11/15	2015-008166
Lapeer County Michigan		3/11/15	2754	971
Lenawee County Michigan		3/11/15	2503	112
Livingston County Michigan		3/11/15	2015R-006970
Macomb County Michigan		3/16/15	23293	84
Mason County Michigan		3/11/15	2015R01575
Midland County Michigan		3/11/15	1584	675
Monroe County Michigan		3/12/15	2015R04426
Montcalm County Michigan		3/11/15	2015R-03870
Oakland County Michigan		3/12/15	47953	105
St. Clair County Michigan		3/11/15	4584	81
Sanilac County Michigan		3/11/15	1263	856
Tuscola County Michigan		3/11/15	1325	150
Washtenaw County Michigan		3/11/15	5083	311
Wayne County Michigan		3/26/15	52128	557

RECORDING OF CERTIFICATES OF PROVISION FOR PAYMENT. Certificates of Provision for Payment have been recorded in the offices of the respective Registers of Deeds of certain counties in the State of Michigan, with respect to all bonds of Series A, B, C, D, E, F, G, H, K, L, M, O, W, BB, CC, DDP Nos. 1 and 2, FFR Nos. 1-3, GGP Nos. 1 and 2, IIP No. 1, JJP No. 1, KKP No. 1, LLP No. 1 and GGP No. 8.

	PART III.
	THE TRUSTEE.
TERMS AND CONDITIONS OF ACCEPTANCE OF TRUST BY TRUSTEE.	The Trustee hereby accepts the trust hereby declared and provided, and agrees to perform the same upon the terms and conditions in the Original Indenture, as amended to date and as supplemented by this Supplemental Indenture, and in this Supplemental Indenture set forth, and upon the following terms and conditions:
	The Trustee shall not be responsible in any manner whatsoever for and in respect of the validity or sufficiency of this Supplemental Indenture or the due execution hereof by the Company or for or in respect of the recitals contained herein, all of which recitals are made by the Company solely.

	PART IV.
	MISCELLANEOUS.
CONFIRMATION OF SECTION 318(c) OF TRUST INDENTURE ACT.	Except to the extent specifically provided therein, no provision of this Supplemental Indenture or any future supplemental indenture is intended to modify, and the parties do hereby adopt and confirm, the provisions of Section 318(c) of the Trust Indenture Act which amend and supersede provisions of the Indenture in effect prior to November 15, 1990.
EXECUTION IN COUNTERPARTS.	THIS SUPPLEMENTAL INDENTURE MAY BE SIMULTANEOUSLY EXECUTED IN ANY NUMBER OF COUNTERPARTS, EACH OF WHICH WHEN SO EXECUTED SHALL BE DEEMED TO BE AN ORIGINAL; BUT SUCH COUNTERPARTS SHALL TOGETHER CONSTITUTE BUT ONE AND THE SAME INSTRUMENT.
TESTIMONIUM.	IN WITNESS WHEREOF, DTE ELECTRIC COMPANY AND THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A. HAVE CAUSED THESE PRESENTS TO BE SIGNED IN THEIR RESPECTIVE CORPORATE NAMES BY THEIR RESPECTIVE CHAIRMEN OF THE BOARD, PRESIDENTS, VICE PRESIDENTS, ASSISTANT VICE PRESIDENTS, TREASURERS OR ASSISTANT TREASURERS AND IMPRESSED WITH THEIR RESPECTIVE CORPORATE SEALS, ATTESTED BY THEIR RESPECTIVE SECRETARIES OR ASSISTANT SECRETARIES, ALL AS OF THE DAY AND YEAR FIRST ABOVE WRITTEN.

EXECUTION BY            DTE ELECTRIC COMPANY

COMPANY.

By: /s/Edward J. Solomon

(Corporate Seal) Name:    Edward J. Solomon

Title:    Assistant Treasurer

Attest:

By: /s/Lisa A. Muschong

Name:    Lisa A. Muschong

Title:     Corporate Secretary

Signed, sealed and delivered by

DTE ELECTRIC COMPANY

in the presence of:

/s/Kathleen Hier

Name: Kathleen Hier

/s/ Andrew T. Hayner

Name: Andrew T. Hayner

STATE OF MICHIGAN    )

) SS

COUNTY OF WAYNE    )

ACKNOWLEDG-MENT OF EXECUTION BY COMPANY.

On this 12th day of May, 2016, before me, the subscriber, a Notary Public within and for the County of Wayne, in the State of Michigan, acting in the County of Wayne, personally appeared Edward J. Solomon, to me personally known, who, being by me duly sworn, did say that he does business at One Energy Plaza, Detroit, Michigan 48226 and is the Assistant Treasurer of DTE ELECTRIC COMPANY, one of the corporations described in and which executed the foregoing instrument; that he knows the corporate seal of the said corporation and that the seal affixed to said instrument is the corporate seal of said corporation; and that said instrument was signed and sealed in behalf of said corporation by authority of its Board of Directors and that he subscribed his name thereto by like authority; and said Edward J. Solomon acknowledged said instrument to be the free act and deed of said corporation.

(Notarial Seal)

/s/Elizabeth Ellen Kochevar Elizabeth Ellen Kochevar Notary Public, Wayne County, MI Acting in Wayne My Commission Expires: November 16, 2021

EXECUTION BY THE BANK OF NEW YORK MELLON TRUST

TRUSTEE.    COMPANY, N.A.

By:/s/Valere Boyd

(Corporate Seal)    Name:    Valere Boyd

Title:     Vice President

Attest:

By: /s/Teresa Petta

Name:    Teresa Petta

Title:    Vice President

Signed, sealed and delivered by

THE BANK OF NEW YORK MELLON

TRUST COMPANY, N.A.

in the presence of

/s/Manjari Purkayastha

Name: Manjari Purkayastha

/s/Raymond Torres

Name: Raymond Torres

STATE OF CALIFORNIA    )

) SS

COUNTY OF LOS ANGELES)

ACKNOWLEDG-MENT OF EXECUTION BY TRUSTEE.

On this 12th day of May, 2016, before me, the subscriber, a Notary Public within and for the County of Los Angeles, in the State of California, acting in the County of Los Angeles, personally appeared Valere Boyd to me personally known, who, being by me duly sworn, did say that her business office is located at 2 North LaSalle Street, Suite 1020 Chicago, Illinois 60602, and she is an Authorized Officer of THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A., one of the corporations described in and which executed the foregoing instrument; that she knows the corporate seal of the said corporation and that the seal affixed to said instrument is the corporate seal of said corporation; and that said instrument was signed and sealed in behalf of said corporation by authority of its Board of Directors and that she subscribed her name thereto by like authority; and said Valere Boyd acknowledged said instrument to be the free act and deed of said corporation.

(Notarial Seal)

/s/Marvin G. Cuenca NAME: Marvin G. Cuenca Notary Public, Acting in Los Angeles, CA My Commission Expires: March 27, 2017

STATE OF MICHIGAN    )

) SS

COUNTY OF WAYNE    )

AFFIDAVIT AS TO CONSIDERATION AND GOOD FAITH. Edward J. Solomon, being duly sworn, says: that he is the Assistant Treasurer of DTE ELECTRIC COMPANY, the Mortgagor named in the foregoing instrument, and that he has knowledge of the facts in regard to the making of said instrument and of the consideration therefor; that the consideration for said instrument was and is actual and adequate, and that the same was given in good faith for the purposes in such instrument set forth.

/s/Edward J. Solomon

Name: Edward J. Solomon

Title: Assistant Treasurer

DTE Electric Company

Sworn to before me this 12th day of May, 2016

(Notarial Seal)        

/s/Elizabeth Ellen Kochevar

Elizabeth Ellen Kochevar

Notary Public, Wayne County, MI

Acting in Wayne

My Commission Expires: November 16, 2021

This instrument was drafted by:

Andrew T. Hayner, Esq.

One Energy Plaza

688 WCB

Detroit, Michigan 48226

When recorded return to:

Andrew T. Hayner, Esq.

One Energy Plaza

688 WCB

Detroit, Michigan 48226

11

EX-4.294

EXHIBIT 4.294

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

__________________________

SUPPLEMENTAL INDENTURE
DATED AS OF JUNE 1, 2016

__________________________

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

PROVIDING FOR

2015 SERIES BR 3.30% SENIOR NOTES DUE 2022

1

SUPPLEMENTAL INDENTURE, dated as of the 1st day of June, 2016, 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 “2015 Series BR 3.30% Senior Notes due 2022”; 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 1
DEFINITIONS AND OTHER
PROVISIONS OF GENERAL APPLICATION

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

1

“Business Day” means any day other than a day on which banking institutions in the State of New York or the State of Michigan are authorized or obligated pursuant to law or executive order to close.

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

ARTICLE 2

TITLE AND TERMS OF THE 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 “2015 Series BR 3.30% Senior Notes due 2022” (the “Notes”). The Stated Maturity on which the principal of the Notes shall be due and payable will be June 15, 2022.

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 $300,000,000 (except as provided in Section 301(2) of the Original Indenture); provided that the Company may, without the consent of the Holders of the Outstanding 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 (other than the date of issuance, public offering price, the initial interest payment date and, in some circumstances, interest accrual dates), 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 $1,000 and integral multiples thereof. The Notes will initially be issued in global form (the “Global Notes”) under a book-entry

2

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 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 3.30% per annum on the principal amount thereof from June 13, 2016, 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 June 15 and December 15 of each year (each such date, an “Interest Payment Date”), commencing on June 15, 2016. 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

3

Predecessor Securities) is registered at the close of business on a Special Record Date to be fixed for the payment of such defaulted interest in accordance with Section 307 of the Original Indenture, 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 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, in whole or in part, at any time 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 3

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.

4

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.

5

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

Mark C. Rolling

Vice President and Treasurer

ATTEST:

By: /s/Timothy E. Kraepel

Timothy E. Kraepel

Assistant Corporate Secretary

6

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

By:    /s/R. Tarnas

Name:    R. Tarnas

Title: Vice President

1

EXHIBIT A

FORM OF NOTE

GLOBAL SECURITY LEGEND

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

CUSIP NO.  233331 AV9                        ___________________

DTE ENERGY COMPANY
2015 SERIES BR 3.30% SENIOR NOTES DUE 2022

DTE ENERGY COMPANY, a corporation duly organized and existing under the laws of the State of Michigan (herein referred to as the “Company”, which term includes any successor Person under the Indenture hereinafter referred to), for value received, hereby promises to pay to CEDE & CO., or registered assigns, the principal sum of $__________ on June 15, 2022 (“Stated Maturity” with respect to the principal of this Note), unless previously redeemed, and to pay interest at the rate of 3.30% per annum on said principal sum from June 13, 2016 or from the most recent Interest Payment Date to which interest has been paid or duly provided for, until the principal of this Note becomes due and payable, and on any overdue principal and premium and (to the extent that payment of such interest is enforceable under applicable law) on any overdue installment of interest at the same rate per annum during such overdue period. Interest on this Note will be payable semiannually in arrears on June 15 and December 15 of each year (each such date, an “Interest Payment Date”), commencing June 15, 2016. 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

A-1

the next succeeding day which is a Business Day (and without any interest or other payment in respect of any such delay), in each case with the same force and effect as if made on such date.

A “Business Day” means any day other than a day on which banking institutions in the State of New York or the State of Michigan are authorized or obligated pursuant to law or executive order to close. 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 “2015 Series BR 3.30% Senior Notes due 2022” (the “Notes”), initially limited to an aggregate principal amount of $300,000,000 (except for Notes authenticated and delivered upon transfer of, or in exchange for, or in lieu of other Notes, and except as further provided in the Indenture), all issued or to be issued under and pursuant to an Amended and Restated Indenture, dated as of April 9, 2001, as supplemented through and including the Supplemental Indenture dated as of June 1, 2016 (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.

A-2

This Note will be redeemable at the option of the Company, in whole or in part, at any time (any such date of optional redemption, an “Optional Redemption Date,” which shall be a “Redemption Date” for purposes of the Indenture) at the redemption prices set forth below. At any time prior to the Par Call Date, 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 on the Optional Redemption Date and (ii) the sum of the present values of the remaining scheduled payments of principal and interest on this Note to be redeemed that would be due if this Note matured on the Par Call Date (not including any portion of any payments of interest accrued to, but not including, the Optional Redemption Date), discounted to the 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 each case, accrued and unpaid interest thereon to the Optional Redemption Date. 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 Note to be redeemed, plus accrued and unpaid interest thereon to the redemption date.

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

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

“Comparable Treasury Issue” means the United States Treasury security selected by the Quotation Agent as having a maturity comparable to the remaining term of this Note to be redeemed that would be utilized (assuming for this purpose that this Note matured on 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 to 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 of such Reference Treasury Dealer Quotations, or (ii) if the Quotation Agent obtains fewer than three of 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 April 15, 2022.

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

“Reference Treasury Dealer” means: (i) each of J.P. Morgan Securities LLC, TD Securities (USA) LLC and UBS Securities LLC (or their respective affiliates which are Primary Treasury Dealers), and their respective successors; provided, however, that if any of the foregoing shall cease

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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.

“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 sent at least 30 days but not more than 60 days before the Optional Redemption Date to the Holder hereof at its registered address.

If at the time notice of redemption has been given, the Company has not deposited with the Trustee (or a Paying Agent) monies sufficient to redeem all of the notes called for redemption, such notice shall state that it is subject to the receipt of the redemption monies by the Trustee (or a Paying Agent) on or before the redemption date and such notice will be of no effect unless such monies are so received before such date.

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 Notes shall be selected in accordance with the procedures of DTC or, if not represented by a Global Note, in a manner the Trustee may deem appropriate.

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

A-4

amount thereof, or reduce the rate of interest thereon, or reduce any premium payable upon the redemption thereof or (ii) reduce the percentage of Notes, the Holders of which are required to consent to any amendment or waiver or for certain other matters as set forth in the Indenture. The Indenture also contains provisions permitting (i) the registered Holders of 66 2/3% in aggregate principal amount of the Securities at the time outstanding affected thereby, on behalf of the registered Holders of the Securities, to waive compliance by the Company with certain provisions of the Indenture and (ii) the registered Holders of not less than a majority in aggregate principal amount of the Securities at the time outstanding affected thereby, on behalf of the registered Holders of the Securities, to waive certain past defaults under the Indenture and their consequences. Any such consent or waiver by the registered Holder of this Note (unless revoked as provided in the Indenture) shall be conclusive and binding upon such registered Holder and upon all future registered Holders and owners of this Note and of any Note issued in exchange hereof or in place hereof (whether by registration of transfer or otherwise), irrespective of whether or not any notation of such consent or waiver is made upon this Note.

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

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

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

The Notes are issuable only in fully registered form without coupons in denominations of $1,000 and any integral multiple thereof. This Global Note is exchangeable for Notes in definitive form only under certain limited circumstances set forth in the Indenture. The Notes so issued are issuable only in registered form without coupons in denominations of $1,000 and any integral

A-5

multiple thereof. As provided in the Indenture and subject to certain limitations therein set forth, the Notes are exchangeable for a like aggregate principal amount of the Notes of a different authorized denomination, as requested by the registered Holder surrendering the same.

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

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

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

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

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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: _______________

A-8

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

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

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

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

Dated:________________________

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

A-9

EX-10.101

March 17, 2016 Exhibit 10.101

To the Lenders parties to the

Credit Agreement referred

to below

Re:    Request for Extension of Termination Date

Ladies and Gentlemen:

Pursuant to that certain Third Amended and Restated Five-Year Credit Agreement, dated as of April 16, 2015 (as amended, supplemented or otherwise modified from time to time, the "Credit Agreement", terms defined therein and not otherwise defined herein being used herein as defined therein), among DTE Energy Company (the "Company"), the Lenders (as defined in the Credit Agreement) parties thereto and Citibank, N.A., as Administrative Agent for the Lenders (the "Administrative Agent"), the Company hereby requests that, effective as of April 16, 2016, the Termination Date be extended for a period of one year from the Termination Date now in effect, as provided in Section 2.19 of the Credit Agreement.

You must give notice to the Administrative Agent whether or not you agree to the requested extension. Under Section 2.19(b) of the Credit Agreement, such notice generally must be received no later than 10 Business Days after the Administrative Agent receives this request; however, the Company hereby waives this deadline and sets the Lender Notice Date as April 6, 2016.

The Company hereby certifies that the following statements are true on the date hereof, and will be true on the extension of the Termination Date:

(1)    no Default or Event of Default shall have occurred and be continuing on the applicable Extension Date and immediately after giving effect thereto; and

(2)    the representations and warranties of the Borrower set forth in the Credit Agreement are true and correct on and as of the applicable Extension Date and after giving effect thereto, as though made on and as of such date (or to the extent that such representations and warranties specifically refer to an earlier date, as of such earlier date).

This notice and request is subject in all respects to the terms of the Credit Agreement, is irrevocable and shall be effective only if received by the Administrative Agent no later than March 17, 2016.

DTE ENERGY COMPANY

By : /s/David R. Murphy

Title : Assistant Treasurer

1

EX-10.102

March 17, 2016 Exhibit 10.102

To the Lenders parties to the

Credit Agreement referred

to below

Re:    Request for Extension of Termination Date

Ladies and Gentlemen:

Pursuant to that certain Third Amended and Restated Five-Year Credit Agreement, dated as of April 16, 2015 (as amended, supplemented or otherwise modified from time to time, the "Credit Agreement", terms defined therein and not otherwise defined herein being used herein as defined therein), among DTE Gas Company (the "Company"), the Lenders (as defined in the Credit Agreement) parties thereto and JPMorgan Chase Bank, N.A., as Administrative Agent for the Lenders (the "Administrative Agent"), the Company hereby requests that, effective as of April 16, 2016, the Termination Date be extended for a period of one year from the Termination Date now in effect, as provided in Section 2.18 of the Credit Agreement.

You must give notice to the Administrative Agent whether or not you agree to the requested extension. Under Section 2.18(b) of the Credit Agreement, such notice generally must be received no later than 10 Business Days after the Administrative Agent receives this request; however, the Company hereby waives this deadline and sets the Lender Notice Date as April 6, 2016.

The Company hereby certifies that the following statements are true on the date hereof, and will be true on the extension of the Termination Date:

(1)    no Default or Event of Default shall have occurred and be continuing on the applicable Extension Date and immediately after giving effect thereto; and

(2)    the representations and warranties of the Borrower set forth in the Credit Agreement are true and correct on and as of the applicable Extension Date and after giving effect thereto, as though made on and as of such date (or to the extent that such representations and warranties specifically refer to an earlier date, as of such earlier date).

This notice and request is subject in all respects to the terms of the Credit Agreement, is irrevocable and shall be effective only if received by the Administrative Agent no later than March 17, 2016.

DTE GAS COMPANY

By : /s/David R. Murphy

Title: Assistant Treasurer

1

EX-10.103

March 17, 2016                                    Exhibit     10.103    

To the Lenders parties to the

Credit Agreement referred

to below

Re:    Request for Extension of Termination Date

Ladies and Gentlemen:

Pursuant to that certain Third Amended and Restated Five-Year Credit Agreement, dated as of April 16, 2015 (as amended, supplemented or otherwise modified from time to time, the "Credit Agreement", terms defined therein and not otherwise defined herein being used herein as defined therein), among DTE Electric Company (the "Company"), the Lenders (as defined in the Credit Agreement) parties thereto and Barclays Bank PLC, as Administrative Agent for the Lenders (the "Administrative Agent"), the Company hereby requests that, effective as of April 16, 2016, the Termination Date be extended for a period of one year from the Termination Date now in effect, as provided in Section 2.18 of the Credit Agreement.

You must give notice to the Administrative Agent whether or not you agree to the requested extension. Under Section 2.18(b) of the Credit Agreement, such notice generally must be received no later than 10 Business Days after the Administrative Agent receives this request; however, the Company hereby waives this deadline and sets the Lender Notice Date as April 6, 2016.

The Company hereby certifies that the following statements are true on the date hereof, and will be true on the extension of the Termination Date:

(1)    no Default or Event of Default shall have occurred and be continuing on the applicable Extension Date and immediately after giving effect thereto; and

(2)    the representations and warranties of the Borrower set forth in the Credit Agreement are true and correct on and as of the applicable Extension Date and after giving effect thereto, as though made on and as of such date (or to the extent that such representations and warranties specifically refer to an earlier date, as of such earlier date).

This notice and request is subject in all respects to the terms of the Credit Agreement, is irrevocable and shall be effective only if received by the Administrative Agent no later than March 17, 2016.

DTE ELECTRIC COMPANY

By : /s/David R. Murphy

Title : Assistant Treasurer

1

EX-12.69

Exhibit 12.69

DTE Energy Company

Computation of Ratio of Earnings to Fixed Charges

	Six Months Ended		Year Ended December 31,
	June 30, 2016		2015			2014			2013			2012		2011
	(In millions)
Earnings:
Pretax earnings	$	518	$	950		$	1,275		$	922		$	960	$	991
Adjustments	7		(3		)	(15		)	(26		)	71		4
Fixed charges	237		473			453			461			463		520
Net earnings	$	762	$	1,420		$	1,713		$	1,357		$	1,494	$	1,515
Fixed Charges:
Interest expense	$	225	$	446		$	424		$	432		$	441	$	490
Adjustments	12		27			29			29			22		30
Fixed charges	$	237	$	473		$	453		$	461		$	463	$	520
Ratio of earnings to fixed charges	3.22		3.00			3.78			2.94			3.23		2.91

EX-12.70

Exhibit 12.70

DTE Electric Company

Computation of Ratio of Earnings to Fixed Charges

	Six Months Ended			Year Ended December 31,
	June 30, 2016			2015			2014			2013			2012			2011
	(In millions)
Earnings:
Pretax earnings	$	408		$	836		$	830		$	741		$	768		$	704
Adjustments	(4		)	(11		)	(11		)	(7		)	(7		)	(2		)
Fixed charges	138			277			267			281			286			310
Net earnings	$	542		$	1,102		$	1,086		$	1,015		$	1,047		$	1,012
Fixed Charges:
Interest expense	$	129		$	255		$	247		$	264		$	269		$	287
Adjustments	9			22			20			17			17			23
Fixed charges	$	138		$	277		$	267		$	281		$	286		$	310
Ratio of earnings to fixed charges	3.93			3.98			4.07			3.61			3.66			3.26

EX-31.117

Exhibit 31.117

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:	July 26, 2016
Gerard M. Anderson Chairman of the Board and Chief Executive Officer of DTE Energy Company

EX-31.118

Exhibit 31.118

FORM 10-Q CERTIFICATION

I, Peter B. Oleksiak, certify that:

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

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

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

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

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

b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

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

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

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

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

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

/S/ PETER B. OLEKSIAK	Date:	July 26, 2016
Peter B. Oleksiak Senior Vice President and Chief Financial Officer of DTE Energy Company

EX-31.119

Exhibit 31.119

FORM 10-Q CERTIFICATION

I, Gerard M. Anderson, certify that:

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

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

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

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

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

b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

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

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

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

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

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

/S/ GERARD M. ANDERSON	Date:	July 26, 2016
Gerard M. Anderson  Chairman of the Board and Chief Executive Officer of DTE Electric Company

EX-31.120

Exhibit 31.120

FORM 10-Q CERTIFICATION

I, Peter B. Oleksiak, certify that:

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

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

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

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

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

b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

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

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

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

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

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

/S/ PETER B. OLEKSIAK	Date:	July 26, 2016
Peter B. Oleksiak Senior Vice President and Chief Financial Officer of DTE Electric Company

EX-32.117

Exhibit 32.117

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of DTE Energy Company (the “Company”) for the quarter ended June 30, 2016, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Gerard M. Anderson, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge and belief:

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

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

Date:	July 26, 2016	/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-32.118

Exhibit 32.118

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of DTE Energy Company (the “Company”) for the quarter ended June 30, 2016, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Peter B. Oleksiak, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge and belief:

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

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

Date:	July 26, 2016	/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-32.119

Exhibit 32.119

CERTIFICATION PURSUANT TO

18 U. S. C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of DTE Electric Company (the “Company”) for the quarter ended June 30, 2016, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Gerard M. Anderson, certify, pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge and belief:

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

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

Date:	July 26, 2016	/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-32.120

Exhibit 32.120

CERTIFICATION PURSUANT TO

18 U. S. C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of DTE Electric Company (the “Company”) for the quarter ended June 30, 2016, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Peter B. Oleksiak, certify, pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge and belief:

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

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

Date:	July 26, 2016	/S/ PETER B. OLEKSIAK
		Peter B. Oleksiak Senior Vice President and Chief Financial Officer of DTE Electric Company

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

XML

Document and Entity Information	6 Months Ended
	Jun. 30, 2016 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	Jun. 30, 2016
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Common Stock, Shares Outstanding	179,435,004
DTE Electric
Entity Registrant Name	DTE ELECTRIC CO
Entity Central Index Key	0000028385
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-Q
Document Period End Date	Jun. 30, 2016
Document Fiscal Year Focus	2016
Document Fiscal Period Focus	Q2
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		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Utility operations	$ 1,435	$ 1,357	$ 3,099	$ 3,198
Non-utility operations	827	911	1,729	2,054
Operating Revenues	2,262	2,268	4,828	5,252
Operating Expenses
Fuel, purchased power, and gas — utility	414	434	979	1,127
Fuel, purchased power, and gas — non-utility	717	769	1,493	1,774
Operation and maintenance	542	532	1,058	1,058
Depreciation and amortization	243	220	472	429
Taxes other than income	91	91	190	191
Asset (gains) losses and impairments, net	(1)	18	(1)	8
Operating Expenses	2,006	2,064	4,191	4,587
Operating Income	256	204	637	665
Other (Income) and Deductions
Interest expense	114	115	227	225
Interest income	(3)	(2)	(14)	(6)
Other income	(57)	(49)	(109)	(100)
Other expenses	7	9	15	19
Total Other (Income) and Deductions	61	73	119	138
Income Before Income Taxes	195	131	518	527
Income Tax Expense	50	26	133	148
Net Income	145	105	385	379
Less: Net Loss Attributable to Noncontrolling Interests	(7)	(4)	(14)	(3)
Net Income (Loss) Attributable to DTE Energy Company/DTE Electric	$ 152	$ 109	$ 399	$ 382
Basic Earnings per Common Share
Net Income Attributable to DTE Energy Company (in dollars per share)	$ 0.84	$ 0.61	$ 2.22	$ 2.13
Diluted Earnings per Common Share
Net Income Attributable to DTE Energy Company (in dollars per share)	$ 0.84	$ 0.61	$ 2.22	$ 2.13
Weighted Average Common Shares Outstanding
Basic (in shares)	179	179	179	179
Diluted (in shares)	180	179	180	179
Dividends Declared per Common Share (in dollars per share)	$ 0.73	$ 0.69	$ 1.46	$ 1.38
DTE Electric
Utility operations	$ 1,215	$ 1,147	$ 2,368	$ 2,350
Operating Expenses
Fuel and purchased power — utility	361	381	696	771
Operation and maintenance	332	319	656	636
Depreciation and amortization	187	165	363	320
Taxes other than income	70	68	143	141
Operating Expenses	950	933	1,858	1,868
Operating Income	265	214	510	482
Other (Income) and Deductions
Interest expense	65	67	130	130
Interest income	0	0	(8)	0
Other income	(17)	(13)	(33)	(28)
Other expenses	6	8	13	17
Total Other (Income) and Deductions	54	62	102	119
Income Before Income Taxes	211	152	408	363
Income Tax Expense	76	53	146	127
Net Income (Loss) Attributable to DTE Energy Company/DTE Electric	$ 135	$ 99	$ 262	$ 236

XML

Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Net Income	$ 145	$ 105	$ 385	$ 379
Net Income (Loss)	152	109	399	382
Other comprehensive income (loss), net of tax:
Benefit obligations, net of taxes of $2 and $2, respectively	(1)	3	2	6
Foreign currency translation	(1)	1	1	(2)
Other comprehensive income (loss)	(2)	4	3	4
Comprehensive income	143	109	388	383
Less comprehensive loss attributable to noncontrolling interests	(7)	(4)	(14)	(3)
Comprehensive income attributable to DTE Energy Company/DTE Electric	150	113	402	386
DTE Electric
Net Income (Loss)	135	99	262	236
Other comprehensive income (loss), net of tax:
Transfer of benefit obligations, net of taxes of $— and $18 in 2015, respectively	0	0	0	28
Comprehensive income attributable to DTE Energy Company/DTE Electric	$ 135	$ 99	$ 262	$ 264

XML

Consolidated Statements of Comprehensive Income (Parentheticals) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Tax effect on benefit obligation	$ (1)	$ 2	$ 1	$ 4
DTE Electric
Tax effect on benefit obligation - transfer	$ 0	$ 0	$ 0	$ 18

XML

Consolidated Statements of Financial Position (Unaudited) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Current Assets
Cash and cash equivalents	$ 32	$ 37
Restricted cash	22	23
Accounts receivable (less allowance for doubtful accounts)
Customer	1,180	1,276
Other	82	72
Inventories
Fuel and gas	385	480
Materials and supplies	332	323
Notes receivable
Derivative assets	53	129
Regulatory assets	11	32
Other	161	203
Total Current Assets	2,258	2,575
Investments
Nuclear decommissioning trust funds	1,275	1,236
Investment in equity method investees	633	514
Other	193	186
Total Investments	2,101	1,936
Property
Property, plant, and equipment	28,371	28,121
Less accumulated depreciation and amortization	(10,076)	(10,087)
Property, plant and equipment, net	18,295	18,034
Other Assets
Goodwill	2,018	2,018
Regulatory assets	3,729	3,692
Intangible assets	97	89
Notes receivable	77	85
Derivative assets	35	54
Other	159	179
Total Noncurrent Assets	6,115	6,117
Total Assets	28,769	28,662
Accounts payable
Accounts payable	745	809
Accrued interest	91	89
Dividends payable	269	131
Short-term borrowings	175	499
Current portion long-term debt, including capital leases	165	473
Derivative liabilities	47	57
Gas inventory equalization	46	0
Regulatory liabilities	37	41
Short-term borrowings
Other	308	429
Total Current Liabilities	1,883	2,528
Long-Term Debt (net of current portion)
Mortgage bonds, notes, and other	8,551	8,265
Junior subordinated debentures	780	480
Capital lease obligations	12	15
Total Long-Term Debt (net of current portion)	9,343	8,760
Other Liabilities
Deferred income taxes	4,026	3,923
Regulatory liabilities	572	569
Asset retirement obligations	2,238	2,194
Unamortized investment tax credit	93	62
Derivative liabilities	94	86
Accrued pension liability	1,136	1,133
Accrued postretirement liability	175	228
Nuclear decommissioning	184	177
Other	226	207
Total Noncurrent Liabilities	8,744	8,579
Commitments and Contingencies
Equity
Common stock	4,129	4,123
Retained earnings	4,791	4,794
Accumulated other comprehensive income (loss)	(142)	(145)
Total DTE Energy Company Equity	8,778	8,772
Noncontrolling interests	21	23
Total Equity	8,799	8,795
Total Liabilities and Equity	28,769	28,662
DTE Electric
Current Assets
Cash and cash equivalents	13	15
Accounts receivable (less allowance for doubtful accounts)
Customer	694	657
Affiliates	9	14
Other	34	40
Inventories
Fuel and gas	233	271
Materials and supplies	264	251
Notes receivable
Affiliates	62	0
Other	5	0
Regulatory assets	9	17
Other	58	66
Total Current Assets	1,381	1,331
Investments
Nuclear decommissioning trust funds	1,275	1,236
Other	31	35
Total Investments	1,306	1,271
Property
Property, plant, and equipment	21,479	21,391
Less accumulated depreciation and amortization	(7,577)	(7,646)
Property, plant and equipment, net	13,902	13,745
Other Assets
Regulatory assets	2,998	2,969
Intangible assets	47	34
Prepaid Postretirement Costs, Affiliates	24	24
Other	121	144
Total Noncurrent Assets	3,190	3,171
Total Assets	19,779	19,518
Accounts payable
Affiliates	50	40
Other	313	329
Accrued interest	63	62
Accrued vacation	46	44
Current portion long-term debt, including capital leases	148	157
Regulatory liabilities	34	19
Short-term borrowings
Affiliates	108	75
Other	0	272
Other	74	94
Total Current Liabilities	836	1,092
Long-Term Debt (net of current portion)
Mortgage bonds, notes, and other	5,735	5,437
Capital lease obligations	12	15
Total Long-Term Debt (net of current portion)	5,747	5,452
Other Liabilities
Deferred income taxes	3,605	3,498
Regulatory liabilities	214	199
Asset retirement obligations	2,057	2,020
Unamortized investment tax credit	89	58
Nuclear decommissioning	184	177
Accrued pension liability — affiliates	981	976
Accrued postretirement liability — affiliates	273	307
Other	68	66
Total Noncurrent Liabilities	7,471	7,301
Commitments and Contingencies
Equity
Common stock	4,086	4,086
Retained earnings	1,637	1,585
Accumulated other comprehensive income (loss)	2	2
Total DTE Energy Company Equity	5,725	5,673
Total Liabilities and Equity	$ 19,779	$ 19,518

XML

Consolidated Statements of Financial Position (Unaudited) (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Allowance for doubtful accounts	$ 42	$ 49
Shareholder’s Equity
Common stock, par value (in dollars per share)
Common stock, shares authorized (in shares)	400,000,000	400,000,000
Common stock, shares issued (in shares)	179,435,004	179,470,213
Common stock, shares outstanding (in shares)	179,435,004	179,470,213
DTE Electric
Allowance for doubtful accounts	$ 24	$ 28
Shareholder’s Equity
Common stock, par value (in dollars per share)	$ 10	$ 10
Common stock, shares authorized (in shares)	400,000,000	400,000,000
Common stock, shares issued (in shares)	138,632,324	138,632,324
Common stock, shares outstanding (in shares)	138,632,324	138,632,324

XML

Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Operating Activities
Net Income	$ 385	$ 379
Net Income (Loss)	399	382
Adjustments to reconcile Net Income to net cash from operating activities:
Depreciation and amortization	472	429
Nuclear fuel amortization	29	28
Allowance for equity funds used during construction	(10)	(10)
Deferred income taxes	134	148
Equity earnings of equity method investees	(35)	(32)
Dividends from equity method investees	33	30
Asset (gains) losses and impairments, net	0	(8)
Changes in assets and liabilities:
Accounts receivable, net	81	234
Inventories	86	73
Accounts payable	(10)	(119)
Gas inventory equalization	46	56
Accrued pension liability	3	(96)
Accrued postretirement liability	(53)	(192)
Derivative assets and liabilities	93	48
Regulatory assets and liabilities	71	89
Other current and noncurrent assets and liabilities	(53)	107
Net cash from operating activities	1,272	1,180
Investing Activities
Plant and equipment expenditures — utility	(797)	(781)
Plant and equipment expenditures — non-utility	(64)	(114)
Acquisition	0	(241)
Proceeds from sale of assets	0	16
Restricted cash for debt redemption, principally Securitization, net	1	99
Proceeds from sale of nuclear decommissioning trust fund assets	741	440
Investment in nuclear decommissioning trust funds	(744)	(446)
Distributions from equity method investees	7	9
Contributions to equity method investees	(121)	(32)
Other	39	14
Net cash used for investing activities	(938)	(1,036)
Financing Activities
Issuance of long-term debt, net of issuance costs	588	793
Redemption of long-term debt	(313)	(118)
Short-term borrowings, net	(324)	(398)
Issuance of common stock	0	9
Repurchase of common stock	(33)	0
Dividends on common stock	(262)	(246)
Other	5	(2)
Net cash from (used for) financing activities	(339)	38
Net Increase (Decrease) in Cash and Cash Equivalents	(5)	182
Cash and Cash Equivalents at Beginning of Period	37	48
Cash and Cash Equivalents at End of Period	32	230
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	154	206
DTE Electric
Operating Activities
Net Income (Loss)	262	236
Adjustments to reconcile Net Income to net cash from operating activities:
Depreciation and amortization	363	320
Nuclear fuel amortization	29	28
Allowance for equity funds used during construction	(9)	(10)
Deferred income taxes	146	127
Changes in assets and liabilities:
Accounts receivable, net	(32)	(43)
Inventories	25	(15)
Accounts payable	32	(28)
Accrued pension liability — affiliates	5	(183)
Accrued postretirement liability — affiliates	(34)	(150)
Regulatory assets and liabilities	82	38
Other current and noncurrent assets and liabilities	(44)	48
Net cash from operating activities	825	368
Investing Activities
Plant and equipment expenditures	(640)	(665)
Acquisition	0	(241)
Proceeds from sale of assets	6	0
Restricted cash for debt redemption, principally Securitization, net	0	96
Notes receivable from affiliate	(62)	8
Proceeds from sale of nuclear decommissioning trust fund assets	741	440
Investment in nuclear decommissioning trust funds	(744)	(446)
Transfer of Rabbi Trust assets to affiliate	0	137
Other	36	14
Net cash used for investing activities	(663)	(657)
Financing Activities
Issuance of long-term debt, net of issuance costs	297	495
Redemption of long-term debt	(10)	(115)
Capital contribution by parent company	0	300
Short-term borrowings, net — affiliate	33	(30)
Short-term borrowings, net — other	(272)	(50)
Dividends on common stock	(210)	(199)
Other	(2)	(3)
Net cash from (used for) financing activities	(164)	398
Net Increase (Decrease) in Cash and Cash Equivalents	(2)	109
Cash and Cash Equivalents at Beginning of Period	15	14
Cash and Cash Equivalents at End of Period	13	123
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	$ 112	$ 154

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Consolidated Statements of Changes in Equity (Unaudited) - 6 months ended Jun. 30, 2016 - 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, 2015	179,470,213	179,470,000				138,632,324	138,632,000
Beginning Balance at Dec. 31, 2015	$ 8,795	$ 4,123	$ 4,794	$ (145)	$ 23
Beginning Balance at Dec. 31, 2015	8,772					$ 5,673	$ 1,386	$ 2,700	$ 1,585	$ 2
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income (Loss)	385		399		(14)
Net Income (Loss)	399					262			262
Dividends declared on common stock	(400)		(400)			$ (210)			(210)
Repurchase of common stock, Shares		(394,000)
Repurchase of common stock	(33)	$ (33)
Benefit obligations, net of tax	2			2
Foreign currency translation	1			1
Stock-based compensation, net contributions from noncontrolling interests, and other, Shares		359,000
Stock-based compensation, net contributions from noncontrolling interests, and other	$ 49	$ 39	(2)		12
Ending Balance, shares at Jun. 30, 2016	179,435,004	179,435,000				138,632,324	138,632,000
Ending Balance at Jun. 30, 2016	$ 8,799	$ 4,129	$ 4,791	$ (142)	$ 21
Ending Balance at Jun. 30, 2016	$ 8,778					$ 5,725	$ 1,386	$ 2,700	$ 1,637	$ 2

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Organization and Basis of Presentation

6 Months Ended

Jun. 30, 2016

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 1.2 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 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 2015 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, 2016.

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. Such revisions include amounts reclassified to separate Operating Revenues and Fuel, purchased power, and gas between Utility operations and Non-utility operations and from Operations and maintenance to Fuel, purchased power, and gas — non-utility related to the Power and Industrial Projects segment. The reclassifications did not affect DTE Energy's Net Income for the prior periods, as such, they are not deemed material to the previously issued Consolidated Financial Statements. For reclassifications of debt issuance costs arising from ASU 2015-03, see Note 3 to the Consolidated Financial Statements, "New Accounting Pronouncements."

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 has variable interests in VIEs through certain of its long-term purchase and sale contracts. DTE Electric has variable interests in VIEs through certain of its long-term purchase contracts. As of June 30, 2016, the carrying amount of assets and liabilities in DTE Energy's Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase and sale contracts are predominantly related to working capital accounts and generally represent the amounts owed by or to DTE Energy for the deliveries associated with the current billing cycle under the contracts. As of June 30, 2016, 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 June 30, 2016 and December 31, 2015. 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.

	June 30, 2016		December 31, 2015
	(In millions)
ASSETS
Cash and cash equivalents	$	11	$	14
Restricted cash	6		8
Accounts receivable	29		18
Inventories	101		82
Property, plant, and equipment, net	59		66
Other current and long-term assets	2		4
	$	208	$	192
LIABILITIES
Accounts payable and accrued current liabilities	$	21	$	13
Current portion long-term debt, including capital leases	6		8
Mortgage bonds, notes, and other	7		10
Other current and long-term liabilities	6		6
	$	40	$	37

Amounts for DTE Energy's non-consolidated VIEs as of June 30, 2016 and December 31, 2015 are as follows:

	June 30, 2016		December 31, 2015
	(In millions)
Investment in equity method investees	$	195	$	136
Notes receivable	$	15	$	15
Future funding commitments	$	8	$	—

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Significant Accounting Policies

6 Months Ended

Jun. 30, 2016

Accounting Policies [Abstract]

Significant Accounting Policies

SIGNIFICANT ACCOUNTING POLICIES

Other Income

Other income for the Registrants is recognized for non-operating income such as equity earnings, allowance for equity funds used during construction, and contract services. DTE Energy's Power and Industrial Projects segment also recognizes Other income in connection with the sale of membership interests in reduced emissions fuel facilities to investors. In exchange for the cash received, the investors will receive a portion of the economic attributes of the facilities, including income tax attributes. The transactions are not treated as a sale of membership interests for financial reporting purposes. Other income is considered earned when refined coal is produced and tax credits are generated. Power and Industrial Projects recognized approximately $20 million of Other income for the three months ended June 30, 2016 and 2015, respectively, and approximately $39 million of Other income for the six months ended June 30, 2016 and 2015, respectively.

Changes in Accumulated Other Comprehensive Income (Loss)

For the three and six months endedJune 30, 2016 and 2015, 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 June 30,				Six Months Ended June 30,				June 30,
	2016		2015		2016		2015		2016
									(In millions)
DTE Energy	26	%	20	%	26	%	28	%	$	3
DTE Electric	36	%	35	%	36	%	35	%	$	4

The 6%increase in DTE Energy's effective tax rate for the three months ended June 30, 2016 is primarily due to higher production tax credits in the second quarter of 2015.

DTE Energy had $2 million of unrecognized tax benefits that, if recognized, would favorably impact its effective tax rate. DTE Electric had $3 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 $8 million and $6 million at June 30, 2016 and December 31, 2015, respectively.

Unrecognized Compensation Costs

As of June 30, 2016, DTE Energy had $77 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 1.56 years.

Allocated Stock-Based Compensation

DTE Electric received an allocation of costs from DTE Energy associated with stock-based compensation of $9 million and $8 million for the three months ended June 30, 2016 and 2015, respectively while such allocation was $19 million and $12 million for the six months ended June 30, 2016 and 2015, respectively.

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New Accounting Pronouncements

6 Months Ended

Jun. 30, 2016

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New Accounting Pronouncements

NEW ACCOUNTING PRONOUNCEMENTS

Recently Adopted Pronouncements

In February 2015, the FASB issued ASU No. 2015-02, Amendments to the Consolidation Analysis, which changes the analysis that a reporting entity must perform to determine whether it should consolidate certain types of legal entities. The ASU affects (1) limited partnerships and similar legal entities, (2) evaluating fees paid to a decision maker or a service provider as a variable interest, (3) the effect of fee arrangements on the primary beneficiary determination, (4) the effect of related parties on the primary beneficiary determination, and (5) certain investment funds. It is effective for the Registrants for the first interim period within annual reporting periods beginning after December 15, 2015. The Registrants adopted this ASU at January 1, 2016. The implementation of this guidance is reflected in Note 1 of the Consolidated Financial Statements, "Organization and Basis of Presentation." Certain entities are now deemed to be VIEs and are included in DTE Energy's non-consolidated VIE table. This implementation did not have a significant impact on the Registrants' Consolidated Financial Statements.

In April 2015, the FASB issued ASU No. 2015-03, Simplifying the Presentation of Debt Issuance Costs. This ASU requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. This ASU is effective for reporting periods beginning after December 15, 2015, and interim periods therein. It is to be applied retrospectively. The Registrants adopted this ASU at January 1, 2016. The effect of the adoption decreased assets and liabilities on DTE Energy’s and DTE Electric’s Consolidated Statements of Financial Position by $75 million and $36 million, respectively, at December 31, 2015.

In May 2015, the FASB issued ASU 2015-07, Fair Value Measurement (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent). This guidance removes the requirement to categorize within the fair value hierarchy all investments for which fair value is measured using the net asset value per share (or its equivalent) practical expedient. The guidance applies to investments for which there is not a readily determinable fair value (market quote) or the investment is in a mutual fund without a publicly available net asset value. It is effective for the Registrants for the first interim period within annual reporting periods beginning after December 15, 2015. It is to be applied retrospectively. The Registrants adopted this ASU at January 1, 2016. The implementation of this guidance is reflected in Note 6 of the Consolidated Financial Statements, "Fair Value." This implementation 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 are currently assessing the impact of the ASU, as amended on their Consolidated Financial Statements.

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 to be applied prospectively and early adoption is permitted. The ASU will not have a significant impact on the Registrants' Consolidated Financial Statements.

In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments — Overall: Recognition and Measurement of Financial Assets and Financial Liabilities. The new guidance is intended to improve the recognition and measurement of financial instruments. The ASU primarily impacts accounting for equity investments in unconsolidated entities (other than those accounted for using the equity method of accounting) and financial liabilities under the fair value option. Under the new guidance, equity investments will generally be measured at fair value, with subsequent changes in fair value recognized in net income. The ASU is effective for fiscal years and interim periods within those years beginning after December 15, 2017. Upon adoption, entities will be required to make a cumulative-effect adjustment to the Statements of Financial Position as of the beginning of the first reporting period in which the guidance is effective. Changes to the accounting for equity securities without a readily determinable fair value will be applied prospectively. The ASU will not have a significant impact on the Registrants' 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 are currently assessing the impact of this ASU on their Consolidated Financial Statements.

In March 2016, the FASB issued ASU No. 2016-09, Compensation— Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting. The ASU simplifies several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the Statements of Cash Flows. Under the new standard, income tax benefits and deficiencies are to be recognized in the income statement and the tax effects of exercised or vested awards should be treated as discrete items in the reporting period in which they occur. This provision is to be applied prospectively. Excess tax benefits should be recognized regardless of whether the benefit reduces taxes payable in the current period, along with any valuation allowance, on a modified retrospective basis as a cumulative-effect adjustment to the retained earnings as of the date of adoption. Excess tax benefits should be classified along with other income tax cash flows as an operating activity. This provision can be applied prospectively or retrospectively for all periods presented. The standard is effective for public entities for annual reporting periods beginning after December 15, 2016, and interim periods therein. Early adoption is permitted. The ASU will not have a significant impact on DTE Energy's 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.

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Regulatory Matters

6 Months Ended

Jun. 30, 2016

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. 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 10.3% to 10.5% on a capital structure of 50% equity and 50% debt. On July 1, 2016, DTE Electric filed an application with the MPSC for a $245 million self-implemented base rate increase effective August 1, 2016. A final MPSC order in this case is expected by February 2017.

2015 DTE Gas Rate Case Filing

DTE Gas filed a rate case with the MPSC on December 18, 2015 requesting an increase in base rates of $183 million, inclusive of $41 million of existing IRM surcharges which are expected to be converted into base rates, based on a projected twelve-month period ending October 31, 2017. The requested increase in base rates is due primarily to an increase in net plant, inclusive of IRM capital investments being recovered through approved IRM surcharge filings. 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 10.5% to 10.75% on a capital structure of 52% equity and 48% debt. Concurrent with the MPSC order in this rate case, the existing IRM surcharge being billed will be terminated. However, DTE Gas requested to implement a new IRM surcharge of approximately $9 million to become effective in January 2017. On May 11, 2016, DTE Gas filed an application with the MPSC for a $103 million self-implemented base rate increase effective November 1, 2016. A final MPSC order in this case is expected by December 2016.

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Earnings Per Share

6 Months Ended

Jun. 30, 2016

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. 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 for the three and six months endedJune 30:

	Three Months Ended June 30,					Six Months Ended June 30,
	2016		2015			2016		2015
	(In millions, except per share amounts)
Basic Earnings per Share
Net Income Attributable to DTE Energy Company	$	152	$	109		$	399	$	382
Average number of common shares outstanding	179		179			179		179
Dividends declared — common shares	$	131	$	124		$	261	$	247
Dividends declared — net restricted shares	—		—			1		1
Total distributed earnings	$	131	$	124		$	262	$	248
Net Income less distributed earnings	$	21	$	(15	)	$	137	$	134
Distributed (dividends per common share)	$	0.73	$	0.69		$	1.46	$	1.38
Undistributed	0.11		(0.08		)	0.76		0.75
Total Basic Earnings per Common Share	$	0.84	$	0.61		$	2.22	$	2.13
Diluted Earnings per Share
Net Income Attributable to DTE Energy Company	$	152	$	109		$	399	$	382
Average number of common shares outstanding	179		179			179		179
Average incremental shares from assumed exercise of options	1		—			1		—
Common shares for dilutive calculation	180		179			180		179
Dividends declared — common shares	$	131	$	124		$	261	$	247
Dividends declared — net restricted shares	—		—			1		1
Total distributed earnings	$	131	$	124		$	262	$	248
Net Income less distributed earnings	$	21	$	(15	)	$	137	$	134
Distributed (dividends per common share)	$	0.73	$	0.69		$	1.46	$	1.38
Undistributed	0.11		(0.08		)	0.76		0.75
Total Diluted Earnings per Common Share	$	0.84	$	0.61		$	2.22	$	2.13

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Fair Value

6 Months Ended

Jun. 30, 2016

Fair Value Disclosures [Abstract]

Fair Value

FAIR VALUE

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable inputs. The Registrants make certain assumptions they believe that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. Credit risk of the Registrants and their counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at June 30, 2016 and December 31, 2015. 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 as of June 30, 2016 and December 31, 2015:

	June 30, 2016																	December 31, 2015
	Level 1			Level 2			Level 3			Other (a)		Netting (b)			Net Balance			Level 1			Level 2			Level 3			Other (a)		Netting (b)			Net Balance
	(In millions)
Assets:
Cash equivalents (c)	$	6		$	3		$	—		$	—	$	—		$	9		$	13		$	3		$	—		$	—	$	—		$	16
Nuclear decommissioning trusts	853			422			—			—		—			1,275			759			473			—			4		—			1,236
Other investments (d)	159			—			—			—		—			159			149			—			—			—		—			149
Derivative assets:
Commodity Contracts:
Natural Gas	171			65			62			—		(248		)	50			193			91			103			—		(285		)	102
Electricity	—			196			43			—		(207		)	32			—			239			68			—		(232		)	75
Other	1			2			4			—		(2		)	5			2			—			3			—		(2		)	3
Foreign currency exchange contracts	—			6			—			—		(5		)	1			—			12			—			—		(9		)	3
Total derivative assets	172			269			109			—		(462		)	88			195			342			174			—		(528		)	183
Total	$	1,190		$	694		$	109		$	—	$	(462	)	$	1,531		$	1,116		$	818		$	174		$	4	$	(528	)	$	1,584
Liabilities:
Derivative liabilities:
Commodity Contracts:
Natural Gas	$	(193	)	$	(58	)	$	(124	)	$	—	$	263		$	(112	)	$	(218	)	$	(57	)	$	(108	)	$	—	$	294		$	(89	)
Electricity	—			(191		)	(49		)	—		212			(28		)	—			(243		)	(62		)	—		253			(52		)
Other	(3		)	(3		)	(5		)	—		10			(1		)	(2		)	—			(8		)	—		8			(2		)
Foreign currency exchange contracts	—			(3		)	—			—		3			—			—			(7		)	—			—		7			—
Total derivative liabilities	(196		)	(255		)	(178		)	—		488			(141		)	(220		)	(307		)	(178		)	—		562			(143		)
Total	$	(196	)	$	(255	)	$	(178	)	$	—	$	488		$	(141	)	$	(220	)	$	(307	)	$	(178	)	$	—	$	562		$	(143	)
Net Assets (Liabilities) at the end of the period	$	994		$	439		$	(69	)	$	—	$	26		$	1,390		$	896		$	511		$	(4	)	$	4	$	34		$	1,441
Assets:
Current	$	151		$	220		$	67		$	—	$	(376	)	$	62		$	174		$	284		$	128		$	—	$	(441	)	$	145
Noncurrent	1,039			474			42			—		(86		)	1,469			942			534			46			4		(87		)	1,439
Total Assets	$	1,190		$	694		$	109		$	—	$	(462	)	$	1,531		$	1,116		$	818		$	174		$	4	$	(528	)	$	1,584
Liabilities:
Current	$	(166	)	$	(204	)	$	(72	)	$	—	$	395		$	(47	)	$	(174	)	$	(260	)	$	(87	)	$	—	$	464		$	(57	)
Noncurrent	(30		)	(51		)	(106		)	—		93			(94		)	(46		)	(47		)	(91		)	—		98			(86		)
Total Liabilities	$	(196	)	$	(255	)	$	(178	)	$	—	$	488		$	(141	)	$	(220	)	$	(307	)	$	(178	)	$	—	$	562		$	(143	)
Net Assets (Liabilities) at the end of the period	$	994		$	439		$	(69	)	$	—	$	26		$	1,390		$	896		$	511		$	(4	)	$	4	$	34		$	1,441

_______________________________________

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

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

(c) At June 30, 2016, available-for-sale securities of $9 million included $6 million and $3 million of cash equivalents included in Restricted cash and Other investments on DTE Energy's Consolidated Statements of Financial Position, respectively. At December 31, 2015, available-for-sale securities of $16 million, included $8 million and $8 million of cash equivalents included in Restricted cash and Other investments on DTE Energy's Consolidated Statements of Financial Position, respectively.

(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 June 30, 2016 and December 31, 2015:

	June 30, 2016										December 31, 2015
	Level 1		Level 2		Level 3		Other (a)		Net Balance		Level 1		Level 2		Level 3		Other (a)		Net Balance
	(In millions)
Assets:
Cash equivalents (b)	$	—	$	3	$	—	$	—	$	3	$	5	$	3	$	—	$	—	$	8
Nuclear decommissioning trusts	853		422		—		—		1,275		759		473		—		4		1,236
Other investments	8		—		—		—		8		8		—		—		—		8
Derivative assets — FTRs	—		—		4		—		4		—		—		3		—		3
Total	$	861	$	425	$	4	$	—	$	1,290	$	772	$	476	$	3	$	4	$	1,255
Assets:
Current	$	—	$	3	$	4	$	—	$	7	$	5	$	3	$	3	$	—	$	11
Noncurrent	861		422		—		—		1,283		767		473		—		4		1,244
Total Assets	$	861	$	425	$	4	$	—	$	1,290	$	772	$	476	$	3	$	4	$	1,255

_______________________________________

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

(b) At June 30, 2016, available-for-sale securities of $3 million consisted of cash equivalents included in Other investments on DTE Electric's Consolidated Statements of Financial Position. At December 31, 2015, available-for-sale securities of $8 million consisted of cash equivalents included in Other investments on DTE Electric's Consolidated Statements of Financial Position.

Cash Equivalents

Cash equivalents include investments with maturities of three months or less when purchased. The cash equivalents shown in the fair value table are comprised of short-term investments and money market funds.

Nuclear Decommissioning Trusts and Other Investments

The nuclear decommissioning trusts and other investments hold debt and equity securities directly and indirectly through 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. The commingled funds hold exchange-traded equity or debt securities (exchange and non-exchange traded) and are valued based on a calculated NAV as a practical expedient. 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 tables present the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for DTE Energy for the three and six months endedJune 30, 2016 and 2015:

	Three Months Ended June 30, 2016												Three Months Ended June 30, 2015
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of March 31	$	(34	)	$	(16	)	$	(7	)	$	(57	)	$	—		$	(7	)	$	(5	)	$	(12	)
Transfers into Level 3 from Level 2	—			—			—			—			—			—			—			—
Transfers from Level 3 into Level 2	—			—			—			—			—			—			—			—
Total gains (losses):
Included in earnings	(36		)	12			2			(22		)	(5		)	18			1			14
Recorded in Regulatory liabilities	—			—			6			6			—			—			13			13
Purchases, issuances, and settlements:
Purchases	—			1			—			1			—			1			—			1
Settlements	8			(3		)	(2		)	3			(3		)	(9		)	(8		)	(20		)
Net Assets (Liabilities) as of June 30	$	(62	)	$	(6	)	$	(1	)	$	(69	)	$	(8	)	$	3		$	1		$	(4	)
The amount of total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at June 30, 2016 and 2015 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	$	(41	)	$	(4	)	$	2		$	(43	)	$	(20	)	$	15		$	1		$	(4	)

	Six Months Ended June 30, 2016												Six Months Ended June 30, 2015
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of December 31	$	(5	)	$	6		$	(5	)	$	(4	)	$	30		$	(5	)	$	(1	)	$	24
Transfers into Level 3 from Level 2	—			—			—			—			—			—			—			—
Transfers from Level 3 into Level 2	(1		)	—			—			(1		)	—			—			—			—
Total gains (losses):
Included in earnings	(56		)	(46		)	1			(101		)	(35		)	24			(2		)	(13		)
Recorded in Regulatory liabilities	—			—			4			4			—			—			11			11
Purchases, issuances, and settlements:
Purchases	—			1			—			1			—			2			—			2
Settlements	—			33			(1		)	32			(3		)	(18		)	(7		)	(28		)
Net Assets (Liabilities) as of June 30	$	(62	)	$	(6	)	$	(1	)	$	(69	)	$	(8	)	$	3		$	1		$	(4	)
The amount of total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at June 30, 2016 and 2015 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	$	(113	)	$	(7	)	$	1		$	(119	)	$	(112	)	$	11		$	(1	)	$	(102	)

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 for the three and six months endedJune 30, 2016 and 2015:

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(In millions)
Net Assets as of beginning of period	$	1		$	1		$	3		$	3
Change in fair value recorded in Regulatory liabilities	6			13			4			11
Purchases, issuances, and settlements:
Settlements	(3		)	(9		)	(3		)	(9		)
Net Assets as of June 30	$	4		$	5		$	4		$	5
The amount of total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets held at June 30, 2016 and 2015 and reflected in DTE Electric's Consolidated Statements of Financial Position	$	4		$	5		$	4		$	5

Derivatives are transferred between levels primarily due to changes in the source data used to construct price curves as a result of changes in market liquidity. Transfers in and transfers out are reflected as if they had occurred at the beginning of the period.

There were no transfers between Levels 1 and 2 for the Registrants during the three and six months endedJune 30, 2016 and 2015, 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 as of June 30, 2016 and December 31, 2015:

	June 30, 2016
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range						Weighted Average
	(In millions)
Natural Gas	$	62	$	(124	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.36	) —	$	3.68	/MMBtu	$	(0.10	)/MMBtu
Electricity	$	43	$	(49	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(14	) —	$	13	/MWh	$	1	/MWh

	December 31, 2015
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range						Weighted Average
	(In millions)
Natural Gas	$	103	$	(108	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.50	) —	$	2.77	/MMBtu	$	(0.19	)/MMBtu
Electricity	$	68	$	(62	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(11	) —	$	14	/MWh	$	2	/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, 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.

The following table presents the carrying amount and fair value of financial instruments for DTE Energy as of June 30, 2016 and December 31, 2015:

	June 30, 2016								December 31, 2015
	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	$	32	$	—	$	—	$	32	$	32	$	—	$	—	$	32
Dividends payable	$	269	$	269	$	—	$	—	$	131	$	131	$	—	$	—
Short-term borrowings	$	175	$	—	$	175	$	—	$	499	$	—	$	499	$	—
Long-term debt, excluding capital leases	$	9,488	$	807	$	8,538	$	1,438	$	9,210	$	496	$	8,136	$	1,203

The following table presents the carrying amount and fair value of financial instruments for DTE Electric as of June 30, 2016 and December 31, 2015:

	June 30, 2016								December 31, 2015
	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	$	5	$	—	$	—	$	5
Notes receivable — affiliates	$	62	$	—	$	—	$	62	$	—	$	—	$	—	$	—
Short-term borrowings — affiliates	$	108	$	—	$	—	$	108	$	75	$	—	$	—	$	75
Short-term borrowings — other	$	—	$	—	$	—	$	—	$	272	$	—	$	272	$	—
Long-term debt, excluding capital leases	$	5,877	$	—	$	5,999	$	755	$	5,588	$	—	$	5,432	$	545

For further fair value information on financial and derivative instruments, see Note 7 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 ARO on DTE Electric's Consolidated Statements of Financial Position. Rates approved by the MPSC provide for the recovery of decommissioning costs of Fermi 2 and the disposal of low-level radioactive waste.

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

	June 30, 2016		December 31, 2015
	(In millions)
Fermi 2	$	1,247	$	1,211
Fermi 1	3		3
Low-level radioactive waste	25		22
Total	$	1,275	$	1,236

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

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(In millions)
Realized gains	$	37		$	13		$	46		$	22
Realized losses	$	(25	)	$	(5	)	$	(40	)	$	(12	)
Proceeds from sales of securities	$	481		$	194		$	741		$	440

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:

	June 30, 2016							December 31, 2015
	Fair Value		Unrealized Gains		Unrealized Losses			Fair Value		Unrealized Gains		Unrealized Losses
	(In millions)
Equity securities	$	831	$	180	$	(53	)	$	731	$	195	$	(68	)
Debt securities	438		29		(2		)	499		16		(4		)
Cash and cash equivalents	6		—		—			6		—		—
	$	1,275	$	209	$	(55	)	$	1,236	$	211	$	(72	)

The debt securities at June 30, 2016 and December 31, 2015 had an average maturity of approximately 7 and 6 years, respectively. 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 June 30, 2016 and December 31, 2015, 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 and six months endedJune 30, 2016 and 2015. Gains related to trading securities held at June 30, 2016 and June 30, 2015 were $10 million and $1 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

6 Months Ended

Jun. 30, 2016

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 2019. 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 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 June 30, 2016 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 as of June 30, 2016 and December 31, 2015 for DTE Energy:

	June 30, 2016					December 31, 2015
	Derivative Assets		Derivative Liabilities			Derivative Assets		Derivative Liabilities
	(In millions)
Derivatives not designated as hedging instruments:
Commodity Contracts:
Natural Gas	$	298	$	(375	)	$	387	$	(383	)
Electricity	239		(240		)	307		(305		)
Other	7		(11		)	5		(10		)
Foreign currency exchange contracts	6		(3		)	12		(7		)
Total derivatives not designated as hedging instruments:	$	550	$	(629	)	$	711	$	(705	)
Current	$	429	$	(442	)	$	570	$	(521	)
Noncurrent	121		(187		)	141		(184		)
Total derivatives	$	550	$	(629	)	$	711	$	(705	)

The following table presents the fair value of derivative instruments as of June 30, 2016 and December 31, 2015 for DTE Electric:

	June 30, 2016		December 31, 2015
	(In millions)
FTRs — Other current assets	$	4	$	3
Total derivatives not designated as hedging instrument	$	4	$	3

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

DTE Energy also provides and receives collateral in the form of letters of credit which can be offset against net Derivative assets and liabilities as well as Accounts receivable and payable. DTE Energy had issued letters of credit of approximately $5 million and $7 million outstanding at June 30, 2016 and December 31, 2015, respectively, which could be used to offset net Derivative liabilities. Letters of credit received from third parties which could be used to offset net Derivative assets were $1 million and $2 million at June 30, 2016 and December 31, 2015, 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 $40 million and $37 million as of June 30, 2016 and December 31, 2015, respectively. DTE Energy had $6 million of cash collateral related to unrealized positions to net against Derivative assets while Derivative liabilities are shown net of cash collateral of $32 million as of June 30, 2016. DTE Energy had $2 million of cash collateral related to unrealized positions to net against Derivative assets while Derivative liabilities are shown net of cash collateral of $36 million as of December 31, 2015. DTE Energy recorded cash collateral paid of $16 million and cash collateral received of $2 million not related to unrealized derivative positions as of June 30, 2016. DTE Energy recorded cash collateral paid of $6 million and cash collateral received of $3 million not related to unrealized derivative positions as of December 31, 2015. 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 at June 30, 2016 and December 31, 2015:

	June 30, 2016									December 31, 2015
	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	$	298		$	(248	)	$	50		$	387		$	(285	)	$	102
Electricity	239			(207		)	32			307			(232		)	75
Other	7			(2		)	5			5			(2		)	3
Foreign currency exchange contracts	6			(5		)	1			12			(9		)	3
Total derivative assets	$	550		$	(462	)	$	88		$	711		$	(528	)	$	183
Derivative liabilities:
Commodity Contracts:
Natural Gas	$	(375	)	$	263		$	(112	)	$	(383	)	$	294		$	(89	)
Electricity	(240		)	212			(28		)	(305		)	253			(52		)
Other	(11		)	10			(1		)	(10		)	8			(2		)
Foreign currency exchange contracts	(3		)	3			—			(7		)	7			—
Total derivative liabilities	$	(629	)	$	488		$	(141	)	$	(705	)	$	562		$	(143	)

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 at June 30, 2016 and December 31, 2015:

	June 30, 2016												December 31, 2015
	Derivative Assets						Derivative Liabilities						Derivative Assets						Derivative Liabilities
	Current			Noncurrent			Current			Noncurrent			Current			Noncurrent			Current			Noncurrent
	(In millions)
Total fair value of derivatives	$	429		$	121		$	(442	)	$	(187	)	$	570		$	141		$	(521	)	$	(184	)
Counterparty netting	(372		)	(84		)	372			84			(441		)	(85		)	441			85
Collateral adjustment	(4		)	(2		)	23			9			—			(2		)	23			13
Total derivatives as reported	$	53		$	35		$	(47	)	$	(94	)	$	129		$	54		$	(57	)	$	(86	)

The effect of derivatives not designated as hedging instruments on DTE Energy's Consolidated Statements of Operations for the three and six months endedJune 30, 2016 and 2015 for DTE Energy 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 June 30,						Gain (Loss) Recognized in Income on Derivatives for the Six Months Ended June 30,
		2016			2015			2016			2015
		(In millions)
Commodity Contracts:
Natural Gas	Operating Revenues — Non-utility operations	$	(30	)	$	(4	)	$	(86	)	$	(130	)
Natural Gas	Fuel, purchased power, and gas — non-utility	(9		)	12			32			33
Electricity	Operating Revenues — Non-utility operations	19			15			(5		)	46
Other	Operating Revenues — Non-utility operations	—			2			(2		)	—
Foreign currency exchange contracts	Operating Revenues — Non-utility operations	1			—			(4		)	1
Total		$	(19	)	$	25		$	(65	)	$	(50	)

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

The following represents the cumulative gross volume of DTE Energy's derivative contracts outstanding as of June 30, 2016:

Commodity	Number of Units
Natural Gas (MMBtu)	1,838,453,487
Electricity (MWh)	37,370,289
Oil (Gallons)	18,102,000
Foreign Currency Exchange (Canadian dollars)	80,449,368

Various subsidiaries of DTE Energy have entered into contracts which contain ratings triggers and are guaranteed by DTE Energy. These contracts contain provisions which allow the counterparties to require that DTE Energy post cash or letters of credit as collateral in the event that DTE Energy’s credit rating is downgraded below investment grade. Certain of these provisions (known as “hard triggers”) state specific circumstances under which DTE Energy can be required to post collateral upon the occurrence of a credit downgrade, while other provisions (known as “soft triggers”) are not as specific. For contracts with soft triggers, it is difficult to estimate the amount of collateral which may be requested by counterparties and/or which DTE Energy may ultimately be required to post. The amount of such collateral which could be requested fluctuates based on commodity prices (primarily natural gas, power, and coal) and the provisions and maturities of the underlying transactions. As of June 30, 2016, 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 $322 million.

As of June 30, 2016, DTE Energy had approximately $482 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 $425 million. The net remaining amount of approximately $57 million is derived from the $322 million noted above.

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Long-Term Debt

6 Months Ended

Jun. 30, 2016

Long-term Debt, Unclassified [Abstract]

Long-term Debt

LONG-TERM DEBT

Debt Issuances

In 2016, the following debt was issued:

Company	Month	Type	Interest Rate	Maturity	Amount
					(In millions)
DTE Electric	May	Mortgage Bonds	3.70%	2046	$	300
DTE Energy	May	Junior Subordinated Debentures	5.375%	2076	300
					$	600

Debt Redemptions

In 2016, the following debt was redeemed:

Company	Month	Type	Interest Rate	Maturity	Amount
					(In millions)
DTE Electric	March	Mortgage Bonds	7.904%	2016	$	10
DTE Energy	June	Senior Notes	6.35%	2016	300
DTE Energy	Various	Other Long-Term Debt	Various	2016	3
					$	313

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Short-Term Credit Arrangements and Borrowings

6 Months Ended

Jun. 30, 2016

Short-term Debt [Abstract]

Short-Term Credit Arrangements and Borrowings

SHORT-TERM CREDIT ARRANGEMENTS AND BORROWINGS

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

The agreements require DTE Energy, DTE Electric, and DTE Gas to maintain a total funded debt to capitalization ratio of no more than 0.65 to 1. In the agreements, “total funded debt” means all indebtedness of each respective company and their consolidated subsidiaries, including capital lease obligations, hedge agreements, and guarantees of third parties’ debt, but excluding contingent obligations, nonrecourse and junior subordinated debt, and certain equity-linked securities and, except for calculations at the end of the second quarter, certain DTE Gas short-term debt. “Capitalization” means the sum of (a) total funded debt plus (b) “consolidated net worth,” which is equal to consolidated total equity of each respective company and their consolidated subsidiaries (excluding pension effects under certain FASB statements), as determined in accordance with accounting principles generally accepted in the United States of America. At June 30, 2016, the total funded debt to total capitalization ratios for DTE Energy, DTE Electric, and DTE Gas were 0.50 to 1, 0.51 to 1, and 0.44 to 1, respectively, and were in compliance with this financial covenant.

The availability under the facilities in place at June 30, 2016 is shown in the following table:

	DTE Energy		DTE Electric		DTE Gas		Total
	(In millions)
Unsecured letter of credit facility, expiring in February 2017	$	100	$	—	$	—	$	100
Unsecured letter of credit facility, expiring in September 2017	70		—		—		70
Unsecured revolving credit facility, expiring April 2021	1,200		400		300		1,900
	1,370		400		300		2,070
Amounts outstanding at June 30, 2016
Commercial paper issuances	175		—		—		175
Letters of credit	139		—		—		139
	314		—		—		314
Net availability at June 30, 2016	$	1,056	$	400	$	300	$	1,756

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 June 30, 2016, 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 $63 million and $103 million at June 30, 2016 and December 31, 2015, respectively, and was fully offset by the posted collateral.

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Commitments and Contingencies

6 Months Ended

Jun. 30, 2016

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 sulfur dioxide and nitrogen oxides. The EPA and the State of Michigan have 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 nitrogen oxide, sulfur dioxide, mercury and other emissions. Additional rulemakings are expected over the next few years which could require additional controls for sulfur dioxide, nitrogen oxides, and hazardous air pollutants.

The Mercury and Air Toxics Standards (MATS) rule, formerly known as the Electric Generating Unit Maximum Achievable Control Technology (EGU MACT) Rule was finalized in December 2011. The MATS rule required reductions of mercury and other hazardous air pollutants beginning in April 2015. DTE Electric requested and was granted compliance date extensions for all relevant units to April 2016. In November 2014, the U.S. Supreme Court agreed to review a challenge to the MATS rule based on a narrowly focused question of how the EPA considered costs in regulating air pollutants emitted by electric utilities. In June 2015, the U.S. Supreme Court reversed the decision of the Court of Appeals for the D.C. District and remanded the MATS rule to the Court of Appeals for further consideration based on their decision that the EPA must consider costs prior to deciding to regulate under the provisions of the Clean Air Act. Subsequently, in December 2015, the Court of Appeals ordered a remand of the MATS rule back to the EPA without staying the rule. A petition to the U.S. Supreme Court for review of the D.C. Circuit’s remand of the rule was denied in April 2016, leaving the MATS rule in place. DTE Electric is currently operating in compliance with the rule at all regulated units. Although various issues surrounding the MATS rule remain subject to litigation in the D.C. Circuit, at this time DTE Electric does not expect future decisions to have a material effect on its compliance program.

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 are 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.

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 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 is implementing 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 electric generating units (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. 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.

To comply with air pollution requirements, DTE Electric spent approximately $2.3 billion through 2015. DTE Electric estimates making capital expenditures of approximately $45 million in 2016.

Coal Combustion Residuals and Effluent Limitations Guidelines — A final EPA rule for the disposal of coal combustion residuals, commonly known as coal ash, became effective in October 2015. 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. 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 effluent limitations guidelines 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. No new permits have been issued, consequently no compliance timelines have been established. Certain effluent limitations guidelines requirements will be required to be performed in conjunction with the coal combustion residuals requirements. Costs associated with the building of new facilities over the next seven years to comply with coal combustion residuals requirements and effluent limitations guidelines are estimated to be approximately $280 million.

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 five of the MGP sites is complete and the sites are closed. DTE Gas has also completed partial closure of three additional sites. Cleanup activities associated with the remaining sites will continue over the next several years. The MPSC has established a cost deferral and rate recovery mechanism for investigation and remediation costs incurred at former MGP sites. In addition to the MGP sites, DTE Gas is also in the process of cleaning up other contaminated sites, including gate stations, gas pipeline releases, and underground storage tank locations. As of June 30, 2016 and December 31, 2015, DTE Gas had $38 million and $22 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.

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 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.

In January 2016, the Yolo Solano County Health Department in California with the District Attorney issued subpoenas to investigate 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 power generation facility. We are currently working with the County Health Department and District Attorney's office to sample the beneficially reused ash and appropriately manage it according to the results. Additional reviews are being conducted to verify if biomass ash sent to landfills was properly characterized and managed. The Woodland Companies are currently negotiating a settlement with the District Attorney. As of June 30, 2016, DTE Energy had $3 million accrued for this matter. Changes in estimated remediation and settlement costs, if any, that occur upon completion of the investigation are not expected to have a material impact on DTE Energy’s Consolidated Financial Statements.

Riverview Energy Systems, LLC, a 50% owned landfill gas recovery facility, received a NOV in May 2015 due to stack test and landfill gas sample results exceeding permitting levels for sulfur.  A permit application to correct issues has been submitted, and a consent order was negotiated with the MDEQ. The consent order requires Riverview Energy Systems to pay $375,000 and install a sulfur control system.

The Shenango coke battery received two NOVs from the Pennsylvania Department of Environmental Protection (PADEP) in 2010 alleging violations of the permit for the Pennsylvania coke battery facility in connection with coal pile storm water runoff. DTE Energy settled the alleged violations by implementing best management practices to address the issues and repair/upgrade its wastewater treatment plant. DTE Energy received a construction permit to upgrade its existing waste water treatment system. Due to the December 2015 decision to close the Shenango coke battery in January 2016, DTE Energy will not proceed with the upgrade to its wastewater treatment system.

The decision to close the Shenango facility has prompted the PADEP, the EPA, and the Allegheny County, PA Health Department to submit demand letters under the 2012 consent decree for stipulated penalties related to water and air matters since 2012. The stipulated penalties totaling $534,000 have been accrued of which $190,000 remained unpaid as of June 30, 2016. DTE Energy is currently working with the respective regulatory agencies to settle all matters.

Nuclear Operations

Nuclear Fuel Disposal Costs

DTE Electric currently employs a spent nuclear fuel storage strategy utilizing a fuel pool and a newly completed dry cask storage facility. The dry cask storage facility is expected to provide sufficient spent fuel storage capability for the life of the plant as defined by the original operating license.

The federal government continues to maintain its legal obligation to accept spent nuclear fuel from Fermi 2 for permanent storage. Issues relating to long-term waste disposal policy and to the disposition of funds contributed by DTE Electric ratepayers to the federal waste fund await future governmental action.

Synthetic Fuel Guarantees

DTE Energy discontinued the operations of its synthetic fuel production facilities throughout the United States as of December 31, 2007. DTE Energy provided certain guarantees and indemnities in conjunction with the sales of interests in its synfuel facilities. The guarantees cover potential commercial, environmental, oil price, and tax-related obligations that will survive until 90 days after expiration of all applicable statutes of limitations. DTE Energy estimates that its maximum potential liability under these guarantees at June 30, 2016 is approximately $850 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 June 30, 2016 is approximately $323 million. Payment under these guarantees is 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 June 30, 2016. 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 June 30, 2016, DTE Energy had approximately $54 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.

Bankruptcies

Certain of the Registrants' customers and suppliers have filed for bankruptcy protection under the U.S. Bankruptcy Code. The Registrants regularly review contingent matters relating to these customers and suppliers and their purchase and sale 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.

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 4 and 7 to the Consolidated Financial Statements, "Regulatory Matters" and "Financial and Other Derivative Instruments," respectively.

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Retirement Benefits and Trusteed Assets

6 Months Ended

Jun. 30, 2016

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
	2016			2015			2016			2015
Three Months Ended June 30,	(In millions)
Service cost	$	23		$	24		$	7		$	8
Interest cost	55			53			20			21
Expected return on plan assets	(78		)	(74		)	(32		)	(32		)
Amortization of:
Net actuarial loss	41			52			8			11
Prior service credit	—			—			(29		)	(32		)
Net periodic benefit cost (credit)	$	41		$	55		$	(26	)	$	(24	)

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
Six Months Ended June 30,	(In millions)
Service cost	$	46		$	49		$	13		$	17
Interest cost	109			106			40			41
Expected return on plan assets	(155		)	(148		)	(64		)	(65		)
Amortization of:
Net actuarial loss	81			103			16			22
Prior service credit	—			—			(59		)	(63		)
Net periodic benefit cost (credit)	$	81		$	110		$	(54	)	$	(48	)

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
	2016			2015			2016			2015
Three Months Ended June 30,	(In millions)
Service cost	$	17		$	18		$	5		$	6
Interest cost	42			41			16			15
Expected return on plan assets	(55		)	(52		)	(22		)	(22		)
Amortization of:
Net actuarial loss	28			36			5			8
Prior service cost (credit)	1			1			(22		)	(23		)
Net periodic benefit cost (credit)	$	33		$	44		$	(18	)	$	(16	)

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
Six Months Ended June 30,	(In millions)
Service cost	$	35		$	38		$	10		$	13
Interest cost	83			81			31			31
Expected return on plan assets	(110		)	(105		)	(45		)	(45		)
Amortization of:
Net actuarial loss	57			74			11			16
Prior service cost (credit)	1			1			(44		)	(47		)
Net periodic benefit cost (credit)	$	66		$	89		$	(37	)	$	(32	)

Pension and Other Postretirement Contributions

At the discretion of management, DTE Energy may make contributions up to $175 million, including contributions from DTE Electric of $145 million, to its pension plans in 2016.

At the discretion of management, DTE Energy may make contributions up to $20 million, through contributions from DTE Gas, to its other postretirement benefit plans in 2016.

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Segment and Related Information

6 Months Ended

Jun. 30, 2016

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 1.2 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, and holds certain non-utility debt and energy-related investments.

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

Inter-segment billing for goods and services exchanged between segments is based upon tariffed or market-based prices of the provider and primarily consists of the sale of reduced emissions fuel, power sales, and natural gas sales in the following segments:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(In millions)
Inter-segment Revenues
Electric	$	8	$	9	$	17	$	18
Gas	3		—		3		1
Gas Storage and Pipelines	3		5		5		6
Power and Industrial Projects	150		215		298		395
Energy Trading	8		7		18		16
Corporate and Other	2		—		2		1
	$	174	$	236	$	343	$	437

Financial data of the DTE Energy business segments follows:

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(In millions)
Operating Revenues — Utility operations
Electric	$	1,215		$	1,148		$	2,368		$	2,351
Gas	231			218			751			865
Operating Revenues — Non-utility operations
Gas Storage and Pipelines	69			57			136			114
Power and Industrial Projects	444			556			890			1,123
Energy Trading	476			524			1,025			1,235
Corporate and Other	1			1			1			1
Reconciliation and Eliminations	(174		)	(236		)	(343		)	(437		)
Total	$	2,262		$	2,268		$	4,828		$	5,252

Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	135		$	99		$	262		$	235
Gas	13			(7		)	100			104
Gas Storage and Pipelines	35			25			65			52
Power and Industrial Projects	15			8			32			41
Energy Trading	(23		)	(3		)	(30		)	(12		)
Corporate and Other	(23		)	(13		)	(30		)	(38		)
Net Income Attributable to DTE Energy Company	$	152		$	109		$	399		$	382

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Significant Accounting Policies (Policies)

6 Months Ended

Jun. 30, 2016

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 2015 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, 2016.

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. Such revisions include amounts reclassified to separate Operating Revenues and Fuel, purchased power, and gas between Utility operations and Non-utility operations and from Operations and maintenance to Fuel, purchased power, and gas — non-utility related to the Power and Industrial Projects segment. The reclassifications did not affect DTE Energy's Net Income for the prior periods, as such, they are not deemed material to the previously issued Consolidated Financial Statements.

Reclassification

Certain prior year balances for the Registrants were reclassified to match the current year's Consolidated Financial Statements presentation. Such revisions include amounts reclassified to separate Operating Revenues and Fuel, purchased power, and gas between Utility operations and Non-utility operations and from Operations and maintenance to Fuel, purchased power, and gas — non-utility related to the Power and Industrial Projects segment. The reclassifications did not affect DTE Energy's Net Income for the prior periods, as such, they are not deemed material to the previously issued Consolidated Financial Statements.

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 has variable interests in VIEs through certain of its long-term purchase and sale contracts. DTE Electric has variable interests in VIEs through certain of its long-term purchase contracts. As of June 30, 2016, the carrying amount of assets and liabilities in DTE Energy's Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase and sale contracts are predominantly related to working capital accounts and generally represent the amounts owed by or to DTE Energy for the deliveries associated with the current billing cycle under the contracts. As of June 30, 2016, 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.

Other Income

Other Income

Other income for the Registrants is recognized for non-operating income such as equity earnings, allowance for equity funds used during construction, and contract services. DTE Energy's Power and Industrial Projects segment also recognizes Other income in connection with the sale of membership interests in reduced emissions fuel facilities to investors. In exchange for the cash received, the investors will receive a portion of the economic attributes of the facilities, including income tax attributes. The transactions are not treated as a sale of membership interests for financial reporting purposes. Other income is considered earned when refined coal is produced and tax credits are generated.

Changes in Accumulated Other Comprehensive Income (Loss)

Changes in Accumulated Other Comprehensive Income (Loss)

For the three and six months endedJune 30, 2016 and 2015, 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 February 2015, the FASB issued ASU No. 2015-02, Amendments to the Consolidation Analysis, which changes the analysis that a reporting entity must perform to determine whether it should consolidate certain types of legal entities. The ASU affects (1) limited partnerships and similar legal entities, (2) evaluating fees paid to a decision maker or a service provider as a variable interest, (3) the effect of fee arrangements on the primary beneficiary determination, (4) the effect of related parties on the primary beneficiary determination, and (5) certain investment funds. It is effective for the Registrants for the first interim period within annual reporting periods beginning after December 15, 2015. The Registrants adopted this ASU at January 1, 2016. The implementation of this guidance is reflected in Note 1 of the Consolidated Financial Statements, "Organization and Basis of Presentation." Certain entities are now deemed to be VIEs and are included in DTE Energy's non-consolidated VIE table. This implementation did not have a significant impact on the Registrants' Consolidated Financial Statements.

In April 2015, the FASB issued ASU No. 2015-03, Simplifying the Presentation of Debt Issuance Costs. This ASU requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. This ASU is effective for reporting periods beginning after December 15, 2015, and interim periods therein. It is to be applied retrospectively. The Registrants adopted this ASU at January 1, 2016. The effect of the adoption decreased assets and liabilities on DTE Energy’s and DTE Electric’s Consolidated Statements of Financial Position by $75 million and $36 million, respectively, at December 31, 2015.

In May 2015, the FASB issued ASU 2015-07, Fair Value Measurement (Topic 820): Disclosures for Investments in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent). This guidance removes the requirement to categorize within the fair value hierarchy all investments for which fair value is measured using the net asset value per share (or its equivalent) practical expedient. The guidance applies to investments for which there is not a readily determinable fair value (market quote) or the investment is in a mutual fund without a publicly available net asset value. It is effective for the Registrants for the first interim period within annual reporting periods beginning after December 15, 2015. It is to be applied retrospectively. The Registrants adopted this ASU at January 1, 2016. The implementation of this guidance is reflected in Note 6 of the Consolidated Financial Statements, "Fair Value." This implementation 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 are currently assessing the impact of the ASU, as amended on their Consolidated Financial Statements.

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 to be applied prospectively and early adoption is permitted. The ASU will not have a significant impact on the Registrants' Consolidated Financial Statements.

In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments — Overall: Recognition and Measurement of Financial Assets and Financial Liabilities. The new guidance is intended to improve the recognition and measurement of financial instruments. The ASU primarily impacts accounting for equity investments in unconsolidated entities (other than those accounted for using the equity method of accounting) and financial liabilities under the fair value option. Under the new guidance, equity investments will generally be measured at fair value, with subsequent changes in fair value recognized in net income. The ASU is effective for fiscal years and interim periods within those years beginning after December 15, 2017. Upon adoption, entities will be required to make a cumulative-effect adjustment to the Statements of Financial Position as of the beginning of the first reporting period in which the guidance is effective. Changes to the accounting for equity securities without a readily determinable fair value will be applied prospectively. The ASU will not have a significant impact on the Registrants' 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 are currently assessing the impact of this ASU on their Consolidated Financial Statements.

In March 2016, the FASB issued ASU No. 2016-09, Compensation— Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting. The ASU simplifies several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the Statements of Cash Flows. Under the new standard, income tax benefits and deficiencies are to be recognized in the income statement and the tax effects of exercised or vested awards should be treated as discrete items in the reporting period in which they occur. This provision is to be applied prospectively. Excess tax benefits should be recognized regardless of whether the benefit reduces taxes payable in the current period, along with any valuation allowance, on a modified retrospective basis as a cumulative-effect adjustment to the retained earnings as of the date of adoption. Excess tax benefits should be classified along with other income tax cash flows as an operating activity. This provision can be applied prospectively or retrospectively for all periods presented. The standard is effective for public entities for annual reporting periods beginning after December 15, 2016, and interim periods therein. Early adoption is permitted. The ASU will not have a significant impact on DTE Energy's 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.

Fair Value Measurement

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable inputs. The Registrants make certain assumptions they believe that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. Credit risk of the Registrants and their counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at June 30, 2016 and December 31, 2015. The Registrants believe they use valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.

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

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

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

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

Nuclear Decommissioning Trusts and Other Investments

Nuclear Decommissioning Trusts and Other Investments

The nuclear decommissioning trusts and other investments hold debt and equity securities directly and indirectly through 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. The commingled funds hold exchange-traded equity or debt securities (exchange and non-exchange traded) and are valued based on a calculated NAV as a practical expedient. 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.

Derivatives, Reporting of Derivative Activity

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

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, 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.

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 2019. 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 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 June 30, 2016 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 $5 million and $7 million outstanding at June 30, 2016 and December 31, 2015, respectively, which could be used to offset net Derivative liabilities. Letters of credit received from third parties which could be used to offset net Derivative assets were $1 million and $2 million at June 30, 2016 and December 31, 2015, 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)

6 Months Ended

Jun. 30, 2016

Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]

Schedule of Variable Interest Entities

The following table summarizes the major Consolidated Statements of Financial Position items for consolidated VIEs as of June 30, 2016 and December 31, 2015. 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.

	June 30, 2016		December 31, 2015
	(In millions)
ASSETS
Cash and cash equivalents	$	11	$	14
Restricted cash	6		8
Accounts receivable	29		18
Inventories	101		82
Property, plant, and equipment, net	59		66
Other current and long-term assets	2		4
	$	208	$	192
LIABILITIES
Accounts payable and accrued current liabilities	$	21	$	13
Current portion long-term debt, including capital leases	6		8
Mortgage bonds, notes, and other	7		10
Other current and long-term liabilities	6		6
	$	40	$	37

Summary of Amounts for Non-Consolidated Variable Interest Entities

Amounts for DTE Energy's non-consolidated VIEs as of June 30, 2016 and December 31, 2015 are as follows:

	June 30, 2016		December 31, 2015
	(In millions)
Investment in equity method investees	$	195	$	136
Notes receivable	$	15	$	15
Future funding commitments	$	8	$	—

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Significant Accounting Policies (Tables)

6 Months Ended

Jun. 30, 2016

Accounting Policies [Abstract]

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 June 30,				Six Months Ended June 30,				June 30,
	2016		2015		2016		2015		2016
									(In millions)
DTE Energy	26	%	20	%	26	%	28	%	$	3
DTE Electric	36	%	35	%	36	%	35	%	$	4

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Earnings Per Share (Tables)

6 Months Ended

Jun. 30, 2016

Earnings Per Share [Abstract]

Schedule of Earnings Per Share, Basic and Diluted

The following is a reconciliation of DTE Energy's basic and diluted income per share calculation for the three and six months endedJune 30:

	Three Months Ended June 30,					Six Months Ended June 30,
	2016		2015			2016		2015
	(In millions, except per share amounts)
Basic Earnings per Share
Net Income Attributable to DTE Energy Company	$	152	$	109		$	399	$	382
Average number of common shares outstanding	179		179			179		179
Dividends declared — common shares	$	131	$	124		$	261	$	247
Dividends declared — net restricted shares	—		—			1		1
Total distributed earnings	$	131	$	124		$	262	$	248
Net Income less distributed earnings	$	21	$	(15	)	$	137	$	134
Distributed (dividends per common share)	$	0.73	$	0.69		$	1.46	$	1.38
Undistributed	0.11		(0.08		)	0.76		0.75
Total Basic Earnings per Common Share	$	0.84	$	0.61		$	2.22	$	2.13
Diluted Earnings per Share
Net Income Attributable to DTE Energy Company	$	152	$	109		$	399	$	382
Average number of common shares outstanding	179		179			179		179
Average incremental shares from assumed exercise of options	1		—			1		—
Common shares for dilutive calculation	180		179			180		179
Dividends declared — common shares	$	131	$	124		$	261	$	247
Dividends declared — net restricted shares	—		—			1		1
Total distributed earnings	$	131	$	124		$	262	$	248
Net Income less distributed earnings	$	21	$	(15	)	$	137	$	134
Distributed (dividends per common share)	$	0.73	$	0.69		$	1.46	$	1.38
Undistributed	0.11		(0.08		)	0.76		0.75
Total Diluted Earnings per Common Share	$	0.84	$	0.61		$	2.22	$	2.13

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Fair Value (Tables)

6 Months Ended

Jun. 30, 2016

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 as of June 30, 2016 and December 31, 2015:

	June 30, 2016																	December 31, 2015
	Level 1			Level 2			Level 3			Other (a)		Netting (b)			Net Balance			Level 1			Level 2			Level 3			Other (a)		Netting (b)			Net Balance
	(In millions)
Assets:
Cash equivalents (c)	$	6		$	3		$	—		$	—	$	—		$	9		$	13		$	3		$	—		$	—	$	—		$	16
Nuclear decommissioning trusts	853			422			—			—		—			1,275			759			473			—			4		—			1,236
Other investments (d)	159			—			—			—		—			159			149			—			—			—		—			149
Derivative assets:
Commodity Contracts:
Natural Gas	171			65			62			—		(248		)	50			193			91			103			—		(285		)	102
Electricity	—			196			43			—		(207		)	32			—			239			68			—		(232		)	75
Other	1			2			4			—		(2		)	5			2			—			3			—		(2		)	3
Foreign currency exchange contracts	—			6			—			—		(5		)	1			—			12			—			—		(9		)	3
Total derivative assets	172			269			109			—		(462		)	88			195			342			174			—		(528		)	183
Total	$	1,190		$	694		$	109		$	—	$	(462	)	$	1,531		$	1,116		$	818		$	174		$	4	$	(528	)	$	1,584
Liabilities:
Derivative liabilities:
Commodity Contracts:
Natural Gas	$	(193	)	$	(58	)	$	(124	)	$	—	$	263		$	(112	)	$	(218	)	$	(57	)	$	(108	)	$	—	$	294		$	(89	)
Electricity	—			(191		)	(49		)	—		212			(28		)	—			(243		)	(62		)	—		253			(52		)
Other	(3		)	(3		)	(5		)	—		10			(1		)	(2		)	—			(8		)	—		8			(2		)
Foreign currency exchange contracts	—			(3		)	—			—		3			—			—			(7		)	—			—		7			—
Total derivative liabilities	(196		)	(255		)	(178		)	—		488			(141		)	(220		)	(307		)	(178		)	—		562			(143		)
Total	$	(196	)	$	(255	)	$	(178	)	$	—	$	488		$	(141	)	$	(220	)	$	(307	)	$	(178	)	$	—	$	562		$	(143	)
Net Assets (Liabilities) at the end of the period	$	994		$	439		$	(69	)	$	—	$	26		$	1,390		$	896		$	511		$	(4	)	$	4	$	34		$	1,441
Assets:
Current	$	151		$	220		$	67		$	—	$	(376	)	$	62		$	174		$	284		$	128		$	—	$	(441	)	$	145
Noncurrent	1,039			474			42			—		(86		)	1,469			942			534			46			4		(87		)	1,439
Total Assets	$	1,190		$	694		$	109		$	—	$	(462	)	$	1,531		$	1,116		$	818		$	174		$	4	$	(528	)	$	1,584
Liabilities:
Current	$	(166	)	$	(204	)	$	(72	)	$	—	$	395		$	(47	)	$	(174	)	$	(260	)	$	(87	)	$	—	$	464		$	(57	)
Noncurrent	(30		)	(51		)	(106		)	—		93			(94		)	(46		)	(47		)	(91		)	—		98			(86		)
Total Liabilities	$	(196	)	$	(255	)	$	(178	)	$	—	$	488		$	(141	)	$	(220	)	$	(307	)	$	(178	)	$	—	$	562		$	(143	)
Net Assets (Liabilities) at the end of the period	$	994		$	439		$	(69	)	$	—	$	26		$	1,390		$	896		$	511		$	(4	)	$	4	$	34		$	1,441

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

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

(c) At June 30, 2016, available-for-sale securities of $9 million included $6 million and $3 million of cash equivalents included in Restricted cash and Other investments on DTE Energy's Consolidated Statements of Financial Position, respectively. At December 31, 2015, available-for-sale securities of $16 million, included $8 million and $8 million of cash equivalents included in Restricted cash and Other investments on DTE Energy's Consolidated Statements of Financial Position, respectively.

(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 June 30, 2016 and December 31, 2015:

	June 30, 2016										December 31, 2015
	Level 1		Level 2		Level 3		Other (a)		Net Balance		Level 1		Level 2		Level 3		Other (a)		Net Balance
	(In millions)
Assets:
Cash equivalents (b)	$	—	$	3	$	—	$	—	$	3	$	5	$	3	$	—	$	—	$	8
Nuclear decommissioning trusts	853		422		—		—		1,275		759		473		—		4		1,236
Other investments	8		—		—		—		8		8		—		—		—		8
Derivative assets — FTRs	—		—		4		—		4		—		—		3		—		3
Total	$	861	$	425	$	4	$	—	$	1,290	$	772	$	476	$	3	$	4	$	1,255
Assets:
Current	$	—	$	3	$	4	$	—	$	7	$	5	$	3	$	3	$	—	$	11
Noncurrent	861		422		—		—		1,283		767		473		—		4		1,244
Total Assets	$	861	$	425	$	4	$	—	$	1,290	$	772	$	476	$	3	$	4	$	1,255

_______________________________________

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

(b) At June 30, 2016, available-for-sale securities of $3 million consisted of cash equivalents included in Other investments on DTE Electric's Consolidated Statements of Financial Position. At December 31, 2015, available-for-sale securities of $8 million consisted of cash equivalents included in Other investments on DTE Electric's Consolidated Statements of Financial Position.

Fair value reconciliation of level 3 assets and liabilities measured at fair value on a recurring basis

The following tables present the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for DTE Energy for the three and six months endedJune 30, 2016 and 2015:

	Three Months Ended June 30, 2016												Three Months Ended June 30, 2015
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of March 31	$	(34	)	$	(16	)	$	(7	)	$	(57	)	$	—		$	(7	)	$	(5	)	$	(12	)
Transfers into Level 3 from Level 2	—			—			—			—			—			—			—			—
Transfers from Level 3 into Level 2	—			—			—			—			—			—			—			—
Total gains (losses):
Included in earnings	(36		)	12			2			(22		)	(5		)	18			1			14
Recorded in Regulatory liabilities	—			—			6			6			—			—			13			13
Purchases, issuances, and settlements:
Purchases	—			1			—			1			—			1			—			1
Settlements	8			(3		)	(2		)	3			(3		)	(9		)	(8		)	(20		)
Net Assets (Liabilities) as of June 30	$	(62	)	$	(6	)	$	(1	)	$	(69	)	$	(8	)	$	3		$	1		$	(4	)
The amount of total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at June 30, 2016 and 2015 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	$	(41	)	$	(4	)	$	2		$	(43	)	$	(20	)	$	15		$	1		$	(4	)

	Six Months Ended June 30, 2016												Six Months Ended June 30, 2015
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of December 31	$	(5	)	$	6		$	(5	)	$	(4	)	$	30		$	(5	)	$	(1	)	$	24
Transfers into Level 3 from Level 2	—			—			—			—			—			—			—			—
Transfers from Level 3 into Level 2	(1		)	—			—			(1		)	—			—			—			—
Total gains (losses):
Included in earnings	(56		)	(46		)	1			(101		)	(35		)	24			(2		)	(13		)
Recorded in Regulatory liabilities	—			—			4			4			—			—			11			11
Purchases, issuances, and settlements:
Purchases	—			1			—			1			—			2			—			2
Settlements	—			33			(1		)	32			(3		)	(18		)	(7		)	(28		)
Net Assets (Liabilities) as of June 30	$	(62	)	$	(6	)	$	(1	)	$	(69	)	$	(8	)	$	3		$	1		$	(4	)
The amount of total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at June 30, 2016 and 2015 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	$	(113	)	$	(7	)	$	1		$	(119	)	$	(112	)	$	11		$	(1	)	$	(102	)

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 for the three and six months endedJune 30, 2016 and 2015:

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(In millions)
Net Assets as of beginning of period	$	1		$	1		$	3		$	3
Change in fair value recorded in Regulatory liabilities	6			13			4			11
Purchases, issuances, and settlements:
Settlements	(3		)	(9		)	(3		)	(9		)
Net Assets as of June 30	$	4		$	5		$	4		$	5
The amount of total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets held at June 30, 2016 and 2015 and reflected in DTE Electric's Consolidated Statements of Financial Position	$	4		$	5		$	4		$	5

Unobservable inputs related to Level 3 assets and liabilities

The following tables present the unobservable inputs related to DTE Energy's Level 3 assets and liabilities as of June 30, 2016 and December 31, 2015:

	June 30, 2016
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range						Weighted Average
	(In millions)
Natural Gas	$	62	$	(124	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.36	) —	$	3.68	/MMBtu	$	(0.10	)/MMBtu
Electricity	$	43	$	(49	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(14	) —	$	13	/MWh	$	1	/MWh

	December 31, 2015
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range						Weighted Average
	(In millions)
Natural Gas	$	103	$	(108	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.50	) —	$	2.77	/MMBtu	$	(0.19	)/MMBtu
Electricity	$	68	$	(62	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(11	) —	$	14	/MWh	$	2	/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 as of June 30, 2016 and December 31, 2015:

	June 30, 2016								December 31, 2015
	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	$	32	$	—	$	—	$	32	$	32	$	—	$	—	$	32
Dividends payable	$	269	$	269	$	—	$	—	$	131	$	131	$	—	$	—
Short-term borrowings	$	175	$	—	$	175	$	—	$	499	$	—	$	499	$	—
Long-term debt, excluding capital leases	$	9,488	$	807	$	8,538	$	1,438	$	9,210	$	496	$	8,136	$	1,203

The following table presents the carrying amount and fair value of financial instruments for DTE Electric as of June 30, 2016 and December 31, 2015:

	June 30, 2016								December 31, 2015
	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	$	5	$	—	$	—	$	5
Notes receivable — affiliates	$	62	$	—	$	—	$	62	$	—	$	—	$	—	$	—
Short-term borrowings — affiliates	$	108	$	—	$	—	$	108	$	75	$	—	$	—	$	75
Short-term borrowings — other	$	—	$	—	$	—	$	—	$	272	$	—	$	272	$	—
Long-term debt, excluding capital leases	$	5,877	$	—	$	5,999	$	755	$	5,588	$	—	$	5,432	$	545

Fair value of nuclear decommissioning trust fund assets

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

	June 30, 2016		December 31, 2015
	(In millions)
Fermi 2	$	1,247	$	1,211
Fermi 1	3		3
Low-level radioactive waste	25		22
Total	$	1,275	$	1,236

Schedule of realized gain (loss)

The following table sets forth DTE Electric's gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds:

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(In millions)
Realized gains	$	37		$	13		$	46		$	22
Realized losses	$	(25	)	$	(5	)	$	(40	)	$	(12	)
Proceeds from sales of securities	$	481		$	194		$	741		$	440

Fair value and unrealized gains and losses for nuclear decommissioning trust fund

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

	June 30, 2016							December 31, 2015
	Fair Value		Unrealized Gains		Unrealized Losses			Fair Value		Unrealized Gains		Unrealized Losses
	(In millions)
Equity securities	$	831	$	180	$	(53	)	$	731	$	195	$	(68	)
Debt securities	438		29		(2		)	499		16		(4		)
Cash and cash equivalents	6		—		—			6		—		—
	$	1,275	$	209	$	(55	)	$	1,236	$	211	$	(72	)

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Financial and Other Derivative Instruments (Tables)

6 Months Ended

Jun. 30, 2016

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair value of derivative instruments

The following table presents the fair value of derivative instruments as of June 30, 2016 and December 31, 2015 for DTE Energy:

	June 30, 2016					December 31, 2015
	Derivative Assets		Derivative Liabilities			Derivative Assets		Derivative Liabilities
	(In millions)
Derivatives not designated as hedging instruments:
Commodity Contracts:
Natural Gas	$	298	$	(375	)	$	387	$	(383	)
Electricity	239		(240		)	307		(305		)
Other	7		(11		)	5		(10		)
Foreign currency exchange contracts	6		(3		)	12		(7		)
Total derivatives not designated as hedging instruments:	$	550	$	(629	)	$	711	$	(705	)
Current	$	429	$	(442	)	$	570	$	(521	)
Noncurrent	121		(187		)	141		(184		)
Total derivatives	$	550	$	(629	)	$	711	$	(705	)

The following table presents the fair value of derivative instruments as of June 30, 2016 and December 31, 2015 for DTE Electric:

	June 30, 2016		December 31, 2015
	(In millions)
FTRs — Other current assets	$	4	$	3
Total derivatives not designated as hedging instrument	$	4	$	3

Netting Offsets of Derivative Assets and Liabilities

The following table presents the netting offsets of Derivative assets and liabilities for DTE Energy at June 30, 2016 and December 31, 2015:

	June 30, 2016									December 31, 2015
	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	$	298		$	(248	)	$	50		$	387		$	(285	)	$	102
Electricity	239			(207		)	32			307			(232		)	75
Other	7			(2		)	5			5			(2		)	3
Foreign currency exchange contracts	6			(5		)	1			12			(9		)	3
Total derivative assets	$	550		$	(462	)	$	88		$	711		$	(528	)	$	183
Derivative liabilities:
Commodity Contracts:
Natural Gas	$	(375	)	$	263		$	(112	)	$	(383	)	$	294		$	(89	)
Electricity	(240		)	212			(28		)	(305		)	253			(52		)
Other	(11		)	10			(1		)	(10		)	8			(2		)
Foreign currency exchange contracts	(3		)	3			—			(7		)	7			—
Total derivative liabilities	$	(629	)	$	488		$	(141	)	$	(705	)	$	562		$	(143	)

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 at June 30, 2016 and December 31, 2015:

	June 30, 2016												December 31, 2015
	Derivative Assets						Derivative Liabilities						Derivative Assets						Derivative Liabilities
	Current			Noncurrent			Current			Noncurrent			Current			Noncurrent			Current			Noncurrent
	(In millions)
Total fair value of derivatives	$	429		$	121		$	(442	)	$	(187	)	$	570		$	141		$	(521	)	$	(184	)
Counterparty netting	(372		)	(84		)	372			84			(441		)	(85		)	441			85
Collateral adjustment	(4		)	(2		)	23			9			—			(2		)	23			13
Total derivatives as reported	$	53		$	35		$	(47	)	$	(94	)	$	129		$	54		$	(57	)	$	(86	)

Gain (Loss) Recognized in Income on Derivative

The effect of derivatives not designated as hedging instruments on DTE Energy's Consolidated Statements of Operations for the three and six months endedJune 30, 2016 and 2015 for DTE Energy 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 June 30,						Gain (Loss) Recognized in Income on Derivatives for the Six Months Ended June 30,
		2016			2015			2016			2015
		(In millions)
Commodity Contracts:
Natural Gas	Operating Revenues — Non-utility operations	$	(30	)	$	(4	)	$	(86	)	$	(130	)
Natural Gas	Fuel, purchased power, and gas — non-utility	(9		)	12			32			33
Electricity	Operating Revenues — Non-utility operations	19			15			(5		)	46
Other	Operating Revenues — Non-utility operations	—			2			(2		)	—
Foreign currency exchange contracts	Operating Revenues — Non-utility operations	1			—			(4		)	1
Total		$	(19	)	$	25		$	(65	)	$	(50	)

Volume of Commodity Contracts

The following represents the cumulative gross volume of DTE Energy's derivative contracts outstanding as of June 30, 2016:

Commodity	Number of Units
Natural Gas (MMBtu)	1,838,453,487
Electricity (MWh)	37,370,289
Oil (Gallons)	18,102,000
Foreign Currency Exchange (Canadian dollars)	80,449,368

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Long-Term Debt (Tables)

6 Months Ended

Jun. 30, 2016

Long-term Debt, Unclassified [Abstract]

Schedule Of Issued Debt

In 2016, the following debt was issued:

Company	Month	Type	Interest Rate	Maturity	Amount
					(In millions)
DTE Electric	May	Mortgage Bonds	3.70%	2046	$	300
DTE Energy	May	Junior Subordinated Debentures	5.375%	2076	300
					$	600

Schedule of Debt Redemptions

In 2016, the following debt was redeemed:

Company	Month	Type	Interest Rate	Maturity	Amount
					(In millions)
DTE Electric	March	Mortgage Bonds	7.904%	2016	$	10
DTE Energy	June	Senior Notes	6.35%	2016	300
DTE Energy	Various	Other Long-Term Debt	Various	2016	3
					$	313

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Short-Term Credit Arrangements and Borrowings (Tables)

6 Months Ended

Jun. 30, 2016

Short-term Debt [Abstract]

Schedule of Line of Credit Facilities

The availability under the facilities in place at June 30, 2016 is shown in the following table:

	DTE Energy		DTE Electric		DTE Gas		Total
	(In millions)
Unsecured letter of credit facility, expiring in February 2017	$	100	$	—	$	—	$	100
Unsecured letter of credit facility, expiring in September 2017	70		—		—		70
Unsecured revolving credit facility, expiring April 2021	1,200		400		300		1,900
	1,370		400		300		2,070
Amounts outstanding at June 30, 2016
Commercial paper issuances	175		—		—		175
Letters of credit	139		—		—		139
	314		—		—		314
Net availability at June 30, 2016	$	1,056	$	400	$	300	$	1,756

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Retirement Benefits and Trusteed Assets (Tables)

6 Months Ended

Jun. 30, 2016

Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]

Schedule of Net Benefit Costs

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
	2016			2015			2016			2015
Three Months Ended June 30,	(In millions)
Service cost	$	23		$	24		$	7		$	8
Interest cost	55			53			20			21
Expected return on plan assets	(78		)	(74		)	(32		)	(32		)
Amortization of:
Net actuarial loss	41			52			8			11
Prior service credit	—			—			(29		)	(32		)
Net periodic benefit cost (credit)	$	41		$	55		$	(26	)	$	(24	)

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
Six Months Ended June 30,	(In millions)
Service cost	$	46		$	49		$	13		$	17
Interest cost	109			106			40			41
Expected return on plan assets	(155		)	(148		)	(64		)	(65		)
Amortization of:
Net actuarial loss	81			103			16			22
Prior service credit	—			—			(59		)	(63		)
Net periodic benefit cost (credit)	$	81		$	110		$	(54	)	$	(48	)

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
	2016			2015			2016			2015
Three Months Ended June 30,	(In millions)
Service cost	$	17		$	18		$	5		$	6
Interest cost	42			41			16			15
Expected return on plan assets	(55		)	(52		)	(22		)	(22		)
Amortization of:
Net actuarial loss	28			36			5			8
Prior service cost (credit)	1			1			(22		)	(23		)
Net periodic benefit cost (credit)	$	33		$	44		$	(18	)	$	(16	)

	Pension Benefits						Other Postretirement Benefits
	2016			2015			2016			2015
Six Months Ended June 30,	(In millions)
Service cost	$	35		$	38		$	10		$	13
Interest cost	83			81			31			31
Expected return on plan assets	(110		)	(105		)	(45		)	(45		)
Amortization of:
Net actuarial loss	57			74			11			16
Prior service cost (credit)	1			1			(44		)	(47		)
Net periodic benefit cost (credit)	$	66		$	89		$	(37	)	$	(32	)

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Segment and Related Information (Tables)

6 Months Ended

Jun. 30, 2016

Segment Reporting [Abstract]

Schedule of Segment Reporting Information, by Segment

Inter-segment billing for goods and services exchanged between segments is based upon tariffed or market-based prices of the provider and primarily consists of the sale of reduced emissions fuel, power sales, and natural gas sales in the following segments:

	Three Months Ended June 30,				Six Months Ended June 30,
	2016		2015		2016		2015
	(In millions)
Inter-segment Revenues
Electric	$	8	$	9	$	17	$	18
Gas	3		—		3		1
Gas Storage and Pipelines	3		5		5		6
Power and Industrial Projects	150		215		298		395
Energy Trading	8		7		18		16
Corporate and Other	2		—		2		1
	$	174	$	236	$	343	$	437

Financial data of the DTE Energy business segments follows:

	Three Months Ended June 30,						Six Months Ended June 30,
	2016			2015			2016			2015
	(In millions)
Operating Revenues — Utility operations
Electric	$	1,215		$	1,148		$	2,368		$	2,351
Gas	231			218			751			865
Operating Revenues — Non-utility operations
Gas Storage and Pipelines	69			57			136			114
Power and Industrial Projects	444			556			890			1,123
Energy Trading	476			524			1,025			1,235
Corporate and Other	1			1			1			1
Reconciliation and Eliminations	(174		)	(236		)	(343		)	(437		)
Total	$	2,262		$	2,268		$	4,828		$	5,252

Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	135		$	99		$	262		$	235
Gas	13			(7		)	100			104
Gas Storage and Pipelines	35			25			65			52
Power and Industrial Projects	15			8			32			41
Energy Trading	(23		)	(3		)	(30		)	(12		)
Corporate and Other	(23		)	(13		)	(30		)	(38		)
Net Income Attributable to DTE Energy Company	$	152		$	109		$	399		$	382

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Organization and Basis of Presentation (Details Textuals) customer in Millions	Jun. 30, 2016 USD ($) customer
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Number of electric utility customers | customer	2.2
Number of gas utility customers | customer	1.2
Significant potential exposure | $	$ 0
DTE Electric
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Significant potential exposure | $	$ 0

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Organization and Basis of Presentation (Consolidated Variable Interest Entities) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015	Jun. 30, 2015	Dec. 31, 2014
ASSETS
Cash and cash equivalents	$ 32	$ 37	$ 230	$ 48
Restricted cash	22	23
Accounts receivable	1,180	1,276
Property, plant, and equipment, net	18,295	18,034
Total Assets	28,769	28,662
LIABILITIES
Current portion long-term debt, including capital leases	165	473
Mortgage bonds, notes, and other	8,551	8,265
Variable Interest Entity, Primary Beneficiary
ASSETS
Cash and cash equivalents	11	14
Restricted cash	6	8
Accounts receivable	29	18
Inventories	101	82
Property, plant, and equipment, net	59	66
Other current and long-term assets	2	4
Total Assets	208	192
LIABILITIES
Accounts payable and accrued current liabilities	21	13
Current portion long-term debt, including capital leases	6	8
Mortgage bonds, notes, and other	7	10
Other current and long-term liabilities	6	6
Total Liabilities	$ 40	$ 37

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Organization and Basis of Presentation (Non Consolidated Variable Interest Entities) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Variable Interest Entity [Line Items]
Investment in equity method investees	$ 633	$ 514
Notes receivable	77	85
Variable Interest Entity, Not Primary Beneficiary
Variable Interest Entity [Line Items]
Investment in equity method investees	195	136
Notes receivable	15	15
Future funding commitments	$ 8	$ 0

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Significant Accounting Policies (Details Textuals) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Significant Accounting Policies [Line Items]
Other income	$ 57	$ 49	$ 109	$ 100
Effective tax rate increase (decrease)	6.00%
Unrecognized tax benefits that would impact effective tax rate	$ 2		2
Unrecognized compensation cost	77		$ 77
Recognition period (in years)			1 year 6 months 21 days
Power and Industrial Projects
Significant Accounting Policies [Line Items]
Other income	20	20	$ 39	39
DTE Electric
Significant Accounting Policies [Line Items]
Other income	17	13	33	28
Unrecognized tax benefits that would impact effective tax rate	3		3
DTE Electric | DTE Energy
Significant Accounting Policies [Line Items]
Income tax receivable	8		8		$ 6
Allocated costs	$ 9	$ 8	$ 19	$ 12

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Significant Accounting Policies (Income Taxes) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Schedule of Income Taxes [Line Items]
Effective Tax Rate	26.00%	20.00%	26.00%	28.00%
Unrecognized Tax Benefits	$ 3		$ 3
DTE Electric
Schedule of Income Taxes [Line Items]
Effective Tax Rate	36.00%	35.00%	36.00%	35.00%
Unrecognized Tax Benefits	$ 4		$ 4

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New Accounting Pronouncements (Details) - ASU No. 2015-03 $ in Millions	Dec. 31, 2015 USD ($)
Liability
New Accounting Pronouncement, Early Adoption [Line Items]
Debt issuance cost	$ 75
Assets
New Accounting Pronouncement, Early Adoption [Line Items]
Debt issuance cost	(75)
DTE Electric | Liability
New Accounting Pronouncement, Early Adoption [Line Items]
Debt issuance cost	36
DTE Electric | Assets
New Accounting Pronouncement, Early Adoption [Line Items]
Debt issuance cost	$ (36)

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Regulatory Matters (Details Textuals) - MPSC - USD ($) $ in Millions					1 Months Ended
	Jul. 01, 2016	May 11, 2016	Feb. 01, 2016	Dec. 18, 2015	Jan. 31, 2017
Electric Rate Case Filing 2016 | DTE Electric
Public Utilities, General Disclosures [Line Items]
Requested rate increase			$ 344
Return on equity percent			10.30%
Return on equity requested percent			10.50%
Capital structure equity percent			50.00%
Capital structure debt percent			50.00%
DTE Gas Rate Case Filing 2015 | DTE Gas
Public Utilities, General Disclosures [Line Items]
Requested rate increase				$ 183
Return on equity percent				10.50%
Return on equity requested percent				10.75%
Capital structure equity percent				52.00%
Capital structure debt percent				48.00%
Self-implemented base rate		$ 103
IRM surcharges				$ 41
Subsequent Event | Electric Rate Case Filing 2016 | DTE Electric
Public Utilities, General Disclosures [Line Items]
Self-implemented base rate	$ 245
Scenario, Forecast | DTE Gas Rate Case Filing 2015 | DTE Gas
Public Utilities, General Disclosures [Line Items]
IRM surcharges					$ 9

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Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Basic Earnings per Share
Net Income (Loss) Attributable to DTE Energy Company	$ 152	$ 109	$ 399	$ 382
Average number of common shares outstanding	179	179	179	179
Dividends declared — common shares	$ 131	$ 124	$ 261	$ 247
Dividends declared — net restricted shares	0	0	1	1
Total distributed earnings	131	124	262	248
Net Income less distributed earnings	$ 21	$ (15)	$ 137	$ 134
Distributed (dividends per common share) (dollars per share)	$ 0.73	$ 0.69	$ 1.46	$ 1.38
Undistributed (dollars per share)	0.11	(0.08)	0.76	0.75
Total Basic Earnings per Common Share (dollars per share)	$ 0.84	$ 0.61	$ 2.22	$ 2.13
Diluted Earnings per Share
Net Income (Loss) Attributable to DTE Energy Company	$ 152	$ 109	$ 399	$ 382
Average number of common shares outstanding	179	179	179	179
Average incremental shares from assumed exercise of options (in shares)	1	0	1	0
Common shares for dilutive calculation	180	179	180	179
Dividends declared — common shares	$ 131	$ 124	$ 261	$ 247
Dividends declared — net restricted shares	0	0	1	1
Total distributed earnings	131	124	262	248
Net Income less distributed earnings	$ 21	$ (15)	$ 137	$ 134
Distributed (dividends per common share) (dollars per share)	$ 0.73	$ 0.69	$ 1.46	$ 1.38
Undistributed (dollars per share)	0.11	(0.08)	0.76	0.75
Total Diluted Earnings per Common Share (dollars per share)	$ 0.84	$ 0.61	$ 2.22	$ 2.13

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Fair Value (Assets and Liabilities Recorded at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Derivative Assets
Derivative Assets, gross	$ 550	$ 711
Derivative asset, netting	(462)	(528)
Derivative assets, net	88	183
Derivative Liabilities
Derivative Liabilities	(629)	(705)
Derivative liability, netting	488	562
Derivative liabilities, net	(141)	(143)
Current derivative liability
Derivative Liabilities
Derivative Liabilities	(442)	(521)
Noncurrent derivative liability
Derivative Liabilities
Derivative Liabilities	(187)	(184)
Natural Gas
Derivative Assets
Derivative Assets, gross	298	387
Derivative asset, netting	(248)	(285)
Derivative assets, net	50	102
Derivative Liabilities
Derivative Liabilities	(375)	(383)
Derivative liability, netting	263	294
Derivative liabilities, net	(112)	(89)
Electricity
Derivative Assets
Derivative Assets, gross	239	307
Derivative asset, netting	(207)	(232)
Derivative assets, net	32	75
Derivative Liabilities
Derivative Liabilities	(240)	(305)
Derivative liability, netting	212	253
Derivative liabilities, net	(28)	(52)
Other
Derivative Assets
Derivative Assets, gross	7	5
Derivative asset, netting	(2)	(2)
Derivative assets, net	5	3
Derivative Liabilities
Derivative Liabilities	(11)	(10)
Derivative liability, netting	10	8
Derivative liabilities, net	(1)	(2)
Foreign currency exchange contracts
Derivative Assets
Derivative Assets, gross	6	12
Derivative asset, netting	(5)	(9)
Derivative assets, net	1	3
Derivative Liabilities
Derivative Liabilities	(3)	(7)
Derivative liability, netting	3	7
Derivative liabilities, net	0	0
Recurring
ASSETS
Cash equivalents	9	16
Nuclear decommissioning trusts	1,275	1,236
Alternative Investments valued at NAV as practical expedient for FV	0	4
Other investments	159	149
Derivative Assets
Derivative asset, netting	(462)	(528)
Derivative assets, net	88	183
Total assets	1,531	1,584
Derivative Liabilities
Derivative liability, netting	488	562
Derivative liabilities, net	(141)	(143)
Net Assets (Liabilities) at the end of the period	1,390	1,441
Net Assets (Liabilities) at the end of the period, netting	26	34
Recurring | Nuclear decommissioning trust fund
ASSETS
Alternative Investments valued at NAV as practical expedient for FV	0	4
Recurring | Restricted Assets
ASSETS
Cash equivalents	6	8
Recurring | Other Investments
ASSETS
Cash equivalents	3	8
Recurring | Current asset
Derivative Assets
Derivative asset, netting	(376)	(441)
Total assets	62	145
Recurring | Noncurrent asset
ASSETS
Alternative Investments valued at NAV as practical expedient for FV	0	4
Derivative Assets
Derivative asset, netting	(86)	(87)
Total assets	1,469	1,439
Recurring | Current derivative liability
Derivative Liabilities
Derivative liability, netting	395	464
Derivative liabilities, net	(47)	(57)
Recurring | Noncurrent derivative liability
Derivative Liabilities
Derivative liability, netting	93	98
Derivative liabilities, net	(94)	(86)
Recurring | Natural Gas
Derivative Assets
Derivative asset, netting	(248)	(285)
Derivative assets, net	50	102
Derivative Liabilities
Derivative liability, netting	263	294
Derivative liabilities, net	(112)	(89)
Recurring | Electricity
Derivative Assets
Derivative asset, netting	(207)	(232)
Derivative assets, net	32	75
Derivative Liabilities
Derivative liability, netting	212	253
Derivative liabilities, net	(28)	(52)
Recurring | Other
Derivative Assets
Derivative asset, netting	(2)	(2)
Derivative assets, net	5	3
Derivative Liabilities
Derivative liability, netting	10	8
Derivative liabilities, net	(1)	(2)
Recurring | Foreign currency exchange contracts
Derivative Assets
Derivative asset, netting	(5)	(9)
Derivative assets, net	1	3
Derivative Liabilities
Derivative liability, netting	3	7
Derivative liabilities, net	0	0
Recurring | Level 1
ASSETS
Cash equivalents	6	13
Nuclear decommissioning trusts	853	759
Other investments	159	149
Derivative Assets
Derivative Assets, gross	172	195
Total assets	1,190	1,116
Derivative Liabilities
Derivative Liabilities	(196)	(220)
Net Assets (Liabilities) at the end of the period	994	896
Recurring | Level 1 | Current asset
Derivative Assets
Total assets	151	174
Recurring | Level 1 | Noncurrent asset
Derivative Assets
Total assets	1,039	942
Recurring | Level 1 | Current derivative liability
Derivative Liabilities
Derivative Liabilities	(166)	(174)
Recurring | Level 1 | Noncurrent derivative liability
Derivative Liabilities
Derivative Liabilities	(30)	(46)
Recurring | Level 1 | Natural Gas
Derivative Assets
Derivative Assets, gross	171	193
Derivative Liabilities
Derivative Liabilities	(193)	(218)
Recurring | Level 1 | Electricity
Derivative Assets
Derivative Assets, gross	0	0
Derivative Liabilities
Derivative Liabilities	0	0
Recurring | Level 1 | Other
Derivative Assets
Derivative Assets, gross	1	2
Derivative Liabilities
Derivative Liabilities	(3)	(2)
Recurring | Level 1 | Foreign currency exchange contracts
Derivative Assets
Derivative Assets, gross	0	0
Derivative Liabilities
Derivative Liabilities	0	0
Recurring | Level 2
ASSETS
Cash equivalents	3	3
Nuclear decommissioning trusts	422	473
Other investments	0	0
Derivative Assets
Derivative Assets, gross	269	342
Total assets	694	818
Derivative Liabilities
Derivative Liabilities	(255)	(307)
Net Assets (Liabilities) at the end of the period	439	511
Recurring | Level 2 | Current asset
Derivative Assets
Total assets	220	284
Recurring | Level 2 | Noncurrent asset
Derivative Assets
Total assets	474	534
Recurring | Level 2 | Current derivative liability
Derivative Liabilities
Derivative Liabilities	(204)	(260)
Recurring | Level 2 | Noncurrent derivative liability
Derivative Liabilities
Derivative Liabilities	(51)	(47)
Recurring | Level 2 | Natural Gas
Derivative Assets
Derivative Assets, gross	65	91
Derivative Liabilities
Derivative Liabilities	(58)	(57)
Recurring | Level 2 | Electricity
Derivative Assets
Derivative Assets, gross	196	239
Derivative Liabilities
Derivative Liabilities	(191)	(243)
Recurring | Level 2 | Other
Derivative Assets
Derivative Assets, gross	2	0
Derivative Liabilities
Derivative Liabilities	(3)	0
Recurring | Level 2 | Foreign currency exchange contracts
Derivative Assets
Derivative Assets, gross	6	12
Derivative Liabilities
Derivative Liabilities	(3)	(7)
Recurring | Level 3
ASSETS
Cash equivalents	0	0
Nuclear decommissioning trusts	0	0
Other investments	0	0
Derivative Assets
Derivative Assets, gross	109	174
Total assets	109	174
Derivative Liabilities
Derivative Liabilities	(178)	(178)
Net Assets (Liabilities) at the end of the period	(69)	(4)
Recurring | Level 3 | Current asset
Derivative Assets
Total assets	67	128
Recurring | Level 3 | Noncurrent asset
Derivative Assets
Total assets	42	46
Recurring | Level 3 | Current derivative liability
Derivative Liabilities
Derivative Liabilities	(72)	(87)
Recurring | Level 3 | Noncurrent derivative liability
Derivative Liabilities
Derivative Liabilities	(106)	(91)
Recurring | Level 3 | Natural Gas
Derivative Assets
Derivative Assets, gross	62	103
Derivative Liabilities
Derivative Liabilities	(124)	(108)
Recurring | Level 3 | Electricity
Derivative Assets
Derivative Assets, gross	43	68
Derivative Liabilities
Derivative Liabilities	(49)	(62)
Recurring | Level 3 | Other
Derivative Assets
Derivative Assets, gross	4	3
Derivative Liabilities
Derivative Liabilities	(5)	(8)
Recurring | Level 3 | Foreign currency exchange contracts
Derivative Assets
Derivative Assets, gross	0	0
Derivative Liabilities
Derivative Liabilities	0	0
DTE Electric | Recurring
ASSETS
Cash equivalents	3	8
Nuclear decommissioning trusts	1,275	1,236
Alternative Investments valued at NAV as practical expedient for FV	0	4
Other investments	8	8
Derivative Assets
Total assets	1,290	1,255
DTE Electric | Recurring | Nuclear decommissioning trust fund
ASSETS
Alternative Investments valued at NAV as practical expedient for FV	0	4
DTE Electric | Recurring | Other Investments
ASSETS
Cash equivalents	3	8
DTE Electric | Recurring | Current asset
Derivative Assets
Total assets	7	11
DTE Electric | Recurring | Noncurrent asset
ASSETS
Alternative Investments valued at NAV as practical expedient for FV	0	4
Derivative Assets
Total assets	1,283	1,244
DTE Electric | Recurring | Financial transmission rights
Derivative Assets
Derivative assets, net	4	3
DTE Electric | Recurring | Level 1
ASSETS
Cash equivalents	0	5
Nuclear decommissioning trusts	853	759
Other investments	8	8
Derivative Assets
Total assets	861	772
DTE Electric | Recurring | Level 1 | Current asset
Derivative Assets
Total assets	0	5
DTE Electric | Recurring | Level 1 | Noncurrent asset
Derivative Assets
Total assets	861	767
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
Nuclear decommissioning trusts	422	473
Other investments	0	0
Derivative Assets
Total assets	425	476
DTE Electric | Recurring | Level 2 | Current asset
Derivative Assets
Total assets	3	3
DTE Electric | Recurring | Level 2 | Noncurrent asset
Derivative Assets
Total assets	422	473
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
Nuclear decommissioning trusts	0	0
Other investments	0	0
Derivative Assets
Total assets	4	3
DTE Electric | Recurring | Level 3 | Current asset
Derivative Assets
Total assets	4	3
DTE Electric | Recurring | Level 3 | Noncurrent asset
Derivative Assets
Total assets	0	0
DTE Electric | Recurring | Level 3 | Financial transmission rights
Derivative Assets
Derivative assets, net	$ 4	$ 3

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Fair Value (Reconciliation of Level 3 Assets and Liabilities at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net Assets (Liabilities) as of beginning of period	$ (57)	$ (12)	$ (4)	$ 24
Transfers into Level 3 from Level 2	0	0	0	0
Transfers from Level 3 into Level 2	0	0	(1)	0
Total gains (losses):
Included in earnings	(22)	14	(101)	(13)
Recorded in Regulatory liabilities	6	13	4	11
Purchases, issuances, and settlements:
Purchases	1	1	1	2
Settlements	3	(20)	32	(28)
Net Assets (Liabilities) as of end of period	(69)	(4)	(69)	(4)
The amount of total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at June 30, 2016 and 2015 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	(43)	(4)	(119)	(102)
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	1	1	3	3
Total gains (losses):
Recorded in Regulatory liabilities	6	13	4	11
Purchases, issuances, and settlements:
Settlements	(3)	(9)	(3)	(9)
Net Assets (Liabilities) as of end of period	4	5	4	5
The amount of total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets held at June 30, 2016 and 2015 and reflected in DTE Electric's Consolidated Statements of Financial Position	4	5	4	5
Natural Gas
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net Assets (Liabilities) as of beginning of period	(34)	0	(5)	30
Transfers into Level 3 from Level 2	0	0	0	0
Transfers from Level 3 into Level 2	0	0	(1)	0
Total gains (losses):
Included in earnings	(36)	(5)	(56)	(35)
Recorded in Regulatory liabilities	0	0	0	0
Purchases, issuances, and settlements:
Purchases	0	0	0	0
Settlements	8	(3)	0	(3)
Net Assets (Liabilities) as of end of period	(62)	(8)	(62)	(8)
The amount of total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at June 30, 2016 and 2015 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	(41)	(20)	(113)	(112)
Electricity
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net Assets (Liabilities) as of beginning of period	(16)	(7)	6	(5)
Transfers into Level 3 from Level 2	0	0	0	0
Transfers from Level 3 into Level 2	0	0	0	0
Total gains (losses):
Included in earnings	12	18	(46)	24
Recorded in Regulatory liabilities	0	0	0	0
Purchases, issuances, and settlements:
Purchases	1	1	1	2
Settlements	(3)	(9)	33	(18)
Net Assets (Liabilities) as of end of period	(6)	3	(6)	3
The amount of total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at June 30, 2016 and 2015 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	(4)	15	(7)	11
Other
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net Assets (Liabilities) as of beginning of period	(7)	(5)	(5)	(1)
Transfers into Level 3 from Level 2	0	0	0	0
Transfers from Level 3 into Level 2	0	0	0	0
Total gains (losses):
Included in earnings	2	1	1	(2)
Recorded in Regulatory liabilities	6	13	4	11
Purchases, issuances, and settlements:
Purchases	0	0	0	0
Settlements	(2)	(8)	(1)	(7)
Net Assets (Liabilities) as of end of period	(1)	1	(1)	1
The amount of total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at June 30, 2016 and 2015 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	$ 2	$ 1	$ 1	$ (1)

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Fair Value (Unobservable Inputs related to Level 3 Assets and Liabilities) (Details) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2016 USD ($) $ / MWh $ / MMBTU	Dec. 31, 2015 USD ($) $ / MWh $ / MMBTU
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets, gross	$ 550	$ 711
Derivative Liabilities	(629)	(705)
Recurring | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets, gross	109	174
Derivative Liabilities	(178)	(178)
Natural Gas
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets, gross	298	387
Derivative Liabilities	(375)	(383)
Natural Gas | Recurring | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets, gross	62	103
Derivative Liabilities	$ (124)	$ (108)
Natural Gas | Minimum | Discounted cash flow valuation technique | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MMBTU	(1.36)	(1.50)
Natural Gas | Maximum | Discounted cash flow valuation technique | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MMBTU	3.68	2.77
Natural Gas | Weighted Average | Discounted cash flow valuation technique | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MMBTU	(0.10)	(0.19)
Electricity
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets, gross	$ 239	$ 307
Derivative Liabilities	(240)	(305)
Electricity | Recurring | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets, gross	43	68
Derivative Liabilities	$ (49)	$ (62)
Electricity | Minimum | Discounted cash flow valuation technique | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MWh	(14)	(11)
Electricity | Maximum | Discounted cash flow valuation technique | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MWh	13	14
Electricity | Weighted Average | Discounted cash flow valuation technique | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MWh	1	2

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Fair Value (Fair Value of Financial Instruments) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	$ 32	$ 32
Dividends payable	269	131
Short-term borrowings	175	499
Long-term debt, excluding capital leases	9,488	9,210
Carrying Amount | DTE Electric
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	5	5
Short-term borrowings	0	272
Long-term debt, excluding capital leases	5,877	5,588
Carrying Amount | DTE Electric | Affiliates
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	62	0
Short-term borrowings	108	75
Fair Value | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	0	0
Dividends payable	269	131
Short-term borrowings	0	0
Long-term debt, excluding capital leases	807	496
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
Long-term debt, excluding capital leases	0	0
Fair Value | Level 1 | DTE Electric | Affiliates
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	0	0
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	175	499
Long-term debt, excluding capital leases	8,538	8,136
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	0	272
Long-term debt, excluding capital leases	5,999	5,432
Fair Value | Level 2 | DTE Electric | Affiliates
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	0	0
Short-term borrowings	0	0
Fair Value | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	32	32
Dividends payable	0	0
Short-term borrowings	0	0
Long-term debt, excluding capital leases	1,438	1,203
Fair Value | Level 3 | DTE Electric
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	5	5
Short-term borrowings	0	0
Long-term debt, excluding capital leases	755	545
Fair Value | Level 3 | DTE Electric | Affiliates
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	62	0
Short-term borrowings	$ 108	$ 75

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Fair Value (Fair Value of Nuclear Decommissioning Trust Fund Assets) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Schedule of Available-for-sale Securities [Line Items]
Nuclear decommissioning trust funds	$ 1,275	$ 1,236
DTE Electric
Schedule of Available-for-sale Securities [Line Items]
Nuclear decommissioning trust funds	1,275	1,236
DTE Electric | Fermi 2
Schedule of Available-for-sale Securities [Line Items]
Nuclear decommissioning trust funds	1,247	1,211
DTE Electric | Fermi 1
Schedule of Available-for-sale Securities [Line Items]
Nuclear decommissioning trust funds	3	3
DTE Electric | Low-level radioactive waste
Schedule of Available-for-sale Securities [Line Items]
Nuclear decommissioning trust funds	25	22
DTE Electric | Nuclear decommissioning trust fund
Schedule of Available-for-sale Securities [Line Items]
Nuclear decommissioning trust funds	$ 1,275	$ 1,236

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Fair Value (Gains and Losses and Proceeds from the Sale of Securities by the Nuclear Decommissioning Trust Funds) (Details) - DTE Electric - Nuclear decommissioning trust fund - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Schedule of Available-for-sale Securities [Line Items]
Realized gains	$ 37	$ 13	$ 46	$ 22
Realized losses	(25)	(5)	(40)	(12)
Proceeds from sales of securities	$ 481	$ 194	$ 741	$ 440

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Fair Value (Fair Value and Unrealized Gains and Losses for the Nuclear Decommissioning Trust Funds) (Details) - DTE Electric - Nuclear decommissioning trust fund - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Schedule of Available-for-sale Securities [Line Items]
Equity securities, fair value	$ 831	$ 731
Debt securities, fair value	438	499
Cash and cash equivalents	6	6
Fair Value	1,275	1,236
Equity securities, unrealized gains	180	195
Debt securities, unrealized gains	29	16
Unrealized Gains	209	211
Equity securities, unrealized losses	(53)	(68)
Debt securities, unrealized losses	(2)	(4)
Unrealized Losses	$ (55)	$ (72)

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Fair Value (Details Textuals)	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2016 USD ($) location	Jun. 30, 2015 USD ($)	Jun. 30, 2016 USD ($) location	Jun. 30, 2015 USD ($)	Dec. 31, 2015
Fair Value, Option, Quantitative Disclosures [Line Items]
Number of locations | location	2		2
Trading securities realized gain (loss)			$ 10,000,000	$ 1,000,000
Nuclear decommissioning trust fund | DTE Electric
Fair Value, Option, Quantitative Disclosures [Line Items]
Average maturity of debt securities (in years)			7 years		6 years
Accumulated Net Unrealized Investment Gain (Loss)
Fair Value, Option, Quantitative Disclosures [Line Items]
Unrealized losses on available for sale securities	$ 0	$ 0	$ 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	$ 0	$ 0

XML

Financial and Other Derivative Instruments (Fair Value of Derivative Instruments) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Derivative Assets	$ 550	$ 711
Derivative Liabilities	(629)	(705)
Not Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Derivative Assets	550	711
Derivative Liabilities	(629)	(705)
DTE Electric | Not Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Derivative Assets	4	3
Natural Gas
Derivatives, Fair Value [Line Items]
Derivative Assets	298	387
Derivative Liabilities	(375)	(383)
Natural Gas | Not Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Derivative Assets	298	387
Derivative Liabilities	(375)	(383)
Electricity
Derivatives, Fair Value [Line Items]
Derivative Assets	239	307
Derivative Liabilities	(240)	(305)
Electricity | Not Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Derivative Assets	239	307
Derivative Liabilities	(240)	(305)
Other
Derivatives, Fair Value [Line Items]
Derivative Assets	7	5
Derivative Liabilities	(11)	(10)
Other | Not Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Derivative Assets	7	5
Derivative Liabilities	(11)	(10)
Foreign currency exchange contracts
Derivatives, Fair Value [Line Items]
Derivative Assets	6	12
Derivative Liabilities	(3)	(7)
Foreign currency exchange contracts | Not Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Derivative Assets	6	12
Derivative Liabilities	(3)	(7)
Financial transmission rights | DTE Electric | Not Designated as Hedging Instrument
Derivatives, Fair Value [Line Items]
Derivative Assets	4	3
Current derivative asset
Derivatives, Fair Value [Line Items]
Derivative Assets	429	570
Current derivative liability
Derivatives, Fair Value [Line Items]
Derivative Liabilities	(442)	(521)
Noncurrent derivative asset
Derivatives, Fair Value [Line Items]
Derivative Assets	121	141
Noncurrent derivative liability
Derivatives, Fair Value [Line Items]
Derivative Liabilities	$ (187)	$ (184)

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Financial and Other Derivative Instruments (Netting Offsets of Derivative Assets and Liabilities) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Offsetting Assets [Line Items]
Derivative Assets	$ 550	$ 711
Gross Amounts Offset in the Consolidated Statements of Financial Position, Assets	(462)	(528)
Net Amounts of Assets Presented in the Consolidated Statements of Financial Position, Assets	88	183
Derivative Liabilities	(629)	(705)
Gross Amounts Offset in the Consolidated Statements of Financial Position, Liabilities	488	562
Net Amounts of (Liabilities) Presented in the Consolidated Statements of Financial Position, Liabilities	(141)	(143)
Natural Gas
Offsetting Assets [Line Items]
Derivative Assets	298	387
Gross Amounts Offset in the Consolidated Statements of Financial Position, Assets	(248)	(285)
Net Amounts of Assets Presented in the Consolidated Statements of Financial Position, Assets	50	102
Derivative Liabilities	(375)	(383)
Gross Amounts Offset in the Consolidated Statements of Financial Position, Liabilities	263	294
Net Amounts of (Liabilities) Presented in the Consolidated Statements of Financial Position, Liabilities	(112)	(89)
Electricity
Offsetting Assets [Line Items]
Derivative Assets	239	307
Gross Amounts Offset in the Consolidated Statements of Financial Position, Assets	(207)	(232)
Net Amounts of Assets Presented in the Consolidated Statements of Financial Position, Assets	32	75
Derivative Liabilities	(240)	(305)
Gross Amounts Offset in the Consolidated Statements of Financial Position, Liabilities	212	253
Net Amounts of (Liabilities) Presented in the Consolidated Statements of Financial Position, Liabilities	(28)	(52)
Other
Offsetting Assets [Line Items]
Derivative Assets	7	5
Gross Amounts Offset in the Consolidated Statements of Financial Position, Assets	(2)	(2)
Net Amounts of Assets Presented in the Consolidated Statements of Financial Position, Assets	5	3
Derivative Liabilities	(11)	(10)
Gross Amounts Offset in the Consolidated Statements of Financial Position, Liabilities	10	8
Net Amounts of (Liabilities) Presented in the Consolidated Statements of Financial Position, Liabilities	(1)	(2)
Foreign currency exchange contracts
Offsetting Assets [Line Items]
Derivative Assets	6	12
Gross Amounts Offset in the Consolidated Statements of Financial Position, Assets	(5)	(9)
Net Amounts of Assets Presented in the Consolidated Statements of Financial Position, Assets	1	3
Derivative Liabilities	(3)	(7)
Gross Amounts Offset in the Consolidated Statements of Financial Position, Liabilities	3	7
Net Amounts of (Liabilities) Presented in the Consolidated Statements of Financial Position, Liabilities	$ 0	$ 0

XML

Financial and Other Derivative Instruments (Netting Offsets Reconciliation to Balance Sheet) (Details) - USD ($) $ in Millions	Jun. 30, 2016	Dec. 31, 2015
Derivative Assets
Derivative Assets, gross	$ 550	$ 711
Collateral adjustment	(6)	(2)
Derivative assets, current	53	129
Derivative assets, noncurrent	35	54
Derivative Liabilities
Derivative Liabilities	(629)	(705)
Collateral adjustment	32	36
Derivative liabilities, current	(47)	(57)
Derivative liabilities, noncurrent	(94)	(86)
Current derivative asset
Derivative Assets
Derivative Assets, gross	429	570
Counterparty netting	(372)	(441)
Collateral adjustment	(4)	0
Noncurrent derivative asset
Derivative Assets
Derivative Assets, gross	121	141
Counterparty netting	(84)	(85)
Collateral adjustment	(2)	(2)
Current derivative liability
Derivative Liabilities
Derivative Liabilities	(442)	(521)
Counterparty netting	372	441
Collateral adjustment	23	23
Noncurrent derivative liability
Derivative Liabilities
Derivative Liabilities	(187)	(184)
Counterparty netting	84	85
Collateral adjustment	$ 9	$ 13

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Financial and Other Derivative Instruments (Effect of Derivatives not Designated as Hedging Instruments on the Consolidated Statement of Operations) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	$ (19)	$ 25	$ (65)	$ (50)
Natural Gas | Operating Revenues — Non-utility operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	(30)	(4)	(86)	(130)
Natural Gas | Fuel, purchased power, and gas — non-utility
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	(9)	12	32	33
Electricity | Operating Revenues — Non-utility operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	19	15	(5)	46
Other | Operating Revenues — Non-utility operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	0	2	(2)	0
Foreign currency exchange contracts | Operating Revenues — Non-utility operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	$ 1	$ 0	$ (4)	$ 1

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Financial and Other Derivative Instruments (Cumulative Gross Volume of Derivative Contracts Outstanding) (Details)	6 Months Ended
	Jun. 30, 2016 CAD MWh MMBTU gal
Natural Gas (MMBtu)
Derivative [Line Items]
Commodity | MMBTU	1,838,453,487
Electricity (MWh)
Derivative [Line Items]
Commodity | MWh	37,370,289
Oil (Gallons)
Derivative [Line Items]
Oil (Gallons) | gal	18,102,000
Foreign currency exchange contracts (Canadian dollars)
Derivative [Line Items]
Foreign Currency Exchange (Canadian dollars) | CAD	CAD 80,449,368

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Financial and Other Derivative Instruments (Details Textuals) - USD ($)	Jun. 30, 2016	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Letters of credit that could be used to offset net derivative liabilities	$ 5,000,000	$ 7,000,000
Letters of credit received that could be used to offset net derivative assets	1,000,000	2,000,000
Cash collateral posted, net of cash collateral received	40,000,000	37,000,000
Collateral adjustment on derivative assets	6,000,000	2,000,000
Collateral adjustment on derivative liabilities	32,000,000	36,000,000
Cash collateral paid	16,000,000	6,000,000
Cash collateral received	2,000,000	$ 3,000,000
Additional collateral, aggregate fair value	322,000,000
Derivative net liability position aggregate fair value	482,000,000
Collateral already posted fair value	0
Derivative net asset position, fair value	425,000,000
Remaining amount of offsets to derivative net liability positions for hard and soft trigger provisions	$ 57,000,000

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Long-Term Debt (Details)	6 Months Ended
	Jun. 30, 2016 USD ($)
Debt Instrument [Line Items]
Debt redemption amount	$ 313,000,000
Debt Instrument, Face Amount	$ 600,000,000
Mortgages | DTE Electric | May Mortgage Bonds 3.70%
Debt Instrument [Line Items]
Interest Rate	3.70%
Debt Instrument, Face Amount	$ 300,000,000
Mortgages | DTE Electric | March 2016 Mortgage Bonds 7.904%
Debt Instrument [Line Items]
Interest Rate	7.904%
Debt redemption amount	$ 10,000,000
Junior Subordinated Debentures | May Junior Subordinated Debentures 5.375%
Debt Instrument [Line Items]
Interest Rate	5.375%
Debt Instrument, Face Amount	$ 300,000,000
Senior Notes | June Senior Notes 6.35% due 2016
Debt Instrument [Line Items]
Interest Rate	6.35%
Debt redemption amount	$ 300,000,000
Other Long-Term Debt | DTE Energy
Debt Instrument [Line Items]
Debt redemption amount	$ 3,000,000

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Short-Term Credit Arrangements and Borrowings (Details)	Jun. 30, 2016 USD ($)
Availability under combined facilities
Maximum borrowing capacity	$ 2,070,000,000
Amounts outstanding	314,000,000
Net availability	1,756,000,000
DTE Energy
Availability under combined facilities
Maximum borrowing capacity	1,370,000,000
Amounts outstanding	314,000,000
Net availability	1,056,000,000
DTE Electric
Availability under combined facilities
Maximum borrowing capacity	400,000,000
Amounts outstanding	0
Net availability	400,000,000
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 2017
Availability under combined facilities
Maximum borrowing capacity	100,000,000
Letter of Credit | Unsecured letter of credit facility, expiring in February 2017 | DTE Energy
Availability under combined facilities
Maximum borrowing capacity	100,000,000
Letter of Credit | Unsecured letter of credit facility, expiring in February 2017 | DTE Electric
Availability under combined facilities
Maximum borrowing capacity	0
Letter of Credit | Unsecured letter of credit facility, expiring in February 2017 | 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
Revolving Credit Facility | Unsecured revolving credit facility, expiring April 2021
Availability under combined facilities
Maximum borrowing capacity	1,900,000,000
Revolving Credit Facility | Unsecured revolving credit facility, expiring April 2021 | DTE Energy
Availability under combined facilities
Maximum borrowing capacity	1,200,000,000
Revolving Credit Facility | Unsecured revolving credit facility, expiring April 2021 | DTE Electric
Availability under combined facilities
Maximum borrowing capacity	400,000,000
Revolving Credit Facility | Unsecured revolving credit facility, expiring April 2021 | DTE Gas
Availability under combined facilities
Maximum borrowing capacity	300,000,000
Commercial paper issuances
Availability under combined facilities
Amounts outstanding	175,000,000
Commercial paper issuances | DTE Energy
Availability under combined facilities
Amounts outstanding	175,000,000
Commercial paper issuances | DTE Electric
Availability under combined facilities
Amounts outstanding	0
Commercial paper issuances | DTE Gas
Availability under combined facilities
Amounts outstanding	$ 0

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Short-Term Credit Arrangements and Borrowings (Details Textuals)	Jun. 30, 2016 USD ($)	Dec. 31, 2015 USD ($)
Short-term Debt [Line Items]
Other outstanding letters of credit	$ 314,000,000
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	0.50
Other outstanding letters of credit	$ 314,000,000
DTE Electric
Short-term Debt [Line Items]
Ratio of indebtedness to net capital	0.51
Other outstanding letters of credit	$ 0
DTE Gas
Short-term Debt [Line Items]
Ratio of indebtedness to net capital	0.44
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	63,000,000	$ 103,000,000
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

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Commitments and Contingencies (Details Textuals)	1 Months Ended	6 Months Ended	12 Months Ended
	May 31, 2015 USD ($)	Jun. 30, 2016 USD ($) instance facility	Dec. 31, 2015 USD ($)	Dec. 31, 2010 violation	Jul. 31, 2009 facility
Synthetic Fuel
Loss Contingencies [Line Items]
Number of days after expiration of statutes of limitations		90 days
Maximum potential liability		$ 850,000,000
Emissions
Loss Contingencies [Line Items]
Number of days after expiration of statutes of limitations		90 days
Maximum potential liability		$ 323,000,000
Other Guarantees
Loss Contingencies [Line Items]
Maximum potential liability		55,000,000
Performance Surety Bonds
Loss Contingencies [Line Items]
Performance bonds outstanding		54,000,000
DTE Electric
Loss Contingencies [Line Items]
Number of power plants in violation | facility					5
Environmental capital expenditures through prior year end			$ 2,300,000,000
Estimated environmental capital expenditures in current year		$ 45,000,000
Number of permitted engineered coal ash storage facilities owned | facility		3
Time period to comply with coal combustion residual requirements and effluent limitations guidelines		7 years
DTE Gas
Loss Contingencies [Line Items]
Number of former Mgp sites | facility		14
Accrued for remediation		$ 38,000,000	22,000,000
Amortization period (in years)		10 years
EPA Multimedia Inspection | EES Coke
Loss Contingencies [Line Items]
Number of NOVs/FOVs | instance		2
Yolo Solano County Health Department in California and the District Attorney Subpoena
Loss Contingencies [Line Items]
Loss accrual		$ 3,000,000
Riverview Energy Systems, LLC, NOV | Riverview Energy Systems, LLC
Loss Contingencies [Line Items]
Ownership percent	50.00%
Required payment amount	$ 375,000
PADEP NOV
Loss Contingencies [Line Items]
Number of NOVs/FOVs | violation				2
Penalties accrued		190,000	$ 534,000
Coal Combustion Residual Rule | DTE Electric
Loss Contingencies [Line Items]
Estimated costs associated with building new facilities		$ 280,000,000
Clean Up Completed and Site Closed | DTE Gas
Loss Contingencies [Line Items]
Number of former Mgp sites | facility		5
Partial Closure Expected By End of Fiscal Year | DTE Gas
Loss Contingencies [Line Items]
Number of former Mgp sites | facility		3

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Retirement Benefits and Trusteed Assets (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Pension Benefits
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost	$ 23	$ 24	$ 46	$ 49
Interest cost	55	53	109	106
Expected return on plan assets	(78)	(74)	(155)	(148)
Amortization of net actuarial loss	41	52	81	103
Amortization of prior service cost (credit)	0	0	0	0
Net periodic benefit cost (credit)	41	55	81	110
Pension Benefits | DTE Electric
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost	17	18	35	38
Interest cost	42	41	83	81
Expected return on plan assets	(55)	(52)	(110)	(105)
Amortization of net actuarial loss	28	36	57	74
Amortization of prior service cost (credit)	1	1	1	1
Net periodic benefit cost (credit)	33	44	66	89
Other Postretirement Benefits
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost	7	8	13	17
Interest cost	20	21	40	41
Expected return on plan assets	(32)	(32)	(64)	(65)
Amortization of net actuarial loss	8	11	16	22
Amortization of prior service cost (credit)	(29)	(32)	(59)	(63)
Net periodic benefit cost (credit)	(26)	(24)	(54)	(48)
Other Postretirement Benefits | DTE Electric
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost	5	6	10	13
Interest cost	16	15	31	31
Expected return on plan assets	(22)	(22)	(45)	(45)
Amortization of net actuarial loss	5	8	11	16
Amortization of prior service cost (credit)	(22)	(23)	(44)	(47)
Net periodic benefit cost (credit)	$ (18)	$ (16)	$ (37)	$ (32)

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Retirement Benefits and Trusteed Assets (Details Textuals) $ in Millions	6 Months Ended
	Jun. 30, 2016 USD ($)
Pension Benefits
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Maximum contribution amount	$ 175
Pension Benefits | DTE Electric
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Maximum contribution amount	145
Qualified Pension Plan | DTE Gas
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Maximum contribution amount	$ 20

XML

Segment and Related Information (Details Textuals) customer in Millions	Jun. 30, 2016 customer
Segment Reporting [Abstract]
Number of electric utility customers	2.2
Number of gas utility customers	1.2

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Segment and Related Information (Financial Data - Operating Revenues including Inter-segment Revenues) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Segment Reporting, Revenue Reconciling Item [Line Items]
Utility operations	$ 1,435	$ 1,357	$ 3,099	$ 3,198
Non-utility operations	827	911	1,729	2,054
Revenues	2,262	2,268	4,828	5,252
Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Non-utility operations	(174)	(236)	(343)	(437)
Electric | Operating Segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Utility operations	1,215	1,148	2,368	2,351
Electric | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Non-utility operations	(8)	(9)	(17)	(18)
Gas | Operating Segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Utility operations	231	218	751	865
Gas | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Non-utility operations	(3)	0	(3)	(1)
Gas Storage and Pipelines | Operating Segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Non-utility operations	69	57	136	114
Gas Storage and Pipelines | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Non-utility operations	(3)	(5)	(5)	(6)
Power and Industrial Projects | Operating Segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Non-utility operations	444	556	890	1,123
Power and Industrial Projects | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Non-utility operations	(150)	(215)	(298)	(395)
Energy Trading | Operating Segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Non-utility operations	476	524	1,025	1,235
Energy Trading | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Non-utility operations	(8)	(7)	(18)	(16)
Corporate and Other | Operating Segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Non-utility operations	1	1	1	1
Corporate and Other | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Non-utility operations	$ (2)	$ 0	$ (2)	$ (1)

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Segment and Related Information (Financial Data - Net Income (Loss) Attributable to DTE Energy by Segment) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income (Loss) Attributable to DTE Energy Company	$ 152	$ 109	$ 399	$ 382
Electric
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income (Loss) Attributable to DTE Energy Company	135	99	262	235
Gas
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income (Loss) Attributable to DTE Energy Company	13	(7)	100	104
Gas Storage and Pipelines
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income (Loss) Attributable to DTE Energy Company	35	25	65	52
Power and Industrial Projects
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income (Loss) Attributable to DTE Energy Company	15	8	32	41
Energy Trading
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income (Loss) Attributable to DTE Energy Company	(23)	(3)	(30)	(12)
Corporate and Other
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income (Loss) Attributable to DTE Energy Company	$ (23)	$ (13)	$ (30)	$ (38)