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, 2018

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 o DTE 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 o DTE Electric Yes x No o

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

DTE Energy	Large accelerated filer x	Accelerated filer o	Non-accelerated filer o	Smaller reporting company o	Emerging growth 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	Emerging growth company o
			(Do not check if a smaller reporting company)

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

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

DTE Energy Yes o No x DTE Electric Yes o No x

Number of shares of Common Stock outstanding at June 30, 2018:

Registrant	Description	Shares
DTE Energy	Common Stock, without par value	181,772,574
DTE Electric	Common Stock, $10 par value, directly owned by DTE Energy	138,632,324

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

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

THIS PAGE INTENTIONALLY LEFT BLANK

TABLE OF CONTENTS

		Page
	Definitions	1
	Filing Format	3
	Forward-Looking Statements	3
PART I - FINANCIAL INFORMATION
Item 1.	Financial Statements
	DTE Energy Consolidated Financial Statements (Unaudited)	5
	DTE Electric Consolidated Financial Statements (Unaudited)	11
	Combined Notes to Consolidated Financial Statements (Unaudited)	17
	Note 1 — Organization and Basis of Presentation	17
	Note 2 — Significant Accounting Policies	20
	Note 3 — New Accounting Pronouncements	22
	Note 4 — Revenue	24
	Note 5 — Regulatory Matters	28
	Note 6 — Earnings Per Share	30
	Note 7 — Fair Value	30
	Note 8 — Financial and Other Derivative Instruments	38
	Note 9 — Long-Term Debt	43
	Note 10 — Short-Term Credit Arrangements and Borrowings	43
	Note 11 — Commitments and Contingencies	44
	Note 12 — Retirement Benefits and Trusteed Assets	48
	Note 13 — Segment and Related Information	50
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	51
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	68
Item 4.	Controls and Procedures	71
PART II - OTHER INFORMATION
Item 1.	Legal Proceedings	72
Item 1A.	Risk Factors	72
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	72
Item 6.	Exhibits	73
	Signatures	74

DEFINITIONS

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

1

DEFINITIONS

NRC	U.S. Nuclear Regulatory Commission
Production tax credits	Tax credits as authorized under Sections 45K and 45 of the Internal Revenue Code that are designed to stimulate investment in and development of alternate fuel sources. The amount of a production tax credit can vary each year as determined by the Internal Revenue Service.
PSCR	A Power Supply Cost Recovery mechanism authorized by the MPSC that allows DTE Electric to recover through rates its fuel, fuel-related, and purchased power costs.
REC	Renewable Energy Credit
REF	Reduced Emissions Fuel
Registrants	DTE Energy and DTE Electric
Retail access	Michigan legislation provided customers the option of access to alternative suppliers for electricity and natural gas.
SGG	Stonewall Gas Gathering is a midstream natural gas asset located in West Virginia. DTE Energy purchased 55% of SGG in October 2016, and this asset is part of DTE Energy's Gas Storage and Pipelines segment.
SO2	Sulfur Dioxide
TCJA	Tax Cuts and Jobs Act of 2017
TCJA rate reduction reserve	Beginning January 1, 2018, as a result of the change in the corporate tax rate, DTE Electric and DTE Gas have reduced revenue and recorded an offsetting regulatory liability
Topic 606	FASB issued ASU No. 2014-09, Revenue from Contracts with Customers, as amended
TRM	A Transitional Reconciliation Mechanism authorized by the MPSC that allows DTE Electric to recover through rates the deferred net incremental revenue requirement associated with the transition of City of Detroit's Public Lighting Department customers to DTE Electric's distribution system.
VIE	Variable Interest Entity

Units of Measurement
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 to debt securities of DTE Energy. This combined Form 10-Q should be read in its entirety. No one section of this combined Form 10-Q deals with all aspects of the subject matter of this combined Form 10-Q. This combined Form 10-Q should be read in conjunction with the Consolidated Financial Statements and Combined Notes to Consolidated Financial Statements and with Management's Discussion and Analysis included in the combined DTE Energy and DTE Electric 2017 Annual Report on Form 10-K.

FORWARD-LOOKING STATEMENTS

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

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

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

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

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

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

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

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

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

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

• 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;

3

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

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

• the timing and extent of changes in interest rates;

• the level of borrowings;

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

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

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

• unplanned outages;

• employee relations and the impact of collective bargaining agreements;

• the 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.

4

Part I — Financial Information

Item 1. Financial Statements

DTE Energy Company

Consolidated Statements of Operations (Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(In millions, except per share amounts)
Operating Revenues
Utility operations	$	1,514		$	1,423		$	3,254		$	3,141
Non-utility operations	1,645			1,432			3,658			2,950
	3,159			2,855			6,912			6,091
Operating Expenses
Fuel, purchased power, and gas — utility	434			396			987			925
Fuel, purchased power, and gas — non-utility	1,443			1,248			3,216			2,428
Operation and maintenance	583			542			1,117			1,126
Depreciation and amortization	272			249			553			498
Taxes other than income	97			97			208			206
Asset (gains) losses and impairments, net	1			3			(2		)	3
	2,830			2,535			6,079			5,186
Operating Income	329			320			833			905
Other (Income) and Deductions
Interest expense	135			133			270			258
Interest income	(3		)	(2		)	(6		)	(5		)
Non-operating retirement benefits, net	9			17			18			33
Other income	(82		)	(66		)	(163		)	(130		)
Other expenses	15			6			40			13
	74			88			159			169
Income Before Income Taxes	255			232			674			736
Income Tax Expense	19			57			87			167
Net Income	236			175			587			569
Less: Net Income (Loss) Attributable to Noncontrolling Interests	2			(2		)	(8		)	(8		)
Net Income Attributable to DTE Energy Company	$	234		$	177		$	595		$	577
Basic Earnings per Common Share
Net Income Attributable to DTE Energy Company	$	1.29		$	0.99		$	3.29		$	3.21
Diluted Earnings per Common Share
Net Income Attributable to DTE Energy Company	$	1.29		$	0.99		$	3.29		$	3.21
Weighted Average Common Shares Outstanding
Basic	181			179			180			179
Diluted	181			179			180			179
Dividends Declared per Common Share	$	1.77		$	1.65		$	2.65		$	2.48

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,
	2018			2017			2018			2017
	(In millions)
Net Income	$	236		$	175		$	587		$	569
Other comprehensive income (loss), net of tax:
Benefit obligations, net of taxes of $1, $2, $2, and $4, respectively	3			3			5			7
Net unrealized gains on investments during the period, net of taxes of $—, respectively	—			1			—			1
Foreign currency translation	(1		)	—			(1		)	—
Other comprehensive income	2			4			4			8
Comprehensive income	238			179			591			577
Less: Comprehensive income (loss) attributable to noncontrolling interests	2			(2		)	(8		)	(8		)
Comprehensive Income Attributable to DTE Energy Company	$	236		$	181		$	599		$	585

See Combined Notes to Consolidated Financial Statements (Unaudited)

6

DTE Energy Company

Consolidated Statements of Financial Position (Unaudited)

	June 30,			December 31,
	2018			2017
	(In millions)
ASSETS
Current Assets
Cash and cash equivalents	$	63		$	66
Restricted cash	23			23
Accounts receivable (less allowance for doubtful accounts of $70 and $49, respectively)
Customer	1,690			1,758
Other	147			98
Inventories
Fuel and gas	313			399
Materials and supplies	362			380
Derivative assets	78			103
Regulatory assets	57			55
Other	162			199
	2,895			3,081
Investments
Nuclear decommissioning trust funds	1,484			1,492
Investments in equity method investees	1,326			1,073
Other	231			232
	3,041			2,797
Property
Property, plant, and equipment	32,122			31,424
Accumulated depreciation and amortization	(10,883		)	(10,703		)
	21,239			20,721
Other Assets
Goodwill	2,293			2,293
Regulatory assets	3,729			3,723
Intangible assets	862			867
Notes receivable	69			73
Derivative assets	45			51
Prepaid postretirement costs	9			—
Other	148			161
	7,155			7,168
Total Assets	$	34,330		$	33,767

See Combined Notes to Consolidated Financial Statements (Unaudited)

7

DTE Energy Company

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

	June 30,			December 31,
	2018			2017
	(In millions, except shares)
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	1,059		$	1,171
Accrued interest	113			111
Dividends payable	321			158
Short-term borrowings	474			621
Current portion long-term debt, including capital leases	5			109
Derivative liabilities	43			99
Gas inventory equalization	37			—
Regulatory liabilities	39			18
Other	408			525
	2,499			2,812
Long-Term Debt (net of current portion)
Mortgage bonds, notes, and other	11,560			11,039
Junior subordinated debentures	1,145			1,145
Capital lease obligations	—			1
	12,705			12,185
Other Liabilities
Deferred income taxes	1,936			1,888
Regulatory liabilities	3,038			2,875
Asset retirement obligations	2,394			2,320
Unamortized investment tax credit	142			122
Derivative liabilities	64			47
Accrued pension liability	727			924
Accrued postretirement liability	—			61
Nuclear decommissioning	219			220
Other	288			323
	8,808			8,780
Commitments and Contingencies (Notes 5 and 11)
Equity
Common stock, without par value, 400,000,000 shares authorized, and 181,772,574 and 179,386,967 shares issued and outstanding, respectively	4,205			3,989
Retained earnings	5,760			5,643
Accumulated other comprehensive loss	(121		)	(120		)
Total DTE Energy Company Equity	9,844			9,512
Noncontrolling interests	474			478
Total Equity	10,318			9,990
Total Liabilities and Equity	$	34,330		$	33,767

See Combined Notes to Consolidated Financial Statements (Unaudited)

8

DTE Energy Company

Consolidated Statements of Cash Flows (Unaudited)

	Six Months Ended June 30,
	2018			2017
	(In millions)
Operating Activities
Net Income	$	587		$	569
Adjustments to reconcile Net Income to Net cash from operating activities:
Depreciation and amortization	553			498
Nuclear fuel amortization	25			24
Allowance for equity funds used during construction	(13		)	(12		)
Deferred income taxes	80			164
Equity earnings of equity method investees	(53		)	(51		)
Dividends from equity method investees	34			37
Asset (gains) losses and impairments, net	—			3
Changes in assets and liabilities:
Accounts receivable, net	20			49
Inventories	104			32
Prepaid postretirement benefit costs	(9		)	—
Accounts payable	(34		)	23
Gas inventory equalization	37			35
Accrued pension liability	(197		)	(133		)
Accrued postretirement liability	(61		)	—
Derivative assets and liabilities	(8		)	(123		)
Regulatory assets and liabilities	230			216
Other current and noncurrent assets and liabilities	138			(148		)
Net cash from operating activities	1,433			1,183
Investing Activities
Plant and equipment expenditures — utility	(1,027		)	(968		)
Plant and equipment expenditures — non-utility	(130		)	(68		)
Proceeds from sale of nuclear decommissioning trust fund assets	616			705
Investment in nuclear decommissioning trust funds	(613		)	(688		)
Distributions from equity method investees	5			7
Contributions to equity method investees	(233		)	(175		)
Other	2			(61		)
Net cash used for investing activities	(1,380		)	(1,248		)
Financing Activities
Issuance of long-term debt, net of issuance costs	520			495
Redemption of long-term debt	(102		)	(6		)
Short-term borrowings, net	(147		)	(79		)
Issuance of common stock	6			—
Repurchase of common stock	—			(51		)
Dividends on common stock	(309		)	(296		)
REF contributions from noncontrolling interests	22			21
Distributions to noncontrolling interests	(17		)	(20		)
Other	(29		)	(28		)
Net cash from (used for) financing activities	(56		)	36
Net Decrease in Cash, Cash Equivalents, and Restricted Cash	(3		)	(29		)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	89			113
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	86		$	84
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	$	216		$	218

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, 2017	179,387	$	3,989	$	5,643		$	(120	)	$	478		$	9,990
Implementation of ASU 2016-01	—	—		5			(5		)	—			—
Net Income (Loss)	—	—		595			—			(8		)	587
Dividends declared on common stock	—	—		(481		)	—			—			(481		)
Issuance of common stock	160	16		—			—			—			16
Contribution of common stock to pension plan	1,751	175		—			—			—			175
Benefit obligations, net of tax	—	—		—			5			—			5
Foreign currency translation	—	—		—			(1		)	—			(1		)
Stock-based compensation, net contributions from noncontrolling interests, and other	475	25		(2		)	—			4			27
Balance, June 30, 2018	181,773	$	4,205	$	5,760		$	(121	)	$	474		$	10,318

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,
	2018			2017			2018			2017
	(In millions)
Operating Revenues — Utility operations	$	1,276		$	1,218		$	2,481		$	2,393
Operating Expenses
Fuel and purchased power — utility	386			355			725			669
Operation and maintenance	345			336			665			719
Depreciation and amortization	202			180			414			361
Taxes other than income	74			75			155			155
	1,007			946			1,959			1,904
Operating Income	269			272			522			489
Other (Income) and Deductions
Interest expense	69			72			137			138
Other income	(22		)	(17		)	(49		)	(36		)
Other expenses	15			5			40			12
	62			60			128			114
Income Before Income Taxes	207			212			394			375
Income Tax Expense	44			74			91			131
Net Income	$	163		$	138		$	303		$	244

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,
	2018		2017		2018		2017
	(In millions)
Net Income	$	163	$	138	$	303	$	244
Other comprehensive income	—		—		—		—
Comprehensive Income	$	163	$	138	$	303	$	244

See Combined Notes to Consolidated Financial Statements (Unaudited)

12

DTE Electric Company

Consolidated Statements of Financial Position (Unaudited)

	June 30,			December 31,
	2018			2017
	(In millions)
ASSETS
Current Assets
Cash and cash equivalents	$	8		$	15
Accounts receivable (less allowance for doubtful accounts of $38 and $31, respectively)
Customer	849			791
Affiliates	14			20
Other	71			37
Inventories
Fuel	165			190
Materials and supplies	276			275
Regulatory assets	56			50
Other	70			68
	1,509			1,446
Investments
Nuclear decommissioning trust funds	1,484			1,492
Other	35			36
	1,519			1,528
Property
Property, plant, and equipment	23,410			22,972
Accumulated depreciation and amortization	(8,101		)	(7,984		)
	15,309			14,988
Other Assets
Regulatory assets	3,035			3,005
Intangible assets	31			25
Prepaid postretirement costs — affiliates	113			113
Other	115			123
	3,294			3,266
Total Assets	$	21,631		$	21,228

See Combined Notes to Consolidated Financial Statements (Unaudited)

13

DTE Electric Company

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

	June 30,		December 31,
	2018		2017
	(In millions, except shares)
LIABILITIES AND SHAREHOLDER’S EQUITY
Current Liabilities
Accounts payable
Affiliates	$	54	$	52
Other	339		416
Accrued interest	74		72
Accrued vacation	45		41
Current portion long-term debt, including capital leases	2		5
Regulatory liabilities	26		17
Short-term borrowings
Affiliates	75		116
Other	130		238
Other	75		104
	820		1,061
Long-Term Debt (net of current portion)
Mortgage bonds, notes, and other	6,537		6,017
Capital lease obligations	—		1
	6,537		6,018
Other Liabilities
Deferred income taxes	2,146		2,088
Regulatory liabilities	2,266		2,137
Asset retirement obligations	2,196		2,125
Unamortized investment tax credit	140		120
Nuclear decommissioning	219		220
Accrued pension liability — affiliates	629		811
Accrued postretirement liability — affiliates	264		311
Other	76		72
	7,936		7,884
Commitments and Contingencies (Notes 5 and 11)
Shareholder’s Equity
Common stock, $10 par value, 400,000,000 shares authorized, and 138,632,324 shares issued and outstanding	4,306		4,306
Retained earnings	2,032		1,956
Accumulated other comprehensive income	—		3
Total Shareholder’s Equity	6,338		6,265
Total Liabilities and Shareholder’s Equity	$	21,631	$	21,228

See Combined Notes to Consolidated Financial Statements (Unaudited)

14

DTE Electric Company

Consolidated Statements of Cash Flows (Unaudited)

	Six Months Ended June 30,
	2018			2017
	(In millions)
Operating Activities
Net Income	$	303		$	244
Adjustments to reconcile Net Income to Net cash from operating activities:
Depreciation and amortization	414			361
Nuclear fuel amortization	25			24
Allowance for equity funds used during construction	(9		)	(10		)
Deferred income taxes	91			130
Changes in assets and liabilities:
Accounts receivable, net	(86		)	(36		)
Inventories	24			23
Accounts payable	(2		)	(4		)
Accrued pension liability — affiliates	(182		)	(122		)
Accrued postretirement liability — affiliates	(47		)	2
Regulatory assets and liabilities	158			193
Other current and noncurrent assets and liabilities	(4		)	(91		)
Net cash from operating activities	685			714
Investing Activities
Plant and equipment expenditures	(825		)	(737		)
Proceeds from sale of nuclear decommissioning trust fund assets	616			705
Investment in nuclear decommissioning trust funds	(613		)	(688		)
Other	(4		)	—
Net cash used for investing activities	(826		)	(720		)
Financing Activities
Issuance of long-term debt, net of issuance costs	520			—
Short-term borrowings, net — affiliate	(41		)	(39		)
Short-term borrowings, net — other	(108		)	264
Dividends on common stock	(230		)	(216		)
Other	(7		)	(7		)
Net cash from financing activities	134			2
Net Decrease in Cash and Cash Equivalents	(7		)	(4		)
Cash and Cash Equivalents at Beginning of Period	15			13
Cash and Cash Equivalents at End of Period	$	8		$	9
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	$	117		$	133

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, 2017	138,632	$	1,386	$	2,920	$	1,956		$	3		$	6,265
Implementation of ASU 2016-01	—	—		—		3			(3		)	—
Net Income	—	—		—		303			—			303
Dividends declared on common stock	—	—		—		(230		)	—			(230		)
Balance, June 30, 2018	138,632	$	1,386	$	2,920	$	2,032		$	—		$	6,338

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	Revenue	DTE Energy and DTE Electric
Note 5	Regulatory Matters	DTE Energy and DTE Electric
Note 6	Earnings per Share	DTE Energy
Note 7	Fair Value	DTE Energy and DTE Electric
Note 8	Financial and Other Derivative Instruments	DTE Energy and DTE Electric
Note 9	Long-Term Debt	DTE Energy and DTE Electric
Note 10	Short-Term Credit Arrangements and Borrowings	DTE Energy and DTE Electric
Note 11	Commitments and Contingencies	DTE Energy and DTE Electric
Note 12	Retirement Benefits and Trusteed Assets	DTE Energy and DTE Electric
Note 13	Segment and Related Information	DTE Energy

NOTE 1 — ORGANIZATION AND BASIS OF PRESENTATION

Corporate Structure

DTE Energy owns the following businesses:

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

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

• Other businesses involved in 1) services related to the gathering, transportation, and storage of natural gas; 2) power and industrial projects; and 3) energy marketing and trading operations.

DTE Electric and DTE Gas are regulated by the MPSC. Certain activities of DTE Electric and DTE Gas, as well as various other aspects of businesses under DTE Energy, are regulated by the FERC. In addition, the Registrants are regulated by other federal and state regulatory agencies including the NRC, the EPA, the MDEQ, and for DTE Energy, the CFTC.

Basis of Presentation

The Consolidated Financial Statements should be read in conjunction with the Combined Notes to Consolidated Financial Statements included in the combined DTE Energy and DTE Electric 2017 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, 2018.

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 DTE Energy were reclassified to match the current year's Consolidated Financial Statements presentation.

Due to the implementation of ASU 2017-07, amounts previously included in Operation and maintenance were reclassified to Non-operating retirement benefits, net on the Consolidated Statements of Operations. See Note 3 to the Consolidated Financial Statements, "New Accounting Pronouncements."

The Dividends Declared per Common Share for the three and six months ended June 30, 2017 on DTE Energy’s Consolidated Statements of Operations were revised to reflect two dividend declarations in the second quarter of 2017, or $1.65 and $2.48 per share, for the three and six month periods, respectively.  The financial statements previously reflected one dividend declaration of $0.83 and $1.65 per share for the three and six-months period ended June 30, 2017, respectively.  This revision was not material to DTE Energy's Consolidated Financial Statements.

Principles of Consolidation

The Registrants consolidate all majority-owned subsidiaries and investments in entities in which they have controlling influence. Non-majority owned investments are accounted for using the equity method when the Registrants are able to significantly influence the operating policies of the investee. When the Registrants do not influence the operating policies of an investee, the cost method is used. These Consolidated Financial Statements also reflect the Registrants' proportionate interests in certain jointly-owned utility plants. The Registrants eliminate all intercompany balances and transactions.

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

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

DTE Energy owns a 55% interest in SGG, which owns and operates midstream natural gas assets. SGG has contracts through which certain construction risk is designed to pass-through to the customers, with DTE Energy retaining operational and customer default risk. SGG is a VIE with DTE Energy as the primary beneficiary.

The Registrants have variable interests in NEXUS, which include DTE Energy's 50% ownership interest and DTE Electric's transportation services contract. NEXUS is a joint venture which is in the process of constructing a 255-mile pipeline to transport Utica and Marcellus shale gas to Ohio, Michigan, and Ontario market centers. NEXUS is a VIE as it has insufficient equity at risk to finance its activities. The Registrants are not the primary beneficiaries, as the power to direct significant activities is shared between the owners of the equity interests. DTE Energy accounts for its ownership interest in NEXUS under the equity method.

The Registrants hold ownership interests in certain limited partnerships. The limited partnerships include investment funds which support regional development and economic growth, as well as an operational business providing energy-related products. These entities are generally VIEs as a result of certain characteristics of the limited partnership voting rights. The ownership interests are accounted for under the equity method as the Registrants are not the primary beneficiaries.

18

DTE Energy Company — DTE Electric Company

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

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

The maximum risk exposure for consolidated VIEs is reflected on the Registrants' Consolidated Statements of Financial Position and in Note 11 to the Consolidated Financial Statements, "Commitments and Contingencies," related to the REF guarantees and indemnities. For non-consolidated VIEs, the maximum risk exposure of the Registrants is generally limited to their investment, notes receivable, future funding commitments, and amounts which DTE Energy has guaranteed. See Note 11 to the Consolidated Financial Statements, "Commitments and Contingencies," for further discussion of the NEXUS guarantee arrangements.

The following table summarizes the major Consolidated Statements of Financial Position items for consolidated VIEs as of June 30, 2018 and December 31, 2017. 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.

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

	June 30, 2018						December 31, 2017
	SGG(a)		Other		Total		SGG(a)		Other		Total
	(In millions)
ASSETS
Cash and cash equivalents	$	28	$	16	$	44	$	23	$	14	$	37
Restricted cash	—		8		8		—		8		8
Accounts receivable	10		32		42		11		42		53
Inventories	3		67		70		3		114		117
Property, plant, and equipment, net	389		68		457		400		75		475
Goodwill	25		—		25		25		—		25
Intangible assets	564		—		564		572		—		572
Other current and long-term assets	2		1		3		4		—		4
	$	1,021	$	192	$	1,213	$	1,038	$	253	$	1,291
LIABILITIES
Accounts payable and accrued current liabilities	$	5	$	32	$	37	$	26	$	47	$	73
Current portion long-term debt, including capital leases	—		3		3		—		4		4
Mortgage bonds, notes, and other	—		—		—		—		1		1
Other current and long-term liabilities	7		15		22		1		16		17
	$	12	$	50	$	62	$	27	$	68	$	95

_____________________________________

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

19

DTE Energy Company — DTE Electric Company

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

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

	June 30, 2018		December 31, 2017
	(In millions)
Investments in equity method investees	$	1,028	$	811
Notes receivable	$	18	$	17
Future funding commitments	$	416	$	598

NOTE 2 — SIGNIFICANT ACCOUNTING POLICIES

Other Income

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(In millions)
Equity earnings of equity method investees	$	32	$	25	$	53	$	51
Income from REF entities	25		22		48		40
Contract services	12		4		32		8
Allowance for equity funds used during construction	6		5		13		12
Gains from equity securities	1		5		1		13
Other	6		5		16		6
	$	82	$	66	$	163	$	130

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(In millions)
Contract services	$	13	$	5	$	33	$	9
Allowance for equity funds used during construction	4		4		9		10
Gains from equity securities allocated from DTE Energy	1		5		1		13
Other	4		3		6		4
	$	22	$	17	$	49	$	36

Changes in Accumulated Other Comprehensive Income (Loss)

For the three and six months endedJune 30, 2018 and 2017, 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. For further discussion regarding changes in Accumulated other comprehensive income (loss), see Note 3 to the Consolidated Financial Statements, "New Accounting Pronouncements."

20

DTE Energy Company — DTE Electric Company

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

Income Taxes

The 2018 estimated annual effective tax rates for DTE Energy and DTE Electric are 12% and 22%, respectively. These tax rates are affected by estimated annual permanent items, including AFUDC equity, production tax credits, and other flow-through items, as well as discrete items that may occur in any given period, but are not consistent from period to period.

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

	Effective Tax Rate
	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
DTE Energy	7	%	25	%	13	%	23	%
DTE Electric	21	%	35	%	23	%	35	%

The 18%decrease and the 10%decrease in DTE Energy's effective tax rate for the three and six months endedJune 30, 2018 and 2017, respectively, was primarily due to the reduction of the corporate tax rate from 35% to 21%, which became effective in 2018. The decrease in the effective tax rate for the three months ended June 30, 2018 was also impacted by an increase in annual production tax credits of 4%. The decrease in the effective tax rate for the six months ended June 30, 2018 was partially offset by true-up adjustments to the remeasurement of deferred taxes in 2018 of $21 million, which increased the effective tax rate by 3%, and the reduction of excess tax benefits on stock-based compensation of $11 million, which increased the effective tax rate by 1%. For further discussion regarding the true-up adjustments, see Note 3 to the Consolidated Financial Statements, "New Accounting Pronouncements."

The 14%decrease and the 12%decrease in DTE Electric's effective tax rate for the three and six months endedJune 30, 2018 and 2017, respectively, was primarily due to the reduction of the corporate tax rate from 35% to 21%, which became effective in 2018. The decrease in the effective tax rate for the six months ended June 30, 2018 was partially offset by true-up adjustments to the remeasurement of deferred taxes in 2018 of $8 million, which increased the effective tax rate by 2%.

DTE Energy's total amount of unrecognized tax benefits as of June 30, 2018 was $8 million, which if recognized, would favorably impact its effective tax rate. DTE Electric's total amount of unrecognized tax benefits as of June 30, 2018 was $10 million, which if recognized, would favorably impact its effective tax rate. The Registrants do not anticipate any material changes to the unrecognized tax benefits in the next twelve months.

DTE Electric had income tax receivables with DTE Energy of $12 million at June 30, 2018 and December 31, 2017.

Unrecognized Compensation Costs

As of June 30, 2018, DTE Energy had $98 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 1.52 years.

Allocated Stock-Based Compensation

DTE Electric received an allocation of costs from DTE Energy associated with stock-based compensation of $8 million and $10 million for the three months ended June 30, 2018 and 2017, respectively, while such allocation was $17 million and $18 million for the six months ended June 30, 2018 and 2017, respectively.

Cash, Cash Equivalents, and Restricted Cash

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

21

DTE Energy Company — DTE Electric Company

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

The following is a table that provides a reconciliation of DTE Energy's Cash and cash equivalents as well as Restricted cash reported within the Consolidated Statements of Financial Position that sum to the total of the same such amounts shown in the Consolidated Statements of Cash Flows:

	June 30,		December 31,
	2018		2017
	(In millions)
Cash and cash equivalents	$	63	$	66
Restricted cash	23		23
Total cash, cash equivalents, and restricted cash shown in the Consolidated Statements of Cash Flows	$	86	$	89

NOTE 3 — NEW ACCOUNTING PRONOUNCEMENTS

Recently Adopted 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 required 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 to be applied retrospectively. The Registrants adopted the standard effective January 1, 2018, using the modified retrospective approach. Under the modified retrospective approach, the information for periods prior to the adoption date has not been restated and continues to be reported under the accounting standards in effect for those periods. As permitted under the standard, the Registrants have elected to apply the guidance only to those contracts that were not completed at January 1, 2018, and have elected not to restate the impacts of any contract modifications made prior to the earliest period presented.

The adoption of the ASU did not have a significant impact on the Registrants' financial position or results of operations, but required additional disclosures for revenue. See Note 4 to the Consolidated Financial Statements, "Revenue."

In March 2017, the FASB issued ASU No. 2017-07, Compensation — Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. The amendments in this update required that an employer report the service cost component in the same line item or items as other compensation costs arising from services rendered by the pertinent employees during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside of income from operations. The amendments in this update also allow only the service cost component to be eligible for capitalization when applicable. The Registrants adopted the standard effective January 1, 2018. The standard has been applied retrospectively for the presentation of the service cost component and the other components of net periodic pension cost and net periodic postretirement benefit cost in the income statement and prospectively for the capitalization of the service cost component of net periodic pension cost and net periodic postretirement benefit in assets. As permitted by the standard, the Registrants have used benefit cost amounts disclosed for prior periods as the basis for retrospective application in the income statement. As a result of regulatory mechanisms, the impact to the Consolidated Financial Statements was not material for the three and six months endedJune 30, 2018.

In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments — Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities, as amended. The new guidance is intended to improve the recognition and measurement of financial instruments. The guidance 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. The guidance requires equity investments to be generally measured at fair value, with subsequent changes in fair value recognized in net income. The guidance requires entities 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. The Registrants adopted the standard effective January 1, 2018. Upon adoption, DTE Energy and DTE Electric recorded a cumulative-effect adjustment to reclassify $5 million and $3 million of unrealized gains from Accumulated other comprehensive income (loss) to Retained earnings, respectively.

22

DTE Energy Company — DTE Electric Company

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

In March 2018, the FASB issued ASU No. 2018-05, Income Taxes (Topic 740): Amendments to SEC paragraphs pursuant to SEC Staff Accounting Bulletin No. 118. The Amendments in this update add various SEC paragraphs pursuant to the issuance of SEC Staff Accounting Bulletin No. 118, Income Tax Accounting Implications of the Tax Cuts and Jobs Act (SAB 118). SAB 118 directs taxpayers to consider the implications of the TCJA as provisional when it does not have the necessary information available, prepared, or analyzed in reasonable detail to complete its accounting for the change in the tax law. As described in Note 10 to the Consolidated Financial Statements, "Income Taxes," within the combined DTE Energy and DTE Electric 2017 Annual Report on Form 10-K and in accordance with SAB 118, the Registrants recorded amounts that were considered provisional. During the six months endedJune 30, 2018, DTE Energy and DTE Electric recorded true-up adjustments to the remeasurement of deferred taxes of $21 million and $8 million, respectively. The impact of the true-up adjustments was an increase in Income Tax Expense, of which $16 million was attributable to the regulated utilities and offset to Regulatory liabilities.The true-up adjustments were a result of further analysis for items subject to further consideration at December 31, 2017, under SAB 118 and primarily related to timing differences not recoverable from DTE Electric and DTE Gas customers. The Registrants will continue to analyze the amounts throughout 2018, which may result in additional changes.

Recently Issued Pronouncements

In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842), as amended. This guidance requires a lessee to account for leases as finance or operating leases, and disclose key information about leasing arrangements. Both types of leases will result in the lessee recognizing a right-of-use asset and a corresponding lease liability on its balance sheet, with differing methodology for income statement recognition, depending on the lease classification. The Registrants will adopt the standard on January 1, 2019. As originally issued, the standard requires a modified retrospective approach for leases existing or entered into after the beginning of the earliest comparative period in the Consolidated Financial Statements. The Registrants expect to elect the package of practical expedients allowing entities to not reassess whether an agreement is a lease, to carryforward the existing lease classification, and to not reassess initial direct costs associated with existing leases. The Registrants also plan to elect the practical expedient allowing entities to not evaluate land easements under the new guidance at adoption if they were not previously accounted for as leases.

A third-party software tool is being implemented that will assist with the initial adoption and ongoing compliance of the standard. The Registrants are compiling lease contracts and abstracting the required data, as well as evaluating new business processes, internal controls, and accounting policies. In addition, the Registrants are monitoring utility industry implementation issues for purchase power agreements, pipeline laterals, and other industry specific arrangements. While the Registrants expect an increase in assets and liabilities, as well as additional disclosures, they are still assessing the impact of this ASU on their Consolidated Financial Statements.

In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments — Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments. The amendments in this update replace the incurred loss impairment methodology in current generally accepted accounting principles with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates. Entities will apply the new guidance as a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is adopted. The ASU is effective for the Registrants beginning after December 15, 2019, and interim periods therein. Early adoption is permitted. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements.

In February 2018, the FASB issued ASU No. 2018-02, Income Statement — Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income. The amendments in this update allow a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the TCJA. The amendments in this update also require entities to disclose their accounting policy for releasing income tax effects from accumulated other comprehensive income. The ASU is effective for the Registrants for fiscal years beginning after December 15, 2018, and interim periods therein. Early adoption is permitted. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements.

23

DTE Energy Company — DTE Electric Company

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

NOTE 4 — REVENUE

Significant Accounting Policy

Upon the adoption of Topic 606, revenue is measured based upon the consideration specified in a contract with a customer at the time when performance obligations are satisfied. Under Topic 606, a performance obligation is a promise in a contract to transfer a distinct good or service or a series of distinct goods or services to the customer. The Registrants recognize revenue when performance obligations are satisfied by transferring control over a product or service to a customer. The Registrants have determined control to be transferred when the product is delivered or the service is provided to the customer. For the three and six months endedJune 30, 2018, recognition of revenue for the Registrants subsequent to the adoption of Topic 606 is substantially similar in amount and approach to that prior to adoption.

Rates for DTE Electric and DTE Gas include provisions to adjust billings for fluctuations in fuel and purchased power costs, cost of natural gas, and certain other costs. Revenues are adjusted for differences between actual costs subject to reconciliation and the amounts billed in current rates. Under or over recovered revenues related to these cost recovery mechanisms are included in Regulatory assets or liabilities on the Registrants' Consolidated Statements of Financial Position and are recovered or returned to customers through adjustments to the billing factors.

For discussion of derivative contracts, see Note 8 to the Consolidated Financial Statements, "Financial and Other Derivative Instruments."

24

DTE Energy Company — DTE Electric Company

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

Disaggregation of Revenue

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

	Three Months Ended June 30,		Six Months Ended June 30,
	2018		2018
	(In millions)
Electric(a)
Residential	$	584	$	1,170
Commercial	446		875
Industrial	178		354
Other(b)	68		82
Total Electric operating revenues(c)	$	1,276	$	2,481
Gas
Gas sales	$	180	$	637
End User Transportation	49		134
Intermediate Transportation	11		29
Other(d)	15		5
Total Gas operating revenues(e)	$	255	$	805
Other segment operating revenues(f)
Gas Storage and Pipelines	$	122	$	241
Power and Industrial Projects	$	538	$	1,105
Energy Trading	$	1,164	$	2,662

_______________________________________

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

(b) Includes decreases of $38 million and $77 million to revenues related to TCJA rate reduction reserves for the three and six months endedJune 30, 2018, respectively.

(c) Includes $4 million and $9 million of other revenues which are outside the scope of Topic 606 for the three and six months endedJune 30, 2018, respectively.

(d) Includes an increase of $5 million and a decrease of $27 million to revenues related to TCJA rate reduction reserves for the three and six months endedJune 30, 2018, respectively.

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

(f) Includes revenues outside the scope of Topic 606 primarily related to $399 million and $844 million of contracts accounted for as leases at the Power and Industrial Projects segment for the three and six months endedJune 30, 2018, respectively, and $937 million and $2.1 billion related to derivatives at the Energy Trading segment for the three and six months endedJune 30, 2018, respectively.

Nature of Goods and Services

The following is a description of principal activities, separated by reportable segments, from which DTE Energy generates revenue. For more detailed information about reportable segments, see Note 13 to the Consolidated Financial Statements, “Segment and Related Information.”

The Registrants have contracts with customers which may contain more than one performance obligation. When more than one performance obligation exists in a contract, the consideration under the contract is allocated to the performance obligations based on the relative standalone selling price. DTE Energy generally determines standalone selling prices based on the prices charged to customers or the use of the adjusted market assessment approach. The adjusted market assessment approach involves the evaluation of the market in which DTE Energy sells goods or services and estimating the price that a customer in that market would be willing to pay.

Under Topic 606, when a customer simultaneously receives and consumes the product or service provided, revenue is considered to be recognized over time. Alternatively, if it is determined that the criteria for recognition of revenue over time is not met, the revenue is considered to be recognized at a point in time.

25

DTE Energy Company — DTE Electric Company

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

Electric

Electric consists principally of DTE Electric. Electric revenues are primarily comprised of the supply and delivery of electricity, and related capacity. Revenues are primarily associated with cancelable contracts, with the exception of certain long-term contracts with commercial and industrial customers. Revenues, including estimated unbilled amounts, are generally recognized over time based upon volumes delivered or through the passage of time ratably based upon providing a stand-ready service. The Registrants have determined that the above methods represent a faithful depiction of the transfer of control to the customer. Unbilled revenues are typically determined utilizing approved tariff rates and estimated meter volumes. Estimated unbilled amounts recognized in revenue are subject to adjustment in the following reporting period as actual volumes by customer class are known. Revenues are typically subject to tariff rates based upon customer class and type of service, and are billed and received monthly. Tariff rates are determined by the MPSC on a per unit or monthly basis.

Gas

Gas consists principally of DTE Gas. Gas revenues are primarily comprised of the supply and delivery of natural gas, and other services including storage, transportation, and appliance maintenance. Revenues are primarily associated with cancelable contracts with the exception of certain long-term contracts with commercial and industrial customers. Revenues, including estimated unbilled amounts, are generally recognized over time based upon volumes delivered or through the passage of time ratably based upon providing a stand-ready service. DTE Energy has determined that the above methods represent a faithful depiction of the transfer of control to the customer. Unbilled revenues are typically determined using both estimated meter volumes and estimated usage based upon the number of unbilled days and historical temperatures. Estimated unbilled amounts recognized in revenue are subject to adjustment in the following reporting period as actual volumes by customer class and service type are known. Revenues are typically subject to tariff rates or other rates subject to regulatory oversight and are billed and received monthly. Tariff rates are determined by the MPSC on a per unit or monthly basis.

Gas Storage and Pipelines

Gas Storage and Pipelines revenues generally consist of services related to the gathering, transportation, and storage of natural gas. Contracts are primarily long-term in nature. Revenues, including estimated unbilled amounts, are generally recognized over time based upon services provided or through the passage of time ratably based upon providing a stand-ready service. DTE Energy has determined that the above methods represent a faithful depiction of the transfer of control to the customer. Revenues are typically billed and received monthly. Pricing for such revenues may consist of demand rates, commodity rates, transportation rates, and other associated fees. Consideration may consist of both fixed and variable components. Generally, uncertainties in the variable consideration components are resolved and revenues are known at the time of recognition.

Power and Industrial Projects

Power and Industrial Projects revenues consist primarily of contracts accounted for as leases which are outside of the scope of Topic 606. For performance obligations within the scope of Topic 606, the timing of revenue recognition is dependent upon when control over the associated product or service is transferred.

Revenues at Power and Industrial Projects, within the scope of Topic 606, generally consist of sales of blast furnace coke and coke oven gas, electricity, equipment maintenance services, and other energy related products and services. Revenues, including estimated unbilled amounts, for the sale of blast furnace coke are generally recognized at a point in time when the product is delivered, which represents the transfer of control to the customer. Other revenues are generally recognized over time based upon services provided or through the passage of time ratably based upon providing a stand-ready service. DTE Energy has determined that the above methods represent a faithful depiction of the transfer of control to the customer. Market based pricing structures exist in such contracts including adjustments for consumer price or other indices. Consideration may consist of both fixed and variable components. Generally, uncertainties in the variable consideration components are resolved and revenues are known at the time of recognition. Billing terms vary and are generally monthly with payment terms typically within 30 days following billing.

Energy Trading

Energy Trading revenues consist primarily of derivative contracts outside of the scope of Topic 606. For performance obligations within the scope of Topic 606, the timing of revenue recognition is dependent upon when control over the associated product or service is transferred.

26

DTE Energy Company — DTE Electric Company

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

Revenues, including estimated unbilled amounts, within the scope of Topic 606 arising from the sale of natural gas, electricity, power capacity, and other energy related products are generally recognized over time based upon volumes delivered or through the passage of time ratably based upon providing a stand-ready service. DTE Energy has determined that the above methods represent a faithful depiction of the transfer of control to the customer. Revenues are known at the time of recognition. Payment for the aforementioned revenues is generally due from customers in the month following delivery.

Revenues associated with RECs are recognized at a point in time when control of the RECs are transferred to the customer which is deemed to be when the subject RECs are entered for transfer to the customer in the applicable regulatory tracking system. Revenues associated with RECs under a wholesale full requirements power contract are deferred until control has been transferred. The deferred revenues represent a contract liability for which payment has been received and the amounts have been estimated using the adjusted market assessment approach. With the exception of RECs, generally all other performance obligations associated with wholesale full requirements power contracts are satisfied over time in conjunction with the delivery of power. At the time power is delivered, DTE Energy may not have control over the RECs as the RECs are not self-generated and may not yet have been procured resulting in deferred revenues.

Deferred Revenue

The following is a summary of deferred revenue activity:

	DTE Energy
	(In millions)
Beginning Balance, January 1, 2018	$	56
Increases due to cash received or receivable, excluding amounts recognized as revenue during the period	29
Revenue recognized that was included in the deferred revenue balance at the beginning of the period	(18		)
Ending Balance, June 30, 2018	$	67

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

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

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

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

	DTE Energy
	(In millions)
2018	$	27
2019	14
2020	2
2021	4
2022	7
2023 and thereafter	13
	$	67

27

DTE Energy Company — DTE Electric Company

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

Transaction Price Allocated to the Remaining Performance Obligations

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

Such contracts consist of varying types of performance obligations across the segments, including the supply and delivery of energy related products and services. Contracts with variable volumes and/or variable pricing, including those with pricing provisions tied to a consumer price or other index, have also been excluded as the related consideration under the contract is variable at inception of the contract. Contract lengths vary from cancelable to multi-year.

The Registrants expect to recognize revenue for the following amounts related to fixed consideration associated with remaining performance obligations in each of the future periods noted:

	DTE Energy		DTE Electric
	(In millions)
2018	$	102	$	5
2019	251		8
2020	178		—
2021	135		—
2022	106		—
2023 and thereafter	351		—
Total	$	1,123	$	13

Other Matters

DTE Energy has recognized charges of $31 million and $56 million related to expense recognized for estimated uncollectible accounts receivable for the three and six months endedJune 30, 2018, respectively. DTE Electric has recognized charges of $17 million and $31 million related to expense recognized for estimated uncollectible accounts receivable for the three and six months endedJune 30, 2018, respectively.

NOTE 5 — REGULATORY MATTERS

2017 Electric Rate Case Filing

DTE Electric filed a rate case with the MPSC on April 19, 2017 requesting an increase in base rates of $231 million based on a projected twelve-month period ending October 31, 2018. On November 1, 2017, DTE Electric self-implemented a base rate increase of $125 million. On April 18, 2018, the MPSC issued an order approving an annual revenue increase of $65.2 million for service rendered on or after May 1, 2018. The MPSC authorized a return on equity of 10.0%. On June 28, 2018, the MPSC issued an order on a rehearing granting in part and denying in part, petitions for rehearings of DTE Electric and other intervenors. As a result, the approved addition to base rates increased from $65.2 million to $74.4 million. DTE Electric has recorded a refund liability of $25 million, representing the total estimated refund due to customers, inclusive of interest, at June 30, 2018. In August 2018, DTE Electric will file to refund its customers based on their pro rata share of the revenue collected through the self-implementation surcharge in effect from November 1, 2017 to May 1, 2018.

28

DTE Energy Company — DTE Electric Company

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

2018 Electric Rate Case Filing

DTE Electric filed a rate case with the MPSC on July 6, 2018 requesting an increase in base rates of $328 million based on a projected twelve-month period ending April 30, 2020. The requested increase in base rates is primarily due to an increase in net plant resulting from infrastructure investments, depreciation expense, as requested in the 2016 DTE Main Electric Depreciation Case Filing, and reliability improvement projects. The rate filing also requests an increase in return on equity from 10.0% to 10.5% and includes projected changes in sales, operation and maintenance expenses, and working capital. In addition, the rate filing requests an Infrastructure Recovery Mechanism to recover the incremental revenue requirement associated with certain distribution, fossil generation, and nuclear generation capital expenditures through 2022. Finally, as noted in the 2017 Tax Reform section below, DTE Electric addressed Calculation C in this filing. A final MPSC order in this case is expected by May 2019.

Certificate of Necessity

On July 31, 2017, DTE Electric filed a request for authority to build a 1,100 megawatt natural gas fueled combined cycle generation facility at DTE Electric's Belle River Power Plant. DTE Electric requested the MPSC to issue three CONs for the following: (1) power supplied by the proposed project is needed, (2) the size, fuel type, and other design characteristics of the proposed project represent the most reasonable and prudent means of meeting the power need, and (3) the estimated capital costs of $989 million for the proposed project will be recoverable in rates from DTE Electric's customers. The MPSC issued an order on April 27, 2018 approving DTE Electric's request for the three CONs with recoverable amounts through rates up to $951.8 million.

2017 Gas Rate Case Filing

DTE Gas filed a rate case with the MPSC on November 22, 2017 requesting an increase in base rates of $85.1 million based on a projected twelve-month period ending September 30, 2019. The requested increase in base rates is primarily due to an increase in net plant. The rate filing also requests an increase in return on equity from 10.1% to 10.5% and includes projected changes in sales, operations and maintenance expenses, and working capital. On May 24, 2018, DTE Gas reduced its initial requested increase in base rates to $38.1 million, primarily due to the effects of the TCJA on the original request. To mitigate the impact to its customers resulting from ASU No. 2017-07, Compensation — Retirement Benefits (Topic 715), DTE Gas suggested regulatory accounting treatment, consistent with the methodology approved by the MPSC in the 2017 DTE Electric Rate Case order. As such, beginning January 1, 2018, pension and postretirement cost components previously included as capital overhead are being deferred. For further discussion of ASU No. 2017-07, see Note 3 to the Consolidated Financial Statements, "New Accounting Pronouncements." A final MPSC order in this case is expected by September 2018.

2017 Tax Reform

On December 27, 2017, the MPSC issued an order to consider changes in the rates of all Michigan rate-regulated utilities to reflect the effects of the federal TCJA. On January 19, 2018, DTE Electric and DTE Gas filed information with the MPSC regarding the potential change in revenue requirements due to the TCJA effective January 1, 2018, and outlined their recommended method to flow the current and deferred tax benefits of those impacts to ratepayers.

On February 22, 2018, the MPSC issued an order in this case requiring utilities, including DTE Electric and DTE Gas, to follow a 3-step approach of credits and calculations. The first step is to establish Credit A, through contested cases. Credit A is a going-forward tax credit to reflect the reduction of the corporate tax rate from 35% to 21%. DTE Gas submitted its Credit A filing on March 28, 2018, reflecting a reduction in revenues of $38.2 million. The MPSC approved the $38.2 million reduction on May 30, 2018, to be effective July 1, 2018. DTE Electric filed its Credit A application on May 18, 2018, reflecting a reduction in revenues of $157 million. On July 24, 2018, the MPSC issued an order approving a settlement in DTE Electric's Credit A filing reflecting a reduction in revenues of $157 million. Rates reflecting this reduction will be effective August 1, 2018. The second step is to establish Credit B, through contested cases. Credit B is a backward-looking tax credit to reflect the reduction of the corporate rate of 35% to 21%, for the period January 1, 2018 through the date Credit A is established. The Credit B filing is required within sixty days after Credit A is implemented. For Credit B, DTE Electric and DTE Gas have been deferring the impact of the reduction to the corporate tax rate since January 1, 2018. The third step is to perform Calculation C, through contested cases. Calculation C will address all remaining issues relative to the new tax law, which is primarily the remeasurement of deferred taxes and how the amounts deferred as Regulatory liabilities will flow to ratepayers. DTE Gas is required to file Calculation C no later than October 1, 2018. DTE Electric addressed Calculation C in its general rate case filed July 6, 2018.

29

DTE Energy Company — DTE Electric Company

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

NOTE 6 — EARNINGS PER SHARE

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

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(In millions, except per share amounts)
Basic Earnings per Share
Net Income Attributable to DTE Energy Company	$	234	$	177	$	595	$	577
Less: Allocation of earnings to net restricted stock awards	—		—		1		1
Net income available to common shareholders — basic	$	234	$	177	$	594	$	576
Average number of common shares outstanding — basic	181		179		180		179
Basic Earnings per Common Share	$	1.29	$	0.99	$	3.29	$	3.21
Diluted Earnings per Share
Net Income Attributable to DTE Energy Company	$	234	$	177	$	595	$	577
Less: Allocation of earnings to net restricted stock awards	—		—		1		1
Net income available to common shareholders — diluted	$	234	$	177	$	594	$	576
Average number of common shares outstanding — diluted	181		179		180		179
Diluted Earnings per Common Share(a)	$	1.29	$	0.99	$	3.29	$	3.21

_______________________________________

(a) The 2016 Equity Units excluded from the calculation of diluted EPS were approximately 6.6 million and 6.3 million for the three months ended June 30, 2018 and 2017, respectively, and 6.6 million for the six months endedJune 30, 2018 and 2017, as the dilutive stock price threshold was not met.

NOTE 7 — FAIR VALUE

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable inputs. The Registrants make certain assumptions they believe that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. Credit risk of the Registrants and their counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at June 30, 2018 and December 31, 2017. The Registrants believe they use valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.

30

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.

31

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:

	June 30, 2018																	December 31, 2017
	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)	$	16		$	3		$	—		$	—	$	—		$	19		$	16		$	3		$	—		$	—	$	—		$	19
Nuclear decommissioning trusts
Equity securities	938			—			—			—		—			938			978			—			—			—		—			978
Fixed income securities	6			521			—			—		—			527			18			477			—			—		—			495
Private equity securities	—			—			—			10		—			10			—			—			—			5		—			5
Cash equivalents	9			—			—			—		—			9			14			—			—			—		—			14
Other investments(d)
Equity securities	120			—			—			—		—			120			118			—			—			—		—			118
Fixed income securities	69			—			—			—		—			69			72			—			—			—		—			72
Cash equivalents	4			—			—			—		—			4			4			—			—			—		—			4
Derivative assets
Commodity contracts
Natural gas	51			80			59			—		(119		)	71			148			112			97			—		(256		)	101
Electricity	—			159			22			—		(146		)	35			—			243			42			—		(241		)	44
Other	—			—			15			—		—			15			—			—			9			—		—			9
Foreign currency exchange contracts	—			2			—			—		—			2			—			1			—			—		(1		)	—
Total derivative assets	51			241			96			—		(265		)	123			148			356			148			—		(498		)	154
Total	$	1,213		$	765		$	96		$	10	$	(265	)	$	1,819		$	1,368		$	836		$	148		$	5	$	(498	)	$	1,859
Liabilities
Derivative liabilities
Commodity contracts
Natural gas	$	(53	)	$	(55	)	$	(84	)	$	—	$	119		$	(73	)	$	(141	)	$	(111	)	$	(126	)	$	—	$	263		$	(115	)
Electricity	(1		)	(144		)	(35		)	—		146			(34		)	—			(245		)	(30		)	—		246			(29		)
Other	—			—			—			—		—			—			—			—			(1		)	—		1			—
Foreign currency exchange contracts	—			—			—			—		—			—			—			(3		)	—			—		1			(2		)
Total derivative liabilities	(54		)	(199		)	(119		)	—		265			(107		)	(141		)	(359		)	(157		)	—		511			(146		)
Total	$	(54	)	$	(199	)	$	(119	)	$	—	$	265		$	(107	)	$	(141	)	$	(359	)	$	(157	)	$	—	$	511		$	(146	)
Net Assets (Liabilities) at end of period	$	1,159		$	566		$	(23	)	$	10	$	—		$	1,712		$	1,227		$	477		$	(9	)	$	5	$	13		$	1,713
Assets
Current	$	67		$	181		$	62		$	—	$	(213	)	$	97		$	157		$	298		$	104		$	—	$	(437	)	$	122
Noncurrent	1,146			584			34			10		(52		)	1,722			1,211			538			44			5		(61		)	1,737
Total Assets	$	1,213		$	765		$	96		$	10	$	(265	)	$	1,819		$	1,368		$	836		$	148		$	5	$	(498	)	$	1,859
Liabilities
Current	$	(47	)	$	(158	)	$	(51	)	$	—	$	213		$	(43	)	$	(137	)	$	(313	)	$	(108	)	$	—	$	459		$	(99	)
Noncurrent	(7		)	(41		)	(68		)	—		52			(64		)	(4		)	(46		)	(49		)	—		52			(47		)
Total Liabilities	$	(54	)	$	(199	)	$	(119	)	$	—	$	265		$	(107	)	$	(141	)	$	(359	)	$	(157	)	$	—	$	511		$	(146	)
Net Assets (Liabilities) at end of period	$	1,159		$	566		$	(23	)	$	10	$	—		$	1,712		$	1,227		$	477		$	(9	)	$	5	$	13		$	1,713

_______________________________________

(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, 2018, equity securities of $19 million consisted of $8 million and $11 million of cash equivalents included in Restricted cash and Other investments on DTE Energy's Consolidated Statements of Financial Position, respectively. At December 31, 2017, equity securities of $19 million consisted of $8 million and $11 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.

32

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, 2018										December 31, 2017
	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)	$	8	$	3	$	—	$	—	$	11	$	8	$	3	$	—	$	—	$	11
Nuclear decommissioning trusts
Equity securities	938		—		—		—		938		978		—		—		—		978
Fixed income securities	6		521		—		—		527		18		477		—		—		495
Private equity securities	—		—				10		10		—		—		—		5		5
Cash equivalents	9		—		—		—		9		14		—		—		—		14
Other investments
Equity securities	11		—		—		—		11		11		—		—		—		11
Derivative assets — FTRs	—		—		15		—		15		—		—		9		—		9
Total	$	972	$	524	$	15	$	10	$	1,521	$	1,029	$	480	$	9	$	5	$	1,523
Assets
Current	$	8	$	3	$	15	$	—	$	26	$	8	$	3	$	9	$	—	$	20
Noncurrent	964		521		—		10		1,495		1,021		477		—		5		1,503
Total Assets	$	972	$	524	$	15	$	10	$	1,521	$	1,029	$	480	$	9	$	5	$	1,523

_______________________________________

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

(b) At June 30, 2018, equity securities of $11 million consisted of cash equivalents included in Other investments on DTE Electric's Consolidated Statements of Financial Position. At December 31, 2017, equity securities of $11 million consisted of cash equivalents included in Other investments on DTE Electric's Consolidated Statements of Financial Position.

Cash Equivalents

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

Nuclear Decommissioning Trusts and Other Investments

The nuclear decommissioning trusts and other investments hold debt and equity securities directly and indirectly through institutional mutual funds and commingled funds. Other assets such as private market investments are used to enhance long-term returns while improving portfolio diversification. All pricing for investments in this category are classified as NAV assets. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. Non-exchange-traded fixed income securities are valued based upon quotations available from brokers or pricing services. The institutional mutual funds hold exchange-traded equity or debt securities (exchange and non-exchange traded) and are valued based on publicly available NAVs. A primary price source is identified by asset type, class, or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustee determines that another price source is considered 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.

33

DTE Energy Company — DTE Electric Company

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

Derivative Assets and Liabilities

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

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

	Three Months Ended June 30, 2018												Three Months Ended June 30, 2017
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of March 31	$	(10	)	$	(13	)	$	4		$	(19	)	$	(15	)	$	(6	)	$	(2	)	$	(23	)
Transfers into Level 3 from Level 2	—			—			—			—			—			—			—			—
Transfers from Level 3 into Level 2	—			—			—			—			—			—			—			—
Total gains (losses)
Included in earnings	(28		)	18			1			(9		)	(6		)	21			—			15
Recorded in Regulatory liabilities	—			—			15			15			—			—			11			11
Purchases, issuances, and settlements
Settlements	13			(18		)	(5		)	(10		)	4			(9		)	(4		)	(9		)
Net Assets (Liabilities) as of June 30	$	(25	)	$	(13	)	$	15		$	(23	)	$	(17	)	$	6		$	5		$	(6	)
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, 2018 and 2017 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	$	(20	)	$	4		$	(2	)	$	(18	)	$	(20	)	$	20		$	—		$	—

34

DTE Energy Company — DTE Electric Company

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

	Six Months Ended June 30, 2018												Six Months Ended June 30, 2017
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of December 31	$	(29	)	$	12		$	8		$	(9	)	$	(96	)	$	9		$	(1	)	$	(88	)
Transfers into Level 3 from Level 2	—			—			—			$	—		—			—			—			—
Transfers from Level 3 into Level 2	(3		)	—			—			(3		)	—			—			—			—
Total gains (losses)
Included in earnings	(98		)	4			1			(93		)	46			11			1			58
Recorded in Regulatory liabilities	—			—			15			15			—			—			13			13
Purchases, issuances, and settlements
Settlements	105			(29		)	(9		)	67			33			(14		)	(8		)	11
Net Assets (Liabilities) as of June 30	$	(25	)	$	(13	)	$	15		$	(23	)	$	(17	)	$	6		$	5		$	(6	)
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, 2018 and 2017 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	$	(78	)	$	(6	)	$	(2	)	$	(86	)	$	16		$	17		$	(1	)	$	32

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

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(In millions)
Net Assets as of beginning of period	$	5		$	1		$	9		$	2
Change in fair value recorded in Regulatory liabilities	15			11			15			13
Purchases, issuances, and settlements
Settlements	(5		)	(4		)	(9		)	(7		)
Net Assets as of June 30	$	15		$	8		$	15		$	8
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, 2018 and 2017 and reflected in DTE Electric's Consolidated Statements of Financial Position	$	15		$	8		$	15		$	8

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, 2018 and 2017, and there were no transfers from or into Level 3 for DTE Electric during the same periods.

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

	June 30, 2018
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	59	$	(84	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.28	)	—	$	4.30	/MMBtu	$	(0.13	)/MMBtu
Electricity	$	22	$	(35	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(7	)	—	$	7	/MWh	$	—

35

DTE Energy Company — DTE Electric Company

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

	December 31, 2017
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	97	$	(126	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.10	)	—	$	9.75	/MMBtu	$	(0.03	)/MMBtu
Electricity	$	42	$	(30	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(5	)	—	$	15	/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 following table presents the carrying amount and fair value of financial instruments for DTE Energy:

	June 30, 2018								December 31, 2017
	Carrying		Fair Value						Carrying		Fair Value
	Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3
	(In millions)
Notes receivable(a), excluding capital leases	$	37	$	—	$	—	$	37	$	38	$	—	$	—	$	38
Dividends payable	$	321	$	321	$	—	$	—	$	158	$	158	$	—	$	—
Short-term borrowings	$	474	$	—	$	474	$	—	$	621	$	—	$	621	$	—
Notes payable — Other(b), excluding capital leases	$	11	$	—	$	—	$	11	$	12	$	—	$	—	$	12
Long-term debt(c)	$	12,708	$	1,889	$	10,092	$	1,122	$	12,288	$	1,939	$	10,571	$	764

_______________________________________

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

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

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

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

	June 30, 2018								December 31, 2017
	Carrying		Fair Value						Carrying		Fair Value
	Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3
	(In millions)
Short-term borrowings — affiliates	$	75	$	—	$	—	$	75	$	116	$	—	$	—	$	116
Short-term borrowings — other	$	130	$	—	$	130	$	—	$	238	$	—	$	238	$	—
Notes payable — Other(b), excluding capital leases	$	2	$	—	$	—	$	2	$	2	$	—	$	—	$	2
Long-term debt(c)	$	6,537	$	—	$	6,305	$	495	$	6,017	$	—	$	6,441	$	171

_______________________________________

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

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

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

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

36

DTE Energy Company — DTE Electric Company

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

Nuclear Decommissioning Trust Funds

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

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

	June 30, 2018		December 31, 2017
	(In millions)
Fermi 2	$	1,467	$	1,475
Fermi 1	3		3
Low-level radioactive waste	14		14
	$	1,484	$	1,492

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,
	2018			2017			2018			2017
	(In millions)
Realized gains	$	19		$	26		$	42		$	49
Realized losses	$	(6	)	$	(8	)	$	(15	)	$	(16	)
Proceeds from sale of securities	$	280		$	311		$	616		$	705

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

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

	June 30, 2018							December 31, 2017
	Fair Value		Unrealized Gains		Unrealized Losses			Fair Value		Unrealized Gains		Unrealized Losses
	(In millions)
Equity securities	$	938	$	300	$	(43	)	$	978	$	320	$	(32	)
Fixed income securities	527		7		(8		)	495		13		(3		)
Private equity securities	10		—		—			5		—		—
Cash equivalents	9		—		—			14		—		—
	$	1,484	$	307	$	(51	)	$	1,492	$	333	$	(35	)

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

	June 30, 2018
	(In millions)
Due within one year	$	24
Due after one through five years	103
Due after five through ten years	113
Due after ten years	287
	$	527

37

DTE Energy Company — DTE Electric Company

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

Other Securities

At June 30, 2018 and December 31, 2017, the Registrants' securities, included in Other investments on the Consolidated Statements of Financial Position, were comprised primarily of money market and equity securities. For the three months ended June 30, 2018 and 2017, gains related to equity securities were $1 million and $5 million, respectively, for the Registrants. For the six months ended June 30, 2018 and 2017, losses related to equity securities were $1 million and gains related to equity securities were $13 million, respectively, for the Registrants. Gains or losses related to the Rabbi Trust assets are allocated from DTE Energy to DTE Electric.

NOTE 8 — FINANCIAL AND OTHER DERIVATIVE INSTRUMENTS

The Registrants recognize all derivatives at their fair value as Derivative assets or liabilities on their respective Consolidated Statements of Financial Position unless they qualify for certain scope exceptions, including the normal purchases and normal sales exception. Further, derivatives that qualify and are designated for hedge accounting are classified as either hedges of a forecasted transaction or the variability of cash flows to be received or paid related to a recognized asset or liability (cash flow hedge); or as hedges of the fair value of a recognized asset or liability or of an unrecognized firm commitment (fair value hedge). For cash flow hedges, the portion of the derivative gain or loss that is effective in offsetting the change in the value of the underlying exposure is deferred in Accumulated other comprehensive income (loss) and later reclassified into earnings when the underlying transaction occurs. Gains or losses from the ineffective portion of cash flow hedges are recognized in earnings immediately. For fair value hedges, changes in fair values for the derivative and hedged item are recognized in earnings each period. For derivatives that do not qualify or are not designated for hedge accounting, changes in fair value are recognized in earnings each period.

The Registrants’ primary market risk exposure is associated with commodity prices, credit, and interest rates. The Registrants have risk management policies to monitor and manage market risks. The Registrants use derivative instruments to manage some of the exposure. DTE Energy uses derivative instruments for trading purposes in its Energy Trading segment. Contracts classified as derivative instruments include electricity, natural gas, oil, certain coal forwards, futures, options, swaps, and foreign currency exchange contracts. Items not classified as derivatives include natural gas inventory, pipeline transportation contracts, renewable energy credits, and natural gas storage assets.

DTE Electric — DTE Electric generates, purchases, distributes, and sells electricity. DTE Electric uses forward 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 2021. Substantially all of these contracts meet the normal purchases and normal sales exception and are therefore accounted for under the accrual method. DTE Gas may also sell forward transportation and storage capacity contracts. Forward transportation and storage contracts are generally not derivatives and are therefore accounted for under the accrual method.

Gas Storage and Pipelines — This segment is primarily engaged in services related to the gathering, transportation, and storage of natural gas. Primarily fixed-priced contracts are used in the marketing and management of transportation and storage services. Generally, these contracts are not derivatives and are therefore accounted for under the accrual method.

Power and Industrial Projects — This segment manages and operates energy and pulverized coal projects, a coke battery, reduced emissions fuel projects, landfill gas recovery, and power generation assets. Primarily fixed-price contracts are used in the marketing and management of the segment assets. These contracts are generally not derivatives and are therefore accounted for under the accrual method.

Energy Trading — Commodity Price Risk — Energy Trading markets and trades electricity, natural gas physical products, and energy financial instruments, and provides energy and asset management services utilizing energy commodity derivative instruments. Forwards, futures, options, and swap agreements are used to manage exposure to the risk of market price and volume fluctuations in its operations. These derivatives are accounted for by recording changes in fair value to earnings unless hedge accounting criteria are met.

38

DTE Energy Company — DTE Electric Company

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

Energy Trading — Foreign Currency Exchange Risk — Energy Trading has foreign currency exchange forward contracts to economically hedge fixed Canadian dollar commitments existing under natural gas and power purchase and sale contracts and natural gas transportation contracts. Energy Trading enters into these contracts to mitigate price volatility with respect to fluctuations of the Canadian dollar relative to the U.S. dollar. These derivatives are accounted for by recording changes in fair value to earnings unless hedge accounting criteria are met.

Corporate and Other — Interest Rate Risk — DTE Energy may use interest rate swaps, treasury locks, and other derivatives to hedge the risk associated with interest rate market volatility.

Credit Risk — DTE Energy maintains credit policies that significantly minimize overall credit risk. These policies include an evaluation of potential customers’ and counterparties’ financial condition, including the viability of underlying productive assets, credit rating, collateral requirements, or other credit enhancements such as letters of credit or guarantees. DTE Energy generally uses standardized agreements that allow the netting of positive and negative transactions associated with a single counterparty. DTE Energy maintains a provision for credit losses based on factors surrounding the credit risk of its customers, historical trends, and other information. Based on DTE Energy's credit policies and its June 30, 2018 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.

39

DTE Energy Company — DTE Electric Company

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

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

	June 30, 2018					December 31, 2017
	Derivative Assets		Derivative Liabilities			Derivative Assets		Derivative Liabilities
	(In millions)
Derivatives not designated as hedging instruments
Commodity contracts
Natural gas	$	190	$	(192	)	$	357	$	(378	)
Electricity	181		(180		)	285		(275		)
Other	15		—			9		(1		)
Foreign currency exchange contracts	2		—			1		(3		)
Total derivatives not designated as hedging instruments	$	388	$	(372	)	$	652	$	(657	)
Current	$	291	$	(256	)	$	540	$	(558	)
Noncurrent	97		(116		)	112		(99		)
Total derivatives	$	388	$	(372	)	$	652	$	(657	)

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

	June 30, 2018		December 31, 2017
	(In millions)
FTRs — Other current assets	$	15	$	9
Total derivatives not designated as hedging instruments	$	15	$	9

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 $1 million and $4 million outstanding at June 30, 2018 and December 31, 2017, 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 $6 million and $4 million at June 30, 2018 and December 31, 2017, 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.

For DTE Energy, the total cash collateral posted, net of cash collateral received, was $19 million and $28 million as of June 30, 2018 and December 31, 2017, respectively. DTE Energy had no cash collateral related to unrealized positions to net against Derivative assets and liabilities as of June 30, 2018. DTE Energy had $9 million of cash collateral related to unrealized positions to net against Derivative assets while Derivative liabilities are shown net of cash collateral of $22 million as of December 31, 2017. DTE Energy recorded cash collateral paid of $24 million and cash collateral received of $5 million not related to unrealized derivative positions as of June 30, 2018. DTE Energy recorded cash collateral paid of $18 million and cash collateral received of $3 million not related to unrealized derivative positions as of December 31, 2017. These amounts are included in Accounts receivable and Accounts payable and are recorded net by counterparty.

40

DTE Energy Company — DTE Electric Company

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

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

	June 30, 2018									December 31, 2017
	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	$	190		$	(119	)	$	71		$	357		$	(256	)	$	101
Electricity	181			(146		)	35			285			(241		)	44
Other	15			—			15			9			—			9
Foreign currency exchange contracts	2			—			2			1			(1		)	—
Total derivative assets	$	388		$	(265	)	$	123		$	652		$	(498	)	$	154
Derivative liabilities
Commodity contracts
Natural gas	$	(192	)	$	119		$	(73	)	$	(378	)	$	263		$	(115	)
Electricity	(180		)	146			(34		)	(275		)	246			(29		)
Other	—			—			—			(1		)	1			—
Foreign currency exchange contracts	—			—			—			(3		)	1			(2		)
Total derivative liabilities	$	(372	)	$	265		$	(107	)	$	(657	)	$	511		$	(146	)

The following table presents the netting offsets of Derivative assets and liabilities showing the reconciliation of derivative instruments to DTE Energy's Consolidated Statements of Financial Position:

	June 30, 2018												December 31, 2017
	Derivative Assets						Derivative Liabilities						Derivative Assets						Derivative Liabilities
	Current			Noncurrent			Current			Noncurrent			Current			Noncurrent			Current			Noncurrent
	(In millions)
Total fair value of derivatives	$	291		$	97		$	(256	)	$	(116	)	$	540		$	112		$	(558	)	$	(99	)
Counterparty netting	(213		)	(52		)	213			52			(437		)	(52		)	437			52
Collateral adjustment	—			—			—			—			—			(9		)	22			—
Total derivatives as reported	$	78		$	45		$	(43	)	$	(64	)	$	103		$	51		$	(99	)	$	(47	)

41

DTE Energy Company — DTE Electric Company

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

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

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,
		2018			2017			2018			2017
		(In millions)
Commodity contracts
Natural gas	Operating Revenues — Non-utility operations	$	(48	)	$	20		$	(158	)	$	77
Natural gas	Fuel, purchased power, and gas — non-utility	16			(15		)	68			46
Electricity	Operating Revenues — Non-utility operations	28			13			11			6
Other	Operating Revenues — Non-utility operations	2			(1		)	1			(1		)
Foreign currency exchange contracts	Operating Revenues — Non-utility operations	2			(1		)	4			(1		)
Total		$	—		$	16		$	(74	)	$	127

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, 2018:

Commodity	Number of Units
Natural gas (MMBtu)	1,908,431,324
Electricity (MWh)	39,463,885
Foreign currency exchange (Canadian dollars)	101,077,223

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, 2018, 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 $508 million.

As of June 30, 2018, DTE Energy had $283 million of derivatives in net liability positions, for which hard triggers exist. There is nocollateral that has been posted against such liabilities, including cash and letters of credit. Associated derivative net asset positions for which contractual offset exists were $247 million. The net remaining amount of $36 million is derived from the $508 millionnoted above.

42

DTE Energy Company — DTE Electric Company

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

NOTE 9 — LONG-TERM DEBT

Debt Issuances

In 2018, the following debt was issued:

Company	Month	Type	Interest Rate	Maturity Date	Amount
					(In millions)
DTE Electric	May	Mortgage Bonds(a)	4.05%	2048	$	525
					$	525

_______________________________________

(a) Bonds were issued as Green Bonds and the proceeds will be used to finance expenditures for solar and wind energy, payments under power purchase agreements for solar and wind energy, and energy optimization programs.

Debt Redemptions

In 2018, the following debt was redeemed:

Company	Month	Type	Interest Rate	Maturity Date	Amount
					(In millions)
DTE Gas	April	Senior Notes	6.04%	2018	$	100
DTE Energy	Various	Other Long-Term Debt	Various	2018	2
					$	102

In June 2018, DTE Gas agreed to issue $195 million of 3.81% First Mortgage Bonds due 2028 and $125 million of 4.14% First Mortgage Bonds due 2048 to a group of institutional investors in a private placement transaction. These bonds are expected to close and fund in August 2018. Proceeds will be used for the repayment of short-term borrowings and for general corporate purposes.

NOTE 10 — SHORT-TERM CREDIT ARRANGEMENTS AND BORROWINGS

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

The agreements require DTE Energy, DTE Electric, and DTE Gas to maintain a total funded debt to capitalization ratio of no more than 0.65 to 1. In the agreements, “total funded debt” means all indebtedness of each respective company and their consolidated subsidiaries, including capital lease obligations, hedge agreements, and guarantees of third parties’ debt, but excluding contingent obligations, nonrecourse and junior subordinated debt, and certain equity-linked securities and, except for calculations at the end of the second quarter, certain DTE Gas short-term debt. “Capitalization” means the sum of (a) total funded debt plus (b) “consolidated net worth,” which is equal to consolidated total equity of each respective company and their consolidated subsidiaries (excluding pension effects under certain FASB statements), as determined in accordance with accounting principles generally accepted in the United States of America. At June 30, 2018, the total funded debt to total capitalization ratios for DTE Energy, DTE Electric, and DTE Gas were 0.54 to 1, 0.51 to 1, and 0.45 to 1, respectively, and were in compliance with this financial covenant.

43

DTE Energy Company — DTE Electric Company

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

The availability under the facilities in place at June 30, 2018 is shown in the following table:

	DTE Energy		DTE Electric		DTE Gas		Total
	(In millions)
Unsecured letter of credit facility, expiring in February 2019	$	150	$	—	$	—	$	150
Unsecured letter of credit facility, expiring in September 2019	70		—		—		70
Unsecured revolving credit facility, expiring April 2022	1,200		400		300		1,900
	1,420		400		300		2,120
Amounts outstanding at June 30, 2018
Commercial paper issuances	177		130		167		474
Letters of credit	147		—		—		147
	324		130		167		621
Net availability at June 30, 2018	$	1,096	$	270	$	133	$	1,499

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

In conjunction with maintaining certain exchange traded risk management positions, DTE Energy may be required to post collateral with its clearing agent. DTE Energy has a demand financing agreement for up to $100 million with its clearing agent. The agreement, as amended, also allows for up to $50 million of additional margin financing provided that DTE Energy posts a letter of credit for the incremental amount and allows the right of setoff with posted collateral. At June 30, 2018, the capacity under this facility was $125 million. The amount outstanding under this agreement was $30 million and $56 million at June 30, 2018 and December 31, 2017, respectively, and was fully offset by the posted collateral.

NOTE 11 — COMMITMENTS AND CONTINGENCIES

Environmental

DTE Electric

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

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

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

44

DTE Energy Company — DTE Electric Company

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

In August 2010, the U.S. Department of Justice, at the request of the EPA, brought a civil suit in the U.S. District Court for the Eastern District of Michigan against DTE Energy and DTE Electric, related to the June 2010 NOV/FOV and the outage work performed at Unit 2 of the Monroe Power Plant. In August 2011, the U.S. District Court judge granted DTE Energy's motion for summary judgment in the civil case, dismissing the case and entering judgment in favor of DTE Energy and DTE Electric. In October 2011, the EPA filed a Notice of Appeal to the Court of Appeals for the Sixth Circuit. In March 2013, the Court of Appeals remanded the case to the U.S. District Court for review of the procedural component of the New Source Review notification requirements. In September 2013, the EPA filed a motion seeking leave to amend their complaint regarding the June 2010 NOV/FOV adding additional claims related to outage work performed at the Trenton Channel and Belle River Power Plants as well as additional claims related to work performed at the Monroe Power Plant. In March 2014, the U.S. District Court judge again granted DTE Energy's motion for summary judgment dismissing the civil case related to Monroe Unit 2. In April 2014, the U.S. District Court judge granted motions filed by the EPA and the Sierra Club to amend their New Source Review complaint adding additional claims for Monroe Units 1, 2, and 3, Belle River Units 1 and 2, and Trenton Channel Unit 9. In October 2014, the EPA and the U.S. Department of Justice filed a notice of appeal of the U.S. District Court judge's dismissal of the Monroe Unit 2 case. The amended New Source Review claims were all stayed pending resolution of the appeal by the Court of Appeals for the Sixth Circuit. On January 10, 2017, a divided panel of the Court reversed the decision of the U.S. District Court. On May 8, 2017, DTE Energy and DTE Electric filed a motion to stay the mandate pending filing of a petition for writ of certiorari with the U.S. Supreme Court. The Sixth Circuit granted the motion on May 16, 2017, staying the claims in the U.S. District Court until the U.S. Supreme Court disposes of the case. DTE Electric and DTE Energy filed a petition for writ of certiorari on July 31, 2017. On December 11, 2017, the U.S. Supreme Court denied certiorari. As a result of the Supreme Court electing not to review the matter, the case was sent back to the U.S. District Court for further proceedings and on June 14, 2018 the case was stayed for 180 days pending settlement negotiations. The proceedings at the District Court are currently stayed while the parties discuss potential resolution of the matter.

The Registrants believe that the plants and generating units identified by the EPA and the Sierra Club have complied with all applicable federal environmental regulations. Depending upon the outcome of the litigation and further discussions with the EPA regarding the two NOVs/FOVs, DTE Electric could be required to install additional pollution control equipment at some or all of the power plants in question, implement early retirement of facilities where control equipment is not economical, engage in supplemental environmental programs, and/or pay fines. The Registrants cannot predict the financial impact or outcome of this matter, or the timing of its resolution.

The EPA has implemented regulatory actions under the Clean Air Act to address emissions of GHGs from the utility sector and other sectors of the economy. Among these actions, in 2015 the EPA finalized performance standards for emissions of carbon dioxide from new and existing EGUs. In February 2016, the U.S. Supreme Court granted petitioners' requests for a stay of the carbon rules for existing EGUs (also known as the EPA Clean Power Plan) pending final review by the courts. The Clean Power Plan has no legal effect while the stay is in place. On March 28, 2017, a presidential executive order was issued on "Promoting Energy Independence and Economic Growth." The order instructs the EPA to review, and if appropriate, suspend, revise or rescind the Clean Power Plan rule. Following the issuance of this order, the federal government requested the U.S. Court of Appeals for the D.C. Circuit to hold all legal challenges in abeyance until the review of these regulations is completed. On October 10, 2017, the EPA proposed to rescind the Clean Power Plan and announced its intent to issue an ANPR seeking input as to whether it should replace the rule and, if so, what form it should take. It is not possible to determine the potential impact of the EPA's repeal and possible replacement of the 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 $2.4 billion through 2017. DTE Electric does not anticipate additional capital expenditures through 2024.

45

DTE Energy Company — DTE Electric Company

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

Water — In response to an EPA regulation, DTE Electric was required to examine alternatives for reducing the environmental impacts of the cooling water intake structures at several of its facilities. Based on the results of completed studies and expected future studies, DTE Electric may be required to install technologies to reduce the impacts of the water intake structures. A final rule became effective in October 2014. The final rule requires studies to be completed and submitted as part of the National Pollutant Discharge Elimination System (NPDES) permit application process to determine the type of technology needed to reduce impacts to fish. DTE Electric has initiated the process of completing the required studies. Final compliance for the installation of any required technology will be determined by each state on a case by case, site specific basis. DTE Electric is currently evaluating the compliance options and working with the State of Michigan on evaluating whether any controls are needed. These evaluations/studies may require modifications to some existing intake structures. It is not possible to quantify the impact of this rulemaking at this time.

Contaminated and Other Sites — Prior to the construction of major interstate natural gas pipelines, gas for heating and other uses was manufactured locally from processes involving coal, coke, or oil. The facilities, which produced gas, have been designated as MGP sites. DTE Electric conducted remedial investigations at contaminated sites, including three former MGP sites. The investigations have revealed contamination related to the by-products of gas manufacturing at each MGP site. In addition to the MGP sites, DTE Electric is also in the process of cleaning up other contaminated sites, including the area surrounding an ash landfill, electrical distribution substations, electric generating power plants, and underground and aboveground storage tank locations. The findings of these investigations indicated that the estimated cost to remediate these sites is expected to be incurred over the next several years. At June 30, 2018 and December 31, 2017, DTE Electric had $5 million and $6 million, respectively, accrued for remediation. Any change in assumptions, such as remediation techniques, nature and extent of contamination, and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect DTE Electric’s financial position and cash flows. DTE Electric believes the likelihood of a material change to the accrued amount is remote based on current knowledge of the conditions at each site.

Coal Combustion Residuals and Effluent Limitations Guidelines — A final EPA rule for the disposal of coal combustion residuals, commonly known as coal ash, became effective in October 2015, and was revised in October 2016. On March 15, 2018, the EPA published a proposed rule for public comment that is expected to be issued in final form in 2019. Some of the proposed rule provisions could change compliance and closure plans for CCR units if included in the final rule. DTE Electric owns and operates three permitted engineered coal ash storage facilities to dispose of coal ash from coal-fired power plants and operates a number of smaller impoundments at its power plants. CCR obligations vary based on plant life, but include the installation of monitoring wells, compliance with groundwater standards, and the closure of landfills and basins at the end of the useful life of the associated power plant or as a basin becomes inactive.

In November 2015, the EPA finalized the ELG Rule for the steam electric power generating industry which may require additional controls to be installed between 2018 and 2023. On April 12, 2017, the EPA granted a petition for reconsideration of the ELG Rule. The EPA also signed an administrative stay of the ELG Rule’s compliance deadlines for fly ash transport water, bottom ash transport water, and flue gas desulfurization (FGD) wastewater, among others. On June 6, 2017, the EPA published in the Federal Register a proposed rule to postpone certain applicable deadlines within the ELG rule. The final rule was published on September 18, 2017, which extended the earliest compliance deadlines for the FGD wastewater and bottom ash transport until November 1, 2020 in order for the EPA to propose and finalize a new ruling. The ELG compliance requirements, final deadlines, and compliance costs will not be known until the EPA completes its reconsideration of the ELG Rule.

DTE Gas

Contaminated and Other Sites — DTE Gas owns or previously owned, 14 former MGP sites. Investigations have revealed contamination related to the by-products of gas manufacturing at each site. Cleanup of six of the MGP sites is complete, and the sites are closed. DTE Gas has also completed partial closure of six 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, 2018 and December 31, 2017, DTE Gas had $37 million and $41 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.

46

DTE Energy Company — DTE Electric Company

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

Non-utility

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

Other

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

Michigan's Phase 1 non-attainment area includes DTE Energy facilities in southwest Detroit and areas of Wayne County. Modeling runs by the MDEQ suggest that emission reductions may be required by significant sources of SO₂ emissions in these areas, including DTE Electric power plants and DTE Energy's Michigan coke battery facility. As part of the state implementation plan process, DTE Energy has worked with the MDEQ to develop air permits reflecting significant SO₂ emission reductions that, in combination with other non-DTE Energy sources' emission reduction strategies, will help the state attain the standard and sustain its attainment. Since several non-DTE Energy sources are also part of the proposed compliance plan, DTE Energy is unable to determine the full impact of the final required emissions reductions at this time.

Michigan's Phase 2 non-attainment area includes DTE Electric facilities in St. Clair County. State implementation plan (SIP) submittal and EPA approval describing the control strategy and timeline for demonstrating compliance with the new SO₂ standard is the next step in the process, expected to be completed by the end of the year. DTE Energy is currently working with the MDEQ to develop the required SIP. DTE Energy is unable to determine the full impact of the SIP strategy.

Synthetic Fuel Guarantees

DTE Energy discontinued the operations of its synthetic fuel production facilities throughout the United States as of December 31, 2007. DTE Energy provided certain guarantees and indemnities in conjunction with the sales of interests in its synfuel facilities. The guarantees cover potential commercial, environmental, oil price, and tax-related obligations that will survive until 90 days after expiration of all applicable statutes of limitations. DTE Energy estimates that its maximum potential liability under these guarantees at June 30, 2018 was approximately $400 million. Payments under these guarantees are considered remote.

REF Guarantees

DTE Energy has provided certain guarantees and indemnities in conjunction with the sales of interests in or lease of its REF facilities. The guarantees cover potential commercial, environmental, and tax-related obligations that will survive until 90 days after expiration of all applicable statutes of limitations. DTE Energy estimates that its maximum potential liability under these guarantees at June 30, 2018 was $453 million. Payments under these guarantees are considered remote.

NEXUS Guarantees

NEXUS entered into certain 15-year capacity lease agreements for the transportation of natural gas with DTE Gas and Texas Eastern Transmission, LP, an unrelated third party. Pursuant to the terms of those agreements, in December 2016, DTE Energy executed separate guarantee agreements with DTE Gas and Texas Eastern Transmission, LP, with maximum potential payments totaling $84 million and $23 million at June 30, 2018, respectively; each representing 50% of all payment obligations due and payable by NEXUS. Should NEXUS fail to perform under the terms of those agreements, DTE Energy is required to perform on its behalf. Each guarantee terminates at the earlier of (i) such time as all of the guaranteed obligations have been fully performed, or (ii) two months following the end of the primary term of the capacity lease agreements. Subsequent to the NEXUS in-service date, the amount of each guarantee decreases annually as payments are made by NEXUS to each of the aforementioned counterparties. Payments under these guarantees are considered remote.

47

DTE Energy Company — DTE Electric Company

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

Other Guarantees

In certain limited circumstances, the Registrants enter into contractual guarantees. The Registrants may guarantee another entity’s obligation in the event it fails to perform and may provide guarantees in certain indemnification agreements. Finally, the Registrants may provide indirect guarantees for the indebtedness of others. DTE Energy’s guarantees are not individually material with maximum potential payments totaling $56 million at June 30, 2018. Payments under these guarantees are considered remote.

DTE Energy is periodically required to obtain performance surety bonds in support of obligations to various governmental entities and other companies in connection with its operations. As of June 30, 2018, DTE Energy had $59 million of performance bonds outstanding. In the event that such bonds are called for nonperformance, DTE Energy would be obligated to reimburse the issuer of the performance bond. DTE Energy is released from the performance bonds as the contractual performance is completed and does not believe that a material amount of any currently outstanding performance bonds will be called.

Labor Contracts

There are several bargaining units for DTE Energy subsidiaries' approximate 5,000 represented employees, including DTE Electric's approximate 2,700 represented employees. The majority of the represented employees are under contracts that expire in 2020 and 2021.

Purchase Commitments

Utility capital expenditures, expenditures for non-utility businesses, and contributions to equity method investees will be approximately $3.6 billion and $1.9 billion in 2018 for DTE Energy and DTE Electric, respectively. The Registrants have made certain commitments in connection with the estimated 2018 annual capital expenditures and contributions to equity method investees.

Other Contingencies

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

For a discussion of contingencies related to regulatory matters and derivatives, see Notes 5 and 8 to the Consolidated Financial Statements, "Regulatory Matters" and "Financial and Other Derivative Instruments," respectively.

NOTE 12 — RETIREMENT BENEFITS AND TRUSTEED ASSETS

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

	Pension Benefits						Other Postretirement Benefits
	2018			2017			2018			2017
Three Months Ended June 30,	(In millions)
Service cost	$	25		$	23		$	7		$	6
Interest cost	50			53			17			19
Expected return on plan assets	(83		)	(77		)	(35		)	(32		)
Amortization of:
Net actuarial loss	45			43			2			4
Prior service credit	—			—			—			(4		)
Net periodic benefit cost (credit)	$	37		$	42		$	(9	)	$	(7	)

48

DTE Energy Company — DTE Electric Company

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

	Pension Benefits						Other Postretirement Benefits
	2018			2017			2018			2017
Six Months Ended June 30,	(In millions)
Service cost	$	50		$	47		$	14		$	13
Interest cost	100			107			34			37
Expected return on plan assets	(165		)	(155		)	(71		)	(65		)
Amortization of:
Net actuarial loss	89			86			5			7
Prior service credit	—			—			—			(7		)
Net periodic benefit cost (credit)	$	74		$	85		$	(18	)	$	(15	)

DTE Electric participates in various plans that provide pension and other postretirement benefits for DTE Energy and its affiliates. The plans are sponsored by DTE Energy's subsidiary, DTE Energy Corporate Services, LLC. DTE Electric accounts for its participation in DTE Energy's qualified and nonqualified pension plans by applying multiemployer accounting. DTE Electric accounts for its participation in other postretirement benefit plans by applying multiple-employer accounting. Within multiemployer and multiple-employer plans, participants pool plan assets for investment purposes and to reduce the cost of plan administration. The primary difference between plan types is assets contributed in multiemployer plans can be used to provide benefits for all participating employers, while assets contributed within a multiple-employer plan are restricted for use by the contributing employer. As a result of multiemployer accounting treatment, capitalized costs associated with these plans are reflected in Property, plant, and equipment in DTE Electric's Consolidated Financial Statements. The same capitalized costs are reflected as Regulatory assets and liabilities in DTE Energy's Consolidated Financial Statements. Plan participants of all plans are solely DTE Energy and affiliate participants.

DTE Energy's subsidiaries are responsible for their share of qualified and nonqualified pension benefit costs. DTE Electric's allocated portion of pension benefit costs included in capital expenditures and operating and maintenance expense were $30 million and $34 million for the three months ended June 30, 2018 and 2017, respectively, and $60 million and $69 million for the six months endedJune 30, 2018 and 2017, respectively. These amounts include recognized contractual termination benefit charges, curtailment gains, and settlement charges.

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

	Other Postretirement Benefits
	2018			2017
Three Months Ended June 30,	(In millions)
Service cost	$	5		$	5
Interest cost	14			14
Expected return on plan assets	(25		)	(22		)
Amortization of:
Net actuarial loss	2			2
Prior service credit	—			(3		)
Net periodic benefit credit	$	(4	)	$	(4	)

	Other Postretirement Benefits
	2018			2017
Six Months Ended June 30,	(In millions)
Service cost	$	10		$	10
Interest cost	27			28
Expected return on plan assets	(49		)	(45		)
Amortization of:
Net actuarial loss	4			4
Prior service credit	—			(5		)
Net periodic benefit credit	$	(8	)	$	(8	)

49

DTE Energy Company — DTE Electric Company

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

Pension and Other Postretirement Contributions

During 2018, DTE Energy contributed the following amounts of DTE Energy common stock to the DTE Energy Company Affiliates Employee Benefit Plans Master Trust:

Date	Number of Shares	Price per Share	Amount
			(In millions)
March 7, 2018	1,751,401	$99.92	$	175

The above contribution was made on behalf of DTE Electric, who paid DTE Energy cash consideration of $175 million in March 2018. At the discretion of management and depending upon financial market conditions, DTE Energy may make additional contributions up to $25 million to its pension plans in 2018, with no additional contributions planned from DTE Electric.

DTE Energy does not anticipate making any contributions to the other postretirement benefit plans in 2018.

NOTE 13 — SEGMENT AND RELATED INFORMATION

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

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

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

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

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

Energy Trading consists of energy marketing and trading operations.

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

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

50

DTE Energy Company — DTE Electric Company

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

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(In millions)
Electric	$	13	$	13	$	26	$	25
Gas	4		2		6		5
Gas Storage and Pipelines	14		15		22		22
Power and Industrial Projects	162		156		317		324
Energy Trading	5		8		12		19
Corporate and Other	—		—		1		1
	$	198	$	194	$	384	$	396

Financial data of DTE Energy's business segments follows:

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(In millions)
Operating Revenues — Utility operations
Electric	$	1,276		$	1,218		$	2,481		$	2,393
Gas	255			220			805			777
Operating Revenues — Non-utility operations
Gas Storage and Pipelines	122			113			241			218
Power and Industrial Projects	538			507			1,105			1,055
Energy Trading	1,164			991			2,662			2,043
Corporate and Other	2			—			2			1
Reconciliation and Eliminations	(198		)	(194		)	(384		)	(396		)
Total	$	3,159		$	2,855		$	6,912		$	6,091

Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	163		$	138		$	303		$	244
Gas	14			1			118			108
Gas Storage and Pipelines	60			40			122			85
Power and Industrial Projects	43			30			88			60
Energy Trading	(5		)	—			26			96
Corporate and Other	(41		)	(32		)	(62		)	(16		)
Net Income Attributable to DTE Energy Company	$	234		$	177		$	595		$	577

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.

51

The following table summarizes DTE Energy's financial results:

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(In millions, except per share amounts)
Net Income Attributable to DTE Energy Company	$	234	$	177	$	595	$	577
Diluted Earnings per Common Share	$	1.29	$	0.99	$	3.29	$	3.21

The increase in Net Income in the second quarter was primarily due to higher earnings in the Electric, Gas, Gas Storage and Pipelines, and Power and Industrial Projects segments. The increase in Net Income in the six-month period was primarily due to higher earnings in the Electric, Gas, Gas Storage and Pipelines, and Power and Industrial Projects segments, partially offset by lower earnings in the Energy Trading and Corporate and Other segments. The increase in the six-month period was impacted by true-up adjustments for the remeasurement of deferred taxes of $21 million. The impact of the true-up adjustments was an increase in Income Tax Expense, of which $16 million was attributable to the regulated utilities and offset to Regulatory liabilities.Total Income Tax Expense decreased from the prior year due to the reduction of the corporate tax rate from 35% to 21%, which became effective in 2018.

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

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

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

In May 2017, DTE Energy announced its plan to reduce carbon emissions. This goal will be attained by cutting carbon emissions 30% by the early 2020s, 45% by 2030, 75% by 2040, and more than 80% by 2050. To achieve this reduction, DTE Energy will transition away from coal-powered sources and incorporate more renewable energy, energy waste reduction, demand response, and highly-efficient natural gas fueled power plants. DTE Energy has already begun the transition in the way it produces power through the continued retirement of its aging coal-fired plants. In May 2018, DTE Energy announced its plans to accelerate its clean energy initiatives by targeting at least a 50% clean energy goal by 2030, achieved through a combination of investments in renewable energy and energy efficiency projects. Refer to the "Capital Investments" section below for further discussion.

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

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

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.

52

DTE Electric's capital investments over the 2018-2022 period are estimated at $10.4 billion comprised of $4.1 billion for capital replacements and other projects, $4.3 billion for distribution infrastructure, and $2.0 billion for new generation. DTE Electric has retired four coal-fired generation units at the Trenton Channel, River Rouge, and St. Clair facilities and has announced plans to retire its remaining thirteen coal-fired generating units. Seven of these coal-fired generating units will be retired through 2023 at the Trenton Channel, River Rouge, and St. Clair facilities. The remaining coal-fired generating units at the Belle River and Monroe facilities are expected to be retired by 2040. The retired facilities will be replaced with renewables, energy efficiency, demand response, and natural gas fueled generation. DTE Electric constructed and placed in service 50 megawatts of solar generation in 2017. In April 2018, DTE Electric received approval from the MPSC to build a natural gas fueled combined cycle generation facility to provide approximately 1,100 megawatts of energy beginning in 2022. In March 2018, DTE Electric filed its 2018 Renewable Energy Plan with the MPSC proposing approximately 1,000 additional megawatts of energy from new wind and solar projects to be completed by 2022. The MPSC had previously approved 300 of the 1,000 additional megawatts for wind projects in an MPSC order received in September 2016. In January 2018, DTE Electric filed with the MPSC its five-year distribution operations investment and maintenance plan to improve system reliability. DTE Electric plans to seek regulatory approval for capital expenditures consistent with prior ratemaking treatment. For further discussion of regulatory matters, see Note 5 to the Consolidated Financial Statements, "Regulatory Matters."

DTE Gas' capital investments over the 2018-2022 period are estimated at $2.1 billion comprised of $950 million for base infrastructure, $1.1 billion for gas main renewal, meter move out, and pipeline integrity programs, and $10 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 2018-2022 period are estimated at $2.8 billion to $3.4 billion for gathering and pipeline investments and expansions, including the NEXUS Pipeline. Power and Industrial Projects' capital investments over the 2018-2022 period are estimated at $800 million to $1.2 billion for investments in cogeneration and on-site energy projects.

ENVIRONMENTAL MATTERS

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

DTE Electric is subject to the EPA ozone and fine particulate transport and acid rain regulations that limit power plant emissions of SO₂ and NO_X. The EPA and the State of Michigan have also issued emission reduction regulations relating to ozone, fine particulate, regional haze, mercury, and other air pollution. These rules have led to controls on fossil-fueled power plants to reduce SO₂, NO_X, mercury, and other emissions. Additional rulemakings may occur over the next few years which could require additional controls for SO₂, NO_X, and other hazardous air pollutants. To comply with existing requirements, DTE Electric spent approximately $2.4 billion through 2017. DTE Electric does not anticipate additional capital expenditures through 2024.

The EPA has implemented regulatory actions under the Clean Air Act to address emissions of GHGs from the utility sector and other sectors of the economy. Among these actions, in 2015 the EPA finalized performance standards for emissions of carbon dioxide from new and existing EGUs. In February 2016, the U.S. Supreme Court granted petitioners' requests for a stay of the carbon rules for existing EGUs (also known as the EPA Clean Power Plan) pending final review by the courts. The Clean Power Plan has no legal effect while the stay is in place. On March 28, 2017, a presidential executive order was issued on "Promoting Energy Independence and Economic Growth." The order instructs the EPA to review, and if appropriate, suspend, revise or rescind the Clean Power Plan rule. Following the issuance of this order, the federal government requested the U.S. Court of Appeals for the D.C. Circuit to hold all legal challenges in abeyance until the review of these regulations is completed. On October 10, 2017, the EPA proposed to rescind the Clean Power Plan and announced its intent to issue an ANPR seeking input as to whether it should replace the rule and, if so, what form it should take. It is not possible to determine the potential impact of the EPA's repeal and possible replacement of the Clean Power Plan on existing sources at this time.

53

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 fueled generation, and/or nuclear sources, energy efficiency initiatives, and the potential development of market-based trading of carbon instruments which could provide new business opportunities for DTE Energy's utility and non-utility segments. At the present time, it is not possible to quantify the financial impacts of these climate related regulatory initiatives on the Registrants or their customers.

For further discussion of environmental matters, see Note 11 to the Consolidated Financial Statements, "Commitments and Contingencies."

OUTLOOK

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

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

• electric and gas customer satisfaction;

• electric distribution system reliability;

• new electric generation;

• gas distribution system renewal;

• rate competitiveness and affordability;

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

• employee safety and engagement;

• cost structure optimization across all business segments;

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

• investments that integrate assets and leverage skills and expertise.

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

RESULTS OF OPERATIONS

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

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

54

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

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

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

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

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(In millions)
Net Income (Loss) Attributable to DTE Energy by Segment
Electric	$	163		$	138		$	303		$	244
Gas	14			1			118			108
Gas Storage and Pipelines	60			40			122			85
Power and Industrial Projects	43			30			88			60
Energy Trading	(5		)	—			26			96
Corporate and Other	(41		)	(32		)	(62		)	(16		)
Net Income Attributable to DTE Energy Company	$	234		$	177		$	595		$	577

55

ELECTRIC

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

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(In millions)
Operating Revenues — Utility operations	$	1,276	$	1,218	$	2,481	$	2,393
Fuel and purchased power — utility	386		355		725		669
Utility Margin	890		863		1,756		1,724
Operation and maintenance	337		325		649		696
Depreciation and amortization	202		180		414		361
Taxes other than income	74		75		155		155
Operating Income	277		283		538		512
Other (Income) and Deductions	70		71		144		137
Income Tax Expense	44		74		91		131
Net Income Attributable to DTE Energy Company	$	163	$	138	$	303	$	244

See DTE Electric's Consolidated Statements of Operations for a complete view of its results. For an explanation of differences between the Electric segment and DTE Electric's Consolidated Statements of Operations, refer to Note 12 to the Consolidated Financial Statements, "Retirement Benefits and Trusteed Assets."

Utility Marginincreased$27 million and $32 million in the three and six months endedJune 30, 2018, respectively. Revenues associated with certain mechanisms and surcharges are offset by related expenses elsewhere in the Registrants' Consolidated Statements of Operations.

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

	Three Months			Six Months
	(In millions)
Weather	$	41		$	66
Implementation of new rates	17			31
PSCR disallowance in 2017	13			13
Base sales	(9		)	(14		)
TCJA rate reduction reserve	(38		)	(77		)
Regulatory mechanisms and other	3			13
Increase in Utility Margin	$	27		$	32

56

	Three Months Ended June 30,		Six Months Ended June 30,
	2018	2017	2018	2017
	(In thousands of MWh)
DTE Electric Sales
Residential	3,682	3,436	7,359	6,954
Commercial	4,352	4,324	8,382	8,407
Industrial	2,648	2,458	5,252	4,833
Other	51	61	108	140
	10,733	10,279	21,101	20,334
Interconnection sales(a)	812	1,340	1,894	2,012
Total DTE Electric Sales	11,545	11,619	22,995	22,346
DTE Electric Deliveries
Retail and wholesale	10,733	10,279	21,101	20,334
Electric retail access, including self-generators(b)	1,215	1,194	2,357	2,388
Total DTE Electric Sales and Deliveries	11,948	11,473	23,458	22,722

______________________________

(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$12 million and decreased$47 million in the three and six months endedJune 30, 2018, respectively. The increase in the second quarter was primarily due to increased distribution expenses of $4 million and increased uncollectible expense of $4 million. The decrease in the six-month period was primarily due to decreased power plant generation expenses of $23 million, decreased storm restoration expenses of $19 million, and a one-time benefits expense reimbursement of $9 million, partially offset by increased uncollectible expense of $7 million. The decrease in power plant generation expenses includes a decrease of $17 million of costs related to the 2016 fire at a generation facility incurred in 2017 and $8 million in related insurance proceeds received in 2018.

Depreciation and amortization expense increased$22 million and $53 million in the three and six months endedJune 30, 2018, respectively. The increase in the second quarter was primarily due to an increase to depreciable base of $11 million and an increase of $13 million associated with the TRM. The increase in the six-month period was primarily due to an increase to depreciable base of $25 million and an increase of $31 million associated with the TRM.

Other (Income) and Deductionsdecreased$1 million and increased$7 million in the three and six months endedJune 30, 2018, respectively. The decrease in the second quarter was primarily due to decreased debt expense of $2 million and decreased non-operating retirement benefits of $3 million, partially offset by lower investment earnings of $4 million. The increase in the six-month period was primarily due to lower investment earnings of $14 million, partially offset by decreased non-operating retirement benefits of $7 million.

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

DTE Electric filed a rate case with the MPSC on April 19, 2017 requesting an increase in base rates of $231 million based on a projected twelve-month period ending October 31, 2018. On November 1, 2017, DTE Electric self-implemented a base rate increase of $125 million. On April 18, 2018, the MPSC issued an order approving an annual revenue increase of $65.2 million for service rendered on or after May 1, 2018. The MPSC authorized a return on equity of 10.0%. On June 28, 2018, the MPSC issued an order on a rehearing granting in part and denying in part, petitions for rehearings of DTE Electric and other intervenors. As a result, the approved addition to base rates increased from $65.2 million to $74.4 million. DTE Electric has recorded a refund liability of $25 million, representing the total estimated refund due to customers, inclusive of interest, at June 30, 2018. In August 2018, DTE Electric will file to refund its customers based on their pro rata share of the revenue collected through the self-implementation surcharge in effect from November 1, 2017 to May 1, 2018.

57

DTE Electric filed a rate case with the MPSC on July 6, 2018 requesting an increase in base rates of $328 million based on a projected twelve-month period ending April 30, 2020. The requested increase in base rates is primarily due to an increase in net plant resulting from infrastructure investments, depreciation expense, as requested in the 2016 DTE Main Electric Depreciation Case Filing, and reliability improvement projects. The rate filing also requests an increase in return on equity from 10.0% to 10.5% and includes projected changes in sales, operation and maintenance expenses, and working capital. In addition, the rate filing requests an Infrastructure Recovery Mechanism to recover the incremental revenue requirement associated with certain distribution, fossil generation, and nuclear generation capital expenditures through 2022. Finally, as noted below, DTE Electric addressed Calculation C in this filing. A final MPSC order in this case is expected by May 2019.

On January 19, 2018, DTE Electric filed information with the MPSC regarding the potential change in revenue requirements due to the TCJA effective January 1, 2018, and outlined its recommended method to flow the current and deferred tax benefits of those impacts to ratepayers.

On February 22, 2018, the MPSC issued an order in this case requiring utilities, including DTE Electric, to follow a 3-step approach of credits and calculations. The first step is to establish Credit A, through contested cases. Credit A is a going-forward tax credit to reflect the reduction of the corporate tax rate from 35% to 21%. DTE Electric filed its Credit A application on May 18, 2018, reflecting a reduction in revenues of $157 million. On July 24, 2018, the MPSC issued an order approving a settlement in DTE Electric's Credit A filing reflecting a reduction in revenues of $157 million. Rates reflecting this reduction will be effective August 1, 2018. The second step is to establish Credit B, through contested cases. Credit B is a backward-looking tax credit to reflect the reduction of the corporate rate of 35% to 21%, for the period January 1, 2018 through the date Credit A is established. The Credit B filing is required within sixty days after Credit A is implemented. For Credit B, DTE Electric has been deferring the impact of the reduction to the corporate tax rate since January 1, 2018. The third step is to perform Calculation C, through contested cases. Calculation C will address all remaining issues relative to the new tax law, which is primarily the remeasurement of deferred taxes and how the amounts deferred as Regulatory liabilities will flow to ratepayers. DTE Electric addressed Calculation C in its general rate case filed July 6, 2018.

GAS

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(In millions)
Operating Revenues — Utility operations	$	255	$	220	$	805	$	777
Cost of gas — utility	53		45		273		266
Utility Margin	202		175		532		511
Operation and maintenance	122		112		233		219
Depreciation and amortization	31		30		63		60
Taxes other than income	18		18		39		38
Operating Income	31		15		197		194
Other (Income) and Deductions	13		14		27		27
Income Tax Expense	4		—		52		59
Net Income Attributable to DTE Energy Company	$	14	$	1	$	118	$	108

Utility Marginincreased$27 million and $21 million in the three and six months endedJune 30, 2018, respectively. Revenues associated with certain surcharges are offset by related expenses elsewhere in DTE Energy's Consolidated Statements of Operations.

58

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

	Three Months			Six Months
	(In millions)
Weather	$	16		$	46
Midstream storage and transportation revenues	2			4
Revenue decoupling mechanism	(1		)	(4		)
TCJA rate reduction reserve	5			(27		)
Other	5			2
Increase in Utility Margin	$	27		$	21

	Three Months Ended June 30,		Six Months Ended June 30,
	2018	2017	2018	2017
	(In Bcf)
Gas Markets
Gas sales	21	16	83	69
End-user transportation	45	33	104	85
	66	49	187	154
Intermediate transportation	62	68	134	150
Total Gas sales	128	117	321	304

Operation and maintenance expense increased$10 million and $14 million in the three and six months endedJune 30, 2018, respectively. The increase in the second quarter was primarily due to increased gas operations expenses of $5 million and increased uncollectible expense of $4 million. The increase in the six-month period was primarily due to increased uncollectible expense of $9 million and increased gas operations expenses of $6 million.

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

DTE Gas filed a rate case with the MPSC on November 22, 2017 requesting an increase in base rates of $85.1 million based on a projected twelve-month period ending September 30, 2019. The requested increase in base rates is primarily due to an increase in net plant. The rate filing also requests an increase in return on equity from 10.1% to 10.5% and includes projected changes in sales, operations and maintenance expenses, and working capital. On May 24, 2018, DTE Gas reduced its initial requested increase in base rates to $38.1 million, primarily due to the effects of the TCJA on the original request. A final MPSC order in this case is expected by September 2018.

On January 19, 2018, DTE Gas filed information with the MPSC regarding the potential change in revenue requirements due to the TCJA effective January 1, 2018, and outlined its recommended method to flow the current and deferred tax benefits of those impacts to ratepayers.

On February 22, 2018, the MPSC issued an order in this case requiring utilities, including DTE Gas, to follow a 3-step approach of credits and calculations. The first step is to establish Credit A, through contested cases. Credit A is a going-forward tax credit to reflect the reduction of the corporate tax rate from 35% to 21%. DTE Gas submitted its Credit A filing on March 28, 2018, reflecting a reduction in revenues of $38.2 million. The MPSC approved the $38.2 million reduction on May 30, 2018, to be effective July 1, 2018. The second step is to establish Credit B, through contested cases. Credit B is a backward-looking tax credit to reflect the reduction of the corporate rate of 35% to 21%, for the period January 1, 2018 through the date Credit A is established. The Credit B filing is required within sixty days after Credit A is implemented. For Credit B, DTE Gas has been deferring the impact of the reduction to the corporate tax rate since January 1, 2018. The third step is to perform Calculation C, through contested cases. Calculation C will address all remaining issues relative to the new tax law, which is primarily the remeasurement of deferred taxes and how the amounts deferred as Regulatory liabilities will flow to ratepayers. DTE Gas is required to file Calculation C no later than October 1, 2018.

59

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,
	2018			2017			2018			2017
	(In millions)
Operating Revenues — Non-utility operations	$	122		$	113		$	241		$	218
Cost of gas — Non-utility	9			9			13			15
Operation and maintenance	23			19			46			38
Depreciation and amortization	19			19			39			38
Taxes other than income	2			1			5			4
Asset (gains) losses and impairments, net	—			1			(2		)	1
Operating Income	69			64			140			122
Other (Income) and Deductions	(16		)	(9		)	(33		)	(23		)
Income Tax Expense	17			26			36			47
Net Income	68			47			137			98
Less: Net Income Attributable to Noncontrolling Interests	8			7			15			13
Net Income Attributable to DTE Energy Company	$	60		$	40		$	122		$	85

Operating Revenues — Non-utility operationsincreased$9 million and $23 million in the three and six months endedJune 30, 2018, respectively. The increase in both periods was primarily due to increased pipeline and gathering volumes.

Operation and maintenanceexpense increased$4 million and $8 million in the three and six months endedJune 30, 2018, respectively. The increase in both periods was primarily due to additional compression activity on the Bluestone Pipeline and Susquehanna gathering systems and increased labor related expenses.

Other (Income) and Deductionsincreased$7 million and $10 million in the three and six months endedJune 30, 2018, respectively. The increase in both periods was primarily due to increased earnings from pipeline investments.

Outlook — The Bluestone Pipeline and Susquehanna gathering system are being expanded with additional compression facilities and gathering lines as needed to accommodate shipper demand. DTE Energy believes its long-term agreement with Southwestern Energy Production Company and the quality of the natural gas reserves in the Marcellus region soundly positions Bluestone Pipeline and Susquehanna gathering system for future growth.

Progress continues on development activities on the NEXUS Pipeline, a transportation path to transport Appalachian Basin shale gas, including Utica and Marcellus shale gas, directly to consuming markets in northern Ohio, southeastern Michigan, and Dawn Ontario. DTE Energy owns a 50% partnership interest in the NEXUS Pipeline, with an investment balance of $868 million at June 30, 2018. The FERC application was approved on August 25, 2017 and construction commenced in October 2017. DTE Energy anticipates a third quarter 2018 in-service date for the NEXUS Pipeline.

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

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

60

POWER AND INDUSTRIAL PROJECTS

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

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(In millions)
Operating Revenues — Non-utility operations	$	538		$	507		$	1,105		$	1,055
Fuel, purchased power, and gas — non-utility	464			442			962			928
Non-utility Margin	74			65			143			127
Operation and maintenance	90			85			172			167
Depreciation and amortization	17			19			33			37
Taxes other than income	3			2			7			6
Asset (gains) losses and impairments, net	—			2			—			2
Operating Loss	(36		)	(43		)	(69		)	(85		)
Other (Income) and Deductions	(23		)	(22		)	(41		)	(38		)
Income Taxes
Benefit	(2		)	(4		)	(2		)	(10		)
Production Tax Credits	(48		)	(38		)	(91		)	(76		)
	(50		)	(42		)	(93		)	(86		)
Net Income	37			21			65			39
Less: Net Loss Attributable to Noncontrolling Interests	(6		)	(9		)	(23		)	(21		)
Net Income Attributable to DTE Energy Company	$	43		$	30		$	88		$	60

Operating Revenues — Non-utility operationsincreased$31 million and $50 million in the three and six months endedJune 30, 2018, respectively. The increase was due to the following:

	Three Months		Six Months
	(In millions)
Higher demand due to improved conditions in the steel business	$	10	$	37
Higher production in the renewables business	11		17
Higher production offset by lower coal prices in the REF business	6		—
Lower coal prices offset by higher production in the REF business	—		(3		)
Other	4		(1		)
	$	31	$	50

Non-utility Marginincreased$9 million and $16 million in the three and six months endedJune 30, 2018, respectively. The increase was due to the following:

	Three Months			Six Months
	(In millions)
New projects and higher production in the renewables business	$	10		$	15
Other	(1		)	1
	$	9		$	16

Operation and maintenanceexpenseincreased$5 million in the three and six months endedJune 30, 2018. The increase in the second quarter and six-month period was primarily due to higher production in the REF business.

Income Taxes — Production Tax Creditsincreased$10 million and $15 million in the three and six months endedJune 30, 2018, respectively. The increase in the second quarter and six-month period was primarily due to higher production in the REF business.

61

Outlook — Power and Industrial Projects has constructed and placed in service REF facilities at ten sites including facilities located at seven third-party owned coal-fired power plants. DTE Energy has sold membership interests in four of the facilities and entered into lease arrangements in two of the facilities. DTE Energy is currently negotiating two additional lease transactions at existing facilities and will continue to optimize the remaining facilities.

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,
	2018			2017		2018		2017
	(In millions)
Operating Revenues — Non-utility operations	$	1,164		$	991	$	2,662	$	2,043
Purchased power and gas — non-utility	1,149			972		2,585		1,845
Non-utility Margin	15			19		77		198
Operation and maintenance	17			16		34		35
Depreciation and amortization	2			1		3		2
Taxes other than income	1			2		3		3
Operating Income (Loss)	(5		)	—		37		158
Other (Income) and Deductions	1			—		2		1
Income Tax Expense (Benefit)	(1		)	—		9		61
Net Income (Loss) Attributable to DTE Energy Company	$	(5	)	$	—	$	26	$	96

Operating Revenues — Non-utility operationsincreased$173 million and $619 million in the three and six months endedJune 30, 2018, respectively. The increase in the second quarter was primarily due to higher volumes offset by lower gas prices in the gas structured strategy. The increase in the six-month period was primarily due to higher volumes and higher gas prices in the gas structured strategy.

Non-utility Margindecreased$4 million and $121 million in the three and six months endedJune 30, 2018, respectively. The decreases were due to the unrealized and realized margins presented in the following table:

	Three Months
	(In millions)
Unrealized Margins(a)
Favorable results, primarily in power full requirements and gas trading strategies	$	9
Unfavorable results, primarily in the gas structured strategy(b)	(31		)
	(22		)
Realized Margins(a)
Favorable results, primarily in gas structured and power trading strategies(c)	26
Unfavorable results, primarily in the environmental trading strategy	(8		)
	18
Decrease in Non-utility Margin	$	(4	)

_______________________________________

(a) Natural gas structured transactions typically involve a physical purchase or sale of natural gas in the future and/or natural gas basis financial instruments which are derivatives and a related non-derivative pipeline transportation contract. These gas structured transactions can result in significant earnings volatility as the derivative components are marked-to-market without revaluing the related non-derivative contracts.

(b) Amount includes $28 million of timing related losses related to gas strategies which will reverse in future periods as the underlying contracts settle.

(c) Amount includes $15 million of timing related losses related to gas strategies recognized in previous periods that reversed as the underlying contracts settled.

62

	Six Months
	(In millions)
Unrealized Margins(a)
Favorable results, primarily in the gas trading strategy	$	9
Unfavorable results, primarily in gas structured and gas storage strategies(b)	(106		)
	(97		)
Realized Margins(a)
Favorable results, primarily in the gas storage strategy(c)	38
Unfavorable results, primarily in power and gas full requirements, gas trading, and gas structured strategies	(62		)
	(24		)
Decrease in Non-utility Margin	$	(121	)

_______________________________________

(a) Natural gas structured transactions typically involve a physical purchase or sale of natural gas in the future and/or natural gas basis financial instruments which are derivatives and a related non-derivative pipeline transportation contract. These gas structured transactions can result in significant earnings volatility as the derivative components are marked-to-market without revaluing the related non-derivative contracts.

(b) Amount includes $106 million of timing related losses related to gas strategies which will reverse in future periods as the underlying contracts settle.

(c) Amount includes $7 million of timing related losses related to gas strategies recognized in previous periods that reversed as the underlying contracts settled.

Outlook — In the near-term, Energy Trading expects market conditions to remain challenging, and the profitability of this segment may be impacted by the volatility in commodity prices and the uncertainty of impacts associated with 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 also the "Fair Value" section herein and Notes 7 and 8 to the Consolidated Financial Statements, "Fair Value" and "Financial and Other Derivative Instruments," respectively.

CORPORATE AND OTHER

Corporate and Other includes various holding company activities, holds certain non-utility debt, and holds energy-related investments. The net losses of $41 million and $62 million in the three and six months endedJune 30, 2018, respectively, represent increases of $9 million and $46 million from the net losses of $32 million and $16 million in the comparable 2017 period. The increase in the second quarter was primarily due to a reduction in the corporate tax rate from the TCJA in December 2017 and higher interest expense. For the six-month period, the increase was primarily due to effective tax rate adjustments, a reduction in the corporate tax rate from the TCJA in December 2017, lower excess tax benefits on stock-based compensation, and higher interest expense.

CAPITAL RESOURCES AND LIQUIDITY

Cash Requirements

DTE Energy uses cash to maintain and invest in the electric and natural gas utilities, to grow the non-utility businesses, to retire, and pay interest on long-term debt, and to pay dividends. DTE Energy believes it will have sufficient internal and external capital resources to fund anticipated capital and operating requirements. DTE Energy expects that cash from operations in 2018 will be approximately $2.2 billion. DTE Energy anticipates base level utility capital investments, including environmental, renewable, and energy waste reduction expenditures; expenditures for non-utility businesses; and contributions to equity method investees in 2018 of approximately $3.6 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.

63

	Six Months Ended June 30,
	2018			2017
	(In millions)
Cash, Cash Equivalents, and Restricted Cash
Cash Flow From (Used For)
Operating Activities
Net Income	$	587		$	569
Adjustments to reconcile Net Income to Net cash from operating activities:
Depreciation and amortization	553			498
Nuclear fuel amortization	25			24
Allowance for equity funds used during construction	(13		)	(12		)
Deferred income taxes	80			164
Asset (gains) losses and impairments, net	—			3
Working capital and other	201			(63		)
Net cash from operating activities	1,433			1,183
Investing Activities
Plant and equipment expenditures — utility	(1,027		)	(968		)
Plant and equipment expenditures — non-utility	(130		)	(68		)
Contributions to equity method investees	(233		)	(175		)
Other	10			(37		)
Net cash used for investing activities	(1,380		)	(1,248		)
Financing Activities
Issuance of long-term debt, net of issuance costs	520			495
Redemption of long-term debt	(102		)	(6		)
Short-term borrowings, net	(147		)	(79		)
Issuance of common stock	6			—
Repurchase of common stock	—			(51		)
Dividends on common stock	(309		)	(296		)
REF contributions from noncontrolling interests	22			21
Distributions to noncontrolling interests	(17		)	(20		)
Other	(29		)	(28		)
Net cash from (used for) financing activities	(56		)	36
Net Decrease in Cash, Cash Equivalents, and Restricted Cash	$	(3	)	$	(29	)

Cash from Operating Activities

A majority of DTE Energy's operating cash flows are provided by the electric and natural gas utilities, which are significantly influenced by factors such as weather, electric retail access, regulatory deferrals, regulatory outcomes, economic conditions, changes in working capital, and operating costs.

Cash from operations increased by $250 million in 2018 due primarily to an increase in Net Income, Depreciation and amortization, and working capital adjustments, partially offset by a decrease to Deferred income taxes.

The change in working capital items in 2018 is primarily related to increases of cash from Inventories, and Other current and noncurrent assets and liabilities, and a decrease in cash used for Derivative assets and liabilities, partially offset by increases in cash used for Accounts payable, Accrued pension obligation, and Accrued postretirement obligation, and a decrease in cash from Accounts receivable, net.

Cash used for Investing Activities

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

64

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

Capital spending within the non-utility businesses is primarily for ongoing maintenance, expansion, and growth. DTE Energy looks to make growth investments that meet strict criteria in terms of strategy, management skills, risks, and returns. All new investments are analyzed for their rates of return and cash payback on a risk adjusted basis. DTE Energy has been disciplined in how it deploys capital and will not make investments unless they meet the criteria. For new business lines, DTE Energy initially invests based on research and analysis. DTE Energy starts with a limited investment, evaluates the results, and either expands or exits the business based on those results. In any given year, the amount of growth capital will be determined by the underlying cash flows of DTE Energy, with a clear understanding of any potential impact on its credit ratings.

Net cash used for investing activities increased by $132 million in 2018 due primarily to an increase in capital expenditures, and Contributions to equity method investees, primarily to the NEXUS pipeline, partially offset by a decrease in Investing Activities - Other, primarily the result of two 2017 acquisitions of landfill gas facilities, which are presented in Investing Activities - Other.

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 54%, to ensure it is consistent with the objective of a strong investment grade debt rating.

Net cash used for financing activities increased by $92 million in 2018 due primarily to an increase in Redemptions of long-term debt and Short-term borrowings, partially offset by an increase in Issuances of long-term term, and a decrease in Repurchases of common stock.

Outlook

DTE Energy expects cash flows from operations to increase over the long-term, primarily as a result of growth from the utility and non-utility businesses. Growth in the utilities is expected to be driven primarily by capital spending to maintain and improve the electric generation and electric and natural gas distribution infrastructure and to comply with new and existing state and federal regulations that will result in additional environmental and renewable energy investments which will increase the base from which rates are determined. Non-utility growth is expected from additional investments, primarily in the Gas Storage and Pipelines and Power and Industrial Projects segments.

DTE Energy may be impacted by the timing of collection or refund of various recovery and tracking mechanisms, as a result of timing of MPSC orders. Energy prices are likely to be a source of volatility with regard to working capital requirements for the foreseeable future. DTE Energy continues its efforts to identify opportunities to improve cash flows through working capital initiatives and maintaining flexibility in the timing and extent of long-term capital projects.

DTE Energy has approximately $5 million in long-term debt, including capital leases, maturing in the next twelve months. The repayment of the debt is expected to be paid through internally generated funds or the issuance of long-term debt.

DTE Energy has approximately $1.6 billion of available liquidity at June 30, 2018, consisting of cash and amounts available under unsecured revolving credit agreements.

DTE Energy expects to issue equity up to $300 million in 2018 through the dividend reinvestment plan and pension and other employee benefit plans.

At the discretion of management, and depending upon financial market conditions, DTE Energy may make additional contributions up to $25 million to its pension plans in 2018. DTE Energy does not anticipate making any contributions to the other postretirement benefit plans in 2018.

65

Various subsidiaries and equity investees of DTE Energy have entered into contracts which contain ratings triggers and are guaranteed by DTE Energy. These contracts contain provisions which allow the counterparties to require that DTE Energy post cash or letters of credit as collateral in the event that DTE Energy's credit rating is downgraded below investment grade. Certain of these provisions (known as "hard triggers") state specific circumstances under which DTE Energy can be required to post collateral upon the occurrence of a credit downgrade, while other provisions (known as "soft triggers") are not as specific. For contracts with soft triggers, it is difficult to estimate the amount of collateral which may be requested by counterparties and/or which DTE Energy may ultimately be required to post. The amount of such collateral which could be requested fluctuates based on commodity prices (primarily natural gas, power, and coal) and the provisions and maturities of the underlying transactions. As of June 30, 2018, 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 $508 million.

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

See Notes 5, 9, 10, 11, and 12 to the Consolidated Financial Statements, "Regulatory Matters," "Long-Term Debt," "Short-Term Credit Arrangements and Borrowings," "Commitments and Contingencies," and "Retirement Benefits and Trusteed Assets," respectively.

NEW ACCOUNTING PRONOUNCEMENTS

See Note 3 to the Consolidated Financial Statements, "New Accounting Pronouncements."

FAIR VALUE

Derivatives are generally recorded at fair value and shown as Derivative assets or liabilities. Contracts DTE Energy typically classifies as derivative instruments include power, natural gas, oil, and certain coal forwards, futures, options and swaps, and foreign currency exchange contracts. Items DTE Energy does not generally account for as derivatives include natural gas inventory, pipeline transportation contracts, renewable energy credits, and storage assets. See Notes 7 and 8 to the Consolidated Financial Statements, "Fair Value" and "Financial and Other Derivative Instruments," respectively.

The tables below do not include the expected earnings impact of non-derivative natural gas storage, transportation, certain power contracts, and renewable energy credits which are subject to accrual accounting. Consequently, gains and losses from these positions may not match with the related physical and financial hedging instruments in some reporting periods, resulting in volatility in the Registrants' reported period-by-period earnings; however, the financial impact of the timing differences will reverse at the time of physical delivery and/or settlement.

The Registrants manage their MTM risk on a portfolio basis based upon the delivery period of their contracts and the individual components of the risks within each contract. Accordingly, the Registrants record and manage the energy purchase and sale obligations under their contracts in separate components based on the commodity (e.g. electricity or natural gas), the product (e.g. electricity for delivery during peak or off-peak hours), the delivery location (e.g. by region), the risk profile (e.g. forward or option), and the delivery period (e.g. by month and year).

The Registrants have established a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). For further discussion of the fair value hierarchy, see Note 7 to the Consolidated Financial Statements, "Fair Value."

66

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

	DTE Energy
	(In millions)
MTM at December 31, 2017	$	8
Reclassified to realized upon settlement	81
Changes in fair value recorded to income	(74		)
Amounts recorded to unrealized income	7
Changes in fair value recorded in regulatory liabilities	15
Change in collateral	(14		)
MTM at June 30, 2018	$	16

The table below shows the maturity of DTE Energy's MTM positions. The positions from 2021 and beyond principally represent longer tenor gas structured transactions:

Source of Fair Value	2018			2019			2020			2021 and Beyond			Total Fair Value
	(In millions)
Level 1	$	2		$	(1	)	$	(2	)	$	(2	)	$	(3	)
Level 2	18			10			5			9			42
Level 3	(7		)	15			6			(37		)	(23		)
MTM before collateral adjustments	$	13		$	24		$	9		$	(30	)	16
Collateral adjustments													—
MTM at June 30, 2018													$	16

67

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Market Price Risk

The Electric and Gas businesses have commodity price risk, primarily related to the purchases of coal, natural gas, uranium, and electricity. However, the Registrants do not bear significant exposure to earnings risk, as such changes are included in the PSCR and GCR regulatory rate-recovery mechanisms. In addition, changes in the price of natural gas can impact the valuation of lost and stolen gas, storage sales, and transportation services revenue at the Gas segment. The Gas segment manages its market price risk related to storage sales revenue primarily through the sale of long-term storage contracts. The Registrants are exposed to short-term cash flow or liquidity risk as a result of the time differential between actual cash settlements and regulatory rate recovery.

DTE Energy's Gas Storage and Pipelines segment has exposure to natural gas price fluctuations which impact the pricing for natural gas storage, gathering, and transportation. DTE Energy manages its exposure through the use of short, medium, and long-term storage, gathering, and transportation contracts.

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

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

Credit Risk

The Registrants regularly review contingent matters relating to customers and their contracts and record provisions for amounts considered at risk of probable loss in the allowance for doubtful accounts. The Registrants believe their accrued amounts are adequate for probable loss.

68

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, 2018:

	Credit Exposure Before Cash Collateral		Cash Collateral			Net Credit Exposure
	(In millions)
Investment Grade(a)
A− and Greater	$	285	$	—		$	285
BBB+ and BBB	237		—			237
BBB−	75		—			75
Total Investment Grade	597		—			597
Non-investment grade(b)	27		—			27
Internally Rated — investment grade(c)	234		—			234
Internally Rated — non-investment grade(d)	23		(4		)	19
Total	$	881	$	(4	)	$	877

_______________________________________

(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 18% 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 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 12% 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 2% of the total gross credit exposure.

Other

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

Interest Rate Risk

DTE Energy is subject to interest rate risk in connection with the issuance of debt. In order to manage interest costs, DTE Energy may use treasury locks and interest rate swap agreements. DTE Energy's exposure to interest rate risk arises primarily from changes in U.S. Treasury rates, commercial paper rates, and London Inter-Bank Offered Rates (LIBOR). As of June 30, 2018, DTE Energy had a floating rate debt-to-total debt ratio of 3.6%.

Foreign Currency Exchange Risk

DTE Energy has foreign currency exchange risk arising from market price fluctuations associated with fixed priced contracts. These contracts are denominated in Canadian dollars and are primarily for the purchase and sale of natural gas and power, as well as for long-term transportation capacity. To limit DTE Energy's exposure to foreign currency exchange fluctuations, DTE Energy has entered into a series of foreign currency exchange forward contracts through June 2022.

69

Summary of Sensitivity Analyses

Sensitivity analyses were performed on the fair values of commodity contracts for DTE Energy and long-term debt obligations for the Registrants. The commodity contracts listed below principally relate to energy marketing and trading activities. The sensitivity analyses involved increasing and decreasing forward prices and rates at June 30, 2018 and 2017 by a hypothetical 10% and calculating the resulting change in the fair values.

The results of the sensitivity analyses:

	Assuming a 10% Increase in Prices/Rates						Assuming a 10% Decrease in Prices/Rates
	As of June 30,						As of June 30,
Activity	2018			2017			2018			2017			Change in the Fair Value of
	(In millions)
Gas contracts	$	5		$	15		$	(5	)	$	(15	)	Commodity contracts
Power contracts	$	3		$	11		$	(7	)	$	(11	)	Commodity contracts
Interest rate risk — DTE Energy	$	(633	)	$	(529	)	$	608		$	521		Long-term debt
Interest rate risk — DTE Electric	$	(283	)	$	(226	)	$	306		$	242		Long-term debt

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

70

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, 2018, 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, 2018 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, 2018, 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, 2018 that have materially affected, or are reasonably likely to materially affect, DTE Electric's internal control over financial reporting.

71

Part II — Other Information

Item 1. Legal Proceedings

An FOV was issued by the EPA to DTE Electric in 2017 alleging violations related to exceedances of mercury emission limits for the Monroe Power Plant. DTE Electric is currently working with the EPA to address the alleged violations through a consent agreement. At this time, DTE Electric cannot predict the impact of the final settlement.

In March 2018, the Trenton Channel Power Plant experienced exceedances of its mercury emission limits. The exceedances were reported to the EPA and the MDEQ. DTE Electric is currently working with the EPA to address the exceedances. At this time, DTE Electric cannot predict the impact of the exceedances.

For more information on legal proceedings and matters related to the Registrants, see Notes 5 and 11 to the Consolidated Financial Statements, "Regulatory Matters" and "Commitments and Contingencies," respectively.

Item 1A. Risk Factors

There are various risks associated with the operations of the Registrants' businesses. To provide a framework to understand the operating environment of the Registrants, a brief explanation of the more significant risks associated with the Registrants' businesses is provided in Part 1, Item 1A. Risk Factors in DTE Energy's and DTE Electric's combined 2017 Annual Report on Form 10-K. Although the Registrants have tried to identify and discuss key risk factors, others could emerge in the future.

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

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

The following table provides information about DTE Energy purchases of equity securities that are registered by DTE Energy pursuant to Section 12 of the Exchange Act of 1934 for the quarter ended June 30, 2018:

	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
04/01/2018 — 04/30/2018	8,026	$	104.75	—	—	—
05/01/2018 — 05/31/2018	1,490	$	100.92	—	—	—
06/01/2018 — 06/30/2018	2,600	$	96.30	—	—	—
Total	12,116			—

_______________________________________

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

72

Item 6. Exhibits

Exhibit Number	Description	DTE Energy	DTE Electric
	(i) Exhibits filed herewith:
4.299	Supplemental Indenture dated as of May 1, 2018, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between DTE Electric Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (2018 Series A)	X	X
12.85	Computation of Ratio of Earnings to Fixed Charges	X
12.86	Computation of Ratio of Earnings to Fixed Charges		X
31.149	Chief Executive Officer Section 302 Form 10-Q Certification of Periodic Report	X
31.150	Chief Financial Officer Section 302 Form 10-Q Certification of Periodic Report	X
31.151	Chief Executive Officer Section 302 Form 10-Q Certification of Periodic Report		X
31.152	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:
32.149	Chief Executive Officer Section 906 Form 10-Q Certification of Periodic Report	X
32.150	Chief Financial Officer Section 906 Form 10-Q Certification of Periodic Report	X
32.151	Chief Executive Officer Section 906 Form 10-Q Certification of Periodic Report		X
32.152	Chief Financial Officer Section 906 Form 10-Q Certification of Periodic Report		X
	(iii) Exhibits incorporated by reference:
10.109	DTE Energy Company Long-Term Incentive Plan Amended and Restated Effective May 3, 2018 (Exhibit 4.3 to DTE Energy's Form S-8 filed on June 27, 2018)	X

73

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 25, 2018
			DTE ENERGY COMPANY
		By:	/S/ JEFFREY A. JEWELL
			Jeffrey A. Jewell Vice President, Controller, and Chief Accounting Officer
			(Duly Authorized Officer)
			DTE ELECTRIC COMPANY
		By:	/S/ JEFFREY A. JEWELL
			Jeffrey A. Jewell Vice President, Controller, and Chief Accounting Officer
			(Duly Authorized Officer)

74

EX-4.299

Exhibit 4.299

INDENTURE

DATED AS OF MAY 1, 2018

_______________

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,

2018 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 2018 Series A	11
Further Assurance	12
Authorization of Supplemental Indenture	12
Consideration for Supplemental Indenture	12
PART I. CREATION OF THREE HUNDRED SEVENTY EIGHTH SERIES OF BONDS, GENERAL AND REFUNDING MORTGAGE BONDS, 2018 SERIES A	13
Sec. 1. Terms of Bonds of 2018 Series A	13
Sec. 2. Redemption of Bonds of 2018 Series A	15
Sec. 3. Exchange and Transfer	17
Sec. 4. Form of Bonds of 2018 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 August 1, 2017	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 2018, 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, March 1, 2015, May 1, 2016 and August 1, 2017 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 Eighteen billion, two hundred twenty-eight million, fifty-seven thousand dollars ($18,228,057,000) have heretofore been issued under the indenture as follows, viz:

3

(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,
(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,
(23-31)	Bonds of Series DDP Nos. 1-9	— Principal Amount $14,305,000,
(32-45)	Bonds of Series FFR Nos. 1-14	— Principal Amount $45,600,000,
(46-67)	Bonds of Series GGP Nos. 1-22	— Principal Amount $42,300,000,
(68)	Bonds of Series HH	— Principal Amount $50,000,000,
(69-90)	Bonds of Series IIP Nos. 1-22	— Principal Amount $3,750,000,
(91-98)	Bonds of Series JJP Nos. 1-8	— Principal Amount $6,850,000,
(99-107)	Bonds of Series KKP Nos. 1-9	— Principal Amount $34,890,000,
(108-122)	Bonds of Series LLP Nos. 1-15	— Principal Amount $8,850,000,
(123-143)	Bonds of Series NNP Nos. 1-21	— Principal Amount $47,950,000,
(144-161)	Bonds of Series OOP Nos. 1-18	— Principal Amount $18,880,000,
(162-180)	Bonds of Series QQP Nos. 1-19	— Principal Amount $13,650,000,
(181-195)	Bonds of Series TTP Nos. 1-15	— Principal Amount $3,800,000,
(196)	Bonds of 1980 Series A	— Principal Amount $50,000,000,
(197-221)	Bonds of 1980 Series CP Nos. 1-25	— Principal Amount $35,000,000,
(222-232)	Bonds of 1980 Series DP Nos. 1-11	— Principal Amount $10,750,000,
(233-248)	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,
(254-255)	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,
(296-301)	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,
(346) (347)	Bonds of 1990 Series E Bonds of 2008 Series G	— Principal Amount $0, and — Principal Amount $300,000,000
	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;
(348)	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;
(349)	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;
(350)	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;
(351)	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;
(352)	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;
(353)	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;
(354)	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;
(355)	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;

8

(356)	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;
(357)	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;
(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;
(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;

9

(376) (377)	Bonds of 2016 Series A in in the principal amount of three hundred million dollars ($300,000,000) all of which are outstanding at the date hereof; and Bonds of 2017 Series B in the principal amount of four hundred forty million dollars  dollars ($440,000,000) all of which are outstanding at the date hereof.
	accordingly, the Company has issued and has presently outstanding Six billion sixty-five million, three hundred thousand dollars ($6,065,300,000) aggregate principal amount of its General and Refunding Mortgage Bonds (the “Bonds”) at the date hereof.
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 2018 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, 2018 Series A,” in the aggregate principal amount of five hundred twenty-five million dollars ($525,000,000), to be authenticated and delivered pursuant to Section 4 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-EIGHTH SERIES OF BONDS, GENERAL AND REFUNDING MORTGAGE BONDS, 2018 SERIES A
TERMS OF BONDS OF 2018 SERIES A.	SECTION 1. The Company hereby creates the three hundred seventy-eighth 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, 2018 Series A” (elsewhere herein referred to as the “bonds of 2018 Series A”). The aggregate principal amount of bonds of 2018 Series A shall be limited to five hundred twenty-five million dollars ($525,000,000), 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 2018 Series A, “reopen” the bonds of 2018 Series A, so long as any additional bonds of 2018 Series A have the same tenor and terms as the bonds of 2018 Series A established hereby.
	The bonds of 2018 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 2018 Series A shall be issued in the aggregate principal amount of $525,000,000, shall mature on May 15, 2048 (subject to earlier redemption) and shall bear interest, payable semi-annually on May 15 and November 15 of each year (commencing November 15, 2018), at the rate of four and five hundredths percent (4.05%) 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 2018 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 2018 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 2018 Series A shall be dated the date of its authentication and interest shall be payable on the principal represented thereby from the May 15 or November 15 next preceding the date to which interest has been paid on bonds of 2018 Series A, unless the bond is authenticated on a date prior to November 15, 2018 in which case interest shall be payable from May 7, 2018.

11

The bonds of 2018 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 2018 Series A). Until bonds of 2018 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 2018 Series A in temporary form, as provided in Section 10 of Article II of the Indenture. Temporary bonds of 2018 Series A if any, may be printed and may be issued in authorized denominations in substantially the form of definitive bonds of 2018 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 2018 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 2018 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 2018 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 2018 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 2018 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 2018 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 2018 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 2018 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.

12

REDEMPTION OF BONDS OF 2018 SERIES A.	SECTION 2. Bonds of 2018 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 the Par Call Date (as defined below), the optional redemption price will be equal to the greater of (i) 100% of the principal amount of the bonds of 2018 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 2018 Series A to be redeemed that would be due if the bonds of 2018 Series A matured on the Par Call Date (not including any portion of any payments of interest accrued to the redemption date), 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 15 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 the Par Call Date, the optional redemption price will be equal to 100% of the principal amount of the bonds of 2018 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 2018 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 2018 Series A (assuming, for this purpose, that the bonds of 2018 Series A mature on the Par Call Date) 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 such comparable maturity.
	“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.
	“Par Call Date” mean November 15, 2047.
	“Quotation Agent” means one of the Reference Treasury Dealers appointed by the Company.

13

	“Reference Treasury Dealer” means (i) each of Barclays Capital Inc., BNP Paribas Securities Corp., Merrill Lynch, Pierce, Fenner & Smith Incorporated and TD Securities (USA) LLC (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 2018 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 2018 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 2018 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 2018 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 2018 Series A (or such portion) designated for redemption has been duly provided for. Bonds of 2018 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 2018 Series A so to be redeemed) sufficient to redeem bonds of 2018 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 2018 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 2018 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 2018 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 2018 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 2018 Series A during any period of ten (10) days next preceding any redemption date for such bonds.
	Bonds of 2018 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 2018 SERIES A.	SECTION 4. The bonds of 2018 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

2018 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 May 15, 2048 (subject to earlier redemption) and interest thereon at the rate of 4.05% per annum, in like lawful money, from May 7, 2018 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 May 15 and November 15 of each year (commencing November 15, 2018), 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.

14

	“Reference Treasury Dealer” means (i) each of Barclays Capital Inc., BNP Paribas Securities Corp., Merrill Lynch, Pierce, Fenner & Smith Incorporated and TD Securities (USA) LLC (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 2018 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 2018 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 2018 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 2018 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 2018 Series A (or such portion) designated for redemption has been duly provided for. Bonds of 2018 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 2018 Series A so to be redeemed) sufficient to redeem bonds of 2018 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 2018 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 2018 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 2018 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 2018 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 2018 Series A during any period of ten (10) days next preceding any redemption date for such bonds.
	Bonds of 2018 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 2018 SERIES A.	SECTION 4. The bonds of 2018 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

2018 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 May 15, 2048 (subject to earlier redemption) and interest thereon at the rate of 4.05% per annum, in like lawful money, from May 7, 2018 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 May 15 and November 15 of each year (commencing November 15, 2018), 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 2018 Series A, limited to an aggregate principal amount of $525,000,000, 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, 2018) 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, 2018, 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.

15

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 the Par Call Date (as defined below), 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 that would be due if this bond matured on the Par Call Date (not including any portion of any payments of interest accrued to the redemption date), 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 [ ] 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 the Par Call Date, 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 (assuming, for this purpose, that this bond matures on the Par Call Date) 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 such comparable maturity.

“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.

“Par Call Date” means November 15, 2047.

“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., Merrill Lynch, Pierce, Fenner & Smith Incorporated and TD Securities (USA) LLC (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.

16

“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 2018 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.

17

		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:_______________________________

18

	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

19

SUPPLEMENTAL INDENTURE DATED AS OF	PURPOSE OF SUPPLEMENTAL INDENTURE	RECORDED AND/OR FILED AS SET FORTH IN SUPPLEMENTAL INDENTURE DATED AS OF
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

20

SUPPLEMENTAL INDENTURE DATED AS OF	PURPOSE OF SUPPLEMENTAL INDENTURE	RECORDED AND/OR FILED AS SET FORTH IN SUPPLEMENTAL INDENTURE DATED AS OF
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

21

SUPPLEMENTAL INDENTURE DATED AS OF	PURPOSE OF SUPPLEMENTAL INDENTURE	RECORDED AND/OR FILED AS SET FORTH IN SUPPLEMENTAL INDENTURE DATED AS OF
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

22

SUPPLEMENTAL INDENTURE DATED AS OF	PURPOSE OF SUPPLEMENTAL INDENTURE	RECORDED AND/OR FILED AS SET FORTH IN SUPPLEMENTAL INDENTURE DATED AS OF
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 March 1, 2015 May 1, 2016	2014 Series A and B Bonds 2014 Series D and E Bonds 2015 Series A Bonds 2016 Series A Bonds	July 1, 2014 March 1, 2015 May 1, 2016 August 1, 2017

(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.

23

RECORDING AND FILING OF SUPPLEMENTAL INDENTURE DATED AS OF AUGUST 1, 2017.	Further, pursuant to the terms and provisions of the Original Indenture, a Supplemental Indenture dated as of August 1, 2017 providing for the terms of bonds to be issued thereunder of 2017 Series B 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 August 9, 2017 (Filing No. 20170810000153-4), has been filed and recorded in the Office of the Surface Transportation Board on August 10, 2017 (Recordation No. 5485-NNNNNN), 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		9/5/17	201709050057905	34
Gratiot County Michigan		8/9/17	1008	135
Huron County Michigan		8/9/17	1611	166
Ingham County Michigan		8/9/17	2017-030104
Lapeer County Michigan		8/9/17	2910	420
Lenawee County Michigan		8/9/17	2549	770
Livingston County Michigan		8/9/17	2017R-023273
Macomb County Michigan		8/17/17	24892	82
Mason County Michigan		8/9/17	2017R04448	34
Midland County Michigan		8/9/17	1608	370
Monroe County Michigan		8/9/17	2017R16307
Montcalm County Michigan		8/9/17	2017R-08727
Oakland County Michigan		8/10/17	50953	834
St. Clair County Michigan		8/9/17	4856	629
Sanilac County Michigan		8/9/17	1344	893
Tuscola County Michigan		8/9/17	1379	816
Washtenaw County Michigan		8/11/17	5219	142
Wayne County Michigan		8/22/17	53900	831

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.

24

	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.

25

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:     Vice President, Corporate Secretary

and Chief of Staff

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

26

STATE OF MICHIGAN    )

) SS

COUNTY OF WAYNE    )

ACKNOWLEDG-MENT OF EXECUTION BY COMPANY.

On this 1st day of May, 2018, 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

27

EXECUTION BY	THE BANK OF NEW YORK MELLON TRUST
TRUSTEE.	COMPANY, N.A.
	By: /s/ Lawrence M. Kusch
(Corporate Seal)	Name:Lawrence M. Kusch
	Title: Vice President

Attest:

By: /s/ R. Tarnas

Name:    R. Tarnas

Title:    Vice President

Signed, sealed and delivered by

THE BANK OF NEW YORK MELLON

TRUST COMPANY, N.A.

in the presence of

/s/ Robert W. Hardy

Name: Robert W. Hardy

/s/ Emily Gigerich

Name: Emily Gigerich

28

STATE OF ILLINOIS    )

) SS

COUNTY OF COOK    )

ACKNOWLEDG-MENT OF EXECUTION BY TRUSTEE.

On this 2nd day of May, 2018, before me, the subscriber, a Notary Public within and for the County of Cook, in the State of Illinois, acting in the County of Cook, personally appeared Lawrence M. Kusch, to me personally known, who, being by me duly sworn, did say that his business office is located at 2 North LaSalle Street, Suite 700 Chicago, Illinois 60602, and he 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 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 Lawrence M. Kusch acknowledged said instrument to be the free act and deed of said corporation.

(Notarial Seal)

/s/ Colleen Sketch NAME: Colleen Sketch Notary Public, Cook County Illinois Acting in Cook County My Commission Expires: 5/20/2021

29

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 1st day of May, 2018

(Notarial Seal)        

/s/ Elizabeth Ellen Kochevar

Elizabeth Ellen Kochevar

Notary Public, Wayne County, MI

Acting in Wayne

My Commission Expires: November 16, 2021

30

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

31

EX-12.85

Exhibit 12.85

DTE Energy Company

Computation of Ratio of Earnings to Fixed Charges

	Six Months Ended			Year Ended December 31,
	June 30, 2018			2017			2016		2015			2014			2013
	(In millions)
Earnings:
Pretax earnings	$	674		$	1,287		$	1,105	$	950		$	1,275		$	922
Adjustments to earnings(a)	(19		)	(19		)	23		(3		)	(15		)	(26		)
Fixed charges	284			561			493		473			453			461
Net earnings	$	939		$	1,829		$	1,621	$	1,420		$	1,713		$	1,357
Fixed Charges:
Interest expense(b)	$	268		$	531		$	468	$	446		$	424		$	432
Adjustments to fixed charges(c)	16			30			25		27			29			29
Fixed charges	$	284		$	561		$	493	$	473		$	453		$	461
Ratio of earnings to fixed charges	3.31			3.26			3.29		3.00			3.78			2.94

_______________________________________

(a) Adjustments include the removal of the impact of earnings from non-consolidated entities and the inclusion of capitalized interest costs.

(b) Includes interest on uncertain positions.

(c) Adjustments include the interest element of rentals where determinable plus 1/3 of rental expense where no readily defined interest element can be determined and capitalized interest costs.

EX-12.86

Exhibit 12.86

DTE Electric Company

Computation of Ratio of Earnings to Fixed Charges

	Six Months Ended			Year Ended December 31,
	June 30, 2018			2017			2016			2015			2014			2013
	(In millions)
Earnings:
Pretax earnings	$	394		$	928		$	975		$	836		$	830		$	741
Adjustments to earnings(a)	(4		)	(9		)	(8		)	(11		)	(11		)	(7		)
Fixed charges	144			288			278			277			267			281
Net earnings	$	534		$	1,207		$	1,245		$	1,102		$	1,086		$	1,015
Fixed Charges:
Interest expense(b)	$	135		$	271		$	261		$	255		$	247		$	264
Adjustments to fixed charges(c)	9			17			17			22			20			17
Fixed charges	$	144		$	288		$	278		$	277		$	267		$	281
Ratio of earnings to fixed charges	3.71			4.19			4.48			3.98			4.07			3.61

_______________________________________

(a) Adjustments include the removal of the impact of earnings from non-consolidated entities and the inclusion of capitalized interest costs.

(b) Includes interest on uncertain positions.

(c) Adjustments include the interest element of rentals where determinable plus 1/3 of rental expense where no readily defined interest element can be determined and capitalized interest costs.

EX-31.149

Exhibit 31.149

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 25, 2018
Gerard M. Anderson Chairman of the Board and Chief Executive Officer of DTE Energy Company

EX-31.150

Exhibit 31.150

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 25, 2018
Peter B. Oleksiak Senior Vice President and Chief Financial Officer of DTE Energy Company

EX-31.151

Exhibit 31.151

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 25, 2018
Gerard M. Anderson  Chairman of the Board and Chief Executive Officer of DTE Electric Company

EX-31.152

Exhibit 31.152

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 25, 2018
Peter B. Oleksiak Senior Vice President and Chief Financial Officer of DTE Electric Company

EX-32.149

Exhibit 32.149

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, 2018, 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 25, 2018	/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-32.150

Exhibit 32.150

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, 2018, 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 25, 2018	/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-32.151

Exhibit 32.151

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, 2018, 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 25, 2018	/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-32.152

Exhibit 32.152

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, 2018, 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 25, 2018	/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, 2018 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, 2018
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Common Stock, Shares Outstanding	181,772,574
DTE Electric
Entity Registrant Name	DTE ELECTRIC CO
Entity Central Index Key	0000028385
Entity Filer Category	Non-accelerated Filer
Document Type	10-Q
Document Fiscal Period Focus	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, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Operating Revenues
Utility operations	$ 1,514	$ 1,423	$ 3,254	$ 3,141
Non-utility operations	1,645	1,432	3,658	2,950
Operating Revenues	3,159	2,855	6,912	6,091
Operating Expenses
Fuel, purchased power, and gas — utility	434	396	987	925
Fuel, purchased power, and gas — non-utility	1,443	1,248	3,216	2,428
Operation and maintenance	583	542	1,117	1,126
Depreciation and amortization	272	249	553	498
Taxes other than income	97	97	208	206
Asset (gains) losses and impairments, net	1	3	(2)	3
Operating Expenses	2,830	2,535	6,079	5,186
Operating Income	329	320	833	905
Other (Income) and Deductions
Interest expense	135	133	270	258
Interest income	(3)	(2)	(6)	(5)
Non-operating retirement benefits, net	9	17	18	33
Other income	(82)	(66)	(163)	(130)
Other expenses	15	6	40	13
Total Other (Income) and Deductions	74	88	159	169
Income Before Income Taxes	255	232	674	736
Income Tax Expense	19	57	87	167
Net Income	236	175	587	569
Less: Net Income (Loss) Attributable to Noncontrolling Interests	2	(2)	(8)	(8)
Net Income Attributable to DTE Energy Company/DTE Electric Company	$ 234	$ 177	$ 595	$ 577
Basic Earnings per Common Share
Net Income Attributable to DTE Energy Company (in dollars per share)	$ 1.29	$ 0.99	$ 3.29	$ 3.21
Diluted Earnings per Common Share
Net Income Attributable to DTE Energy Company (in dollars per share)	$ 1.29	$ 0.99	$ 3.29	$ 3.21
Weighted Average Common Shares Outstanding
Basic (in shares)	181	179	180	179
Diluted (in shares)	181	179	180	179
Dividends Declared per Common Share (in dollars per share)	$ 1.77	$ 1.65	$ 2.65	$ 2.48
DTE Electric
Operating Revenues
Utility operations	$ 1,276	$ 1,218	$ 2,481	$ 2,393
Operating Expenses
Fuel, purchased power, and gas — utility	386	355	725	669
Operation and maintenance	345	336	665	719
Depreciation and amortization	202	180	414	361
Taxes other than income	74	75	155	155
Operating Expenses	1,007	946	1,959	1,904
Operating Income	269	272	522	489
Other (Income) and Deductions
Interest expense	69	72	137	138
Other income	(22)	(17)	(49)	(36)
Other expenses	15	5	40	12
Total Other (Income) and Deductions	62	60	128	114
Income Before Income Taxes	207	212	394	375
Income Tax Expense	44	74	91	131
Net Income Attributable to DTE Energy Company/DTE Electric Company	$ 163	$ 138	$ 303	$ 244

XML

Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Net Income	$ 236	$ 175	$ 587	$ 569
Net Income	234	177	595	577
Other comprehensive income (loss), net of tax:
Benefit obligations, net of taxes of $1, $2, $2, and $4, respectively	3	3	5	7
Net unrealized gains on investments during the period, net of taxes of $—, respectively	0	1	0	1
Foreign currency translation	(1)	0	(1)	0
Other comprehensive income	2	4	4	8
Comprehensive income	238	179	591	577
Less: Comprehensive income (loss) attributable to noncontrolling interests	2	(2)	(8)	(8)
Comprehensive Income Attributable to DTE Energy Company/DTE Electric Company	236	181	599	585
DTE Electric
Net Income	163	138	303	244
Other comprehensive income (loss), net of tax:
Other comprehensive income	0	0	0	0
Comprehensive Income Attributable to DTE Energy Company/DTE Electric Company	$ 163	$ 138	$ 303	$ 244

XML

Consolidated Statements of Comprehensive Income (Unaudited) (Parentheticals) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Statement of Comprehensive Income [Abstract]
Tax effect on benefit obligation	$ 1	$ 2	$ 2	$ 4
Tax effect on net unrealized gains on investments during the period	$ 0	$ 0	$ 0	$ 0

XML

Consolidated Statements of Financial Position (Unaudited) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Current Assets
Cash and cash equivalents	$ 63	$ 66
Restricted cash	23	23
Accounts receivable (less allowance for doubtful accounts)
Customer	1,690	1,758
Other	147	98
Inventories
Fuel and gas	313	399
Materials and supplies	362	380
Derivative assets	78	103
Regulatory assets	57	55
Other	162	199
Total Current Assets	2,895	3,081
Investments
Nuclear decommissioning trust funds	1,484	1,492
Investments in equity method investees	1,326	1,073
Other	231	232
Total Investments	3,041	2,797
Property
Property, plant, and equipment	32,122	31,424
Accumulated depreciation and amortization	(10,883)	(10,703)
Property, plant, and equipment, net	21,239	20,721
Other Assets
Goodwill	2,293	2,293
Regulatory assets	3,729	3,723
Intangible assets	862	867
Notes receivable	69	73
Derivative assets	45	51
Prepaid postretirement costs	9	0
Other	148	161
Total Other Assets	7,155	7,168
Total Assets	34,330	33,767
Accounts payable
Accounts payable	1,059	1,171
Accrued interest	113	111
Dividends payable	321	158
Short-term borrowings	474	621
Current portion long-term debt, including capital leases	5	109
Derivative liabilities	43	99
Gas inventory equalization	37	0
Regulatory liabilities	39	18
Short-term borrowings
Other	408	525
Total Current Liabilities	2,499	2,812
Long-Term Debt (net of current portion)
Mortgage bonds, notes, and other	11,560	11,039
Junior subordinated debentures	1,145	1,145
Capital lease obligations	0	1
Total Long-Term Debt (net of current portion)	12,705	12,185
Other Liabilities
Deferred income taxes	1,936	1,888
Regulatory liabilities	3,038	2,875
Asset retirement obligations	2,394	2,320
Unamortized investment tax credit	142	122
Derivative liabilities	64	47
Accrued pension liability	727	924
Accrued postretirement liability	0	61
Nuclear decommissioning	219	220
Other	288	323
Total Other Liabilities	8,808	8,780
Commitments and Contingencies (Notes 5 and 11)
Equity
Common stock	4,205	3,989
Retained earnings	5,760	5,643
Accumulated other comprehensive income (loss)	(121)	(120)
Total DTE Energy/DTE Electric Company Equity	9,844	9,512
Noncontrolling interests	474	478
Total Equity	10,318	9,990
Total Liabilities and Equity	34,330	33,767
DTE Electric
Current Assets
Cash and cash equivalents	8	15
Accounts receivable (less allowance for doubtful accounts)
Customer	849	791
Affiliates	14	20
Other	71	37
Inventories
Fuel and gas	165	190
Materials and supplies	276	275
Regulatory assets	56	50
Other	70	68
Total Current Assets	1,509	1,446
Investments
Nuclear decommissioning trust funds	1,484	1,492
Other	35	36
Total Investments	1,519	1,528
Property
Property, plant, and equipment	23,410	22,972
Accumulated depreciation and amortization	(8,101)	(7,984)
Property, plant, and equipment, net	15,309	14,988
Other Assets
Regulatory assets	3,035	3,005
Intangible assets	31	25
Prepaid postretirement costs — affiliates	113	113
Other	115	123
Total Other Assets	3,294	3,266
Total Assets	21,631	21,228
Accounts payable
Affiliates	54	52
Other	339	416
Accrued interest	74	72
Accrued vacation	45	41
Current portion long-term debt, including capital leases	2	5
Regulatory liabilities	26	17
Short-term borrowings
Affiliates	75	116
Other	130	238
Other	75	104
Total Current Liabilities	820	1,061
Long-Term Debt (net of current portion)
Mortgage bonds, notes, and other	6,537	6,017
Capital lease obligations	0	1
Total Long-Term Debt (net of current portion)	6,537	6,018
Other Liabilities
Deferred income taxes	2,146	2,088
Regulatory liabilities	2,266	2,137
Asset retirement obligations	2,196	2,125
Unamortized investment tax credit	140	120
Nuclear decommissioning	219	220
Accrued pension liability — affiliates	629	811
Accrued postretirement liability — affiliates	264	311
Other	76	72
Total Other Liabilities	7,936	7,884
Commitments and Contingencies (Notes 5 and 11)
Equity
Common stock	4,306	4,306
Retained earnings	2,032	1,956
Accumulated other comprehensive income (loss)	0	3
Total DTE Energy/DTE Electric Company Equity	6,338	6,265
Total Liabilities and Equity	$ 21,631	$ 21,228

XML

Consolidated Statements of Financial Position (Unaudited) (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Allowance for doubtful accounts	$ 70	$ 49
Shareholder’s Equity
Common stock, shares authorized (in shares)	400,000,000	400,000,000
Common stock, shares issued (in shares)	181,772,574	179,386,967
Common stock, shares outstanding (in shares)	181,772,574	179,386,967
DTE Electric
Allowance for doubtful accounts	$ 38	$ 31
Shareholder’s Equity
Par value (in dollars per share)	$ 10	$ 10
Common stock, shares authorized (in shares)	400,000,000	400,000,000
Common stock, shares issued (in shares)	138,632,324	138,632,324
Common stock, shares outstanding (in shares)	138,632,324	138,632,324

XML

Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Operating Activities
Net Income	$ 587	$ 569
Net Income	595	577
Adjustments to reconcile Net Income to Net cash from operating activities:
Depreciation and amortization	553	498
Nuclear fuel amortization	25	24
Allowance for equity funds used during construction	(13)	(12)
Deferred income taxes	80	164
Equity earnings of equity method investees	(53)	(51)
Dividends from equity method investees	34	37
Asset (gains) losses and impairments, net	0	3
Changes in assets and liabilities:
Accounts receivable, net	20	49
Inventories	104	32
Prepaid postretirement benefit costs	(9)	0
Accounts payable	(34)	23
Gas inventory equalization	37	35
Accrued pension liability	(197)	(133)
Accrued postretirement liability	(61)	0
Derivative assets and liabilities	(8)	(123)
Regulatory assets and liabilities	230	216
Other current and noncurrent assets and liabilities	138	(148)
Net cash from operating activities	1,433	1,183
Investing Activities
Plant and equipment expenditures — utility	(1,027)	(968)
Plant and equipment expenditures — non-utility	(130)	(68)
Proceeds from sale of nuclear decommissioning trust fund assets	616	705
Investment in nuclear decommissioning trust funds	(613)	(688)
Distributions from equity method investees	5	7
Contributions to equity method investees	(233)	(175)
Other	2	(61)
Net cash used for investing activities	(1,380)	(1,248)
Financing Activities
Issuance of long-term debt, net of issuance costs	520	495
Redemption of long-term debt	(102)	(6)
Short-term borrowings, net	(147)	(79)
Issuance of common stock	6	0
Repurchase of common stock	0	(51)
Dividends on common stock	(309)	(296)
REF contributions from noncontrolling interests	22	21
Distributions to noncontrolling interests	(17)	(20)
Other	(29)	(28)
Net cash from (used for) financing activities	(56)	36
Net Decrease in Cash, Cash Equivalents, and Restricted Cash	(3)	(29)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	89	113
Cash, Cash Equivalents, and Restricted Cash at End of Period	86	84
Cash and Cash Equivalents at Beginning of Period	66
Cash and Cash Equivalents at End of Period	63
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	216	218
DTE Electric
Operating Activities
Net Income	303	244
Adjustments to reconcile Net Income to Net cash from operating activities:
Depreciation and amortization	414	361
Nuclear fuel amortization	25	24
Allowance for equity funds used during construction	(9)	(10)
Deferred income taxes	91	130
Changes in assets and liabilities:
Accounts receivable, net	(86)	(36)
Inventories	24	23
Accounts payable	(2)	(4)
Accrued pension liability — affiliates	(182)	(122)
Accrued postretirement liability — affiliates	(47)	2
Regulatory assets and liabilities	158	193
Other current and noncurrent assets and liabilities	(4)	(91)
Net cash from operating activities	685	714
Investing Activities
Plant and equipment expenditures	(825)	(737)
Proceeds from sale of nuclear decommissioning trust fund assets	616	705
Investment in nuclear decommissioning trust funds	(613)	(688)
Other	(4)	0
Net cash used for investing activities	(826)	(720)
Financing Activities
Issuance of long-term debt, net of issuance costs	520	0
Short-term borrowings, net — affiliate	(41)	(39)
Short-term borrowings, net — other	(108)	264
Dividends on common stock	(230)	(216)
Other	(7)	(7)
Net cash from (used for) financing activities	134	2
Net Decrease in Cash and Cash Equivalents	(7)	(4)
Cash and Cash Equivalents at Beginning of Period	15	13
Cash and Cash Equivalents at End of Period	8	9
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	$ 117	$ 133

XML

Consolidated Statements of Changes in Equity (Unaudited) - USD ($) $ in Millions	Total	Common Stock	Retained Earnings	Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interests	DTE Electric	DTE Electric Common Stock	DTE Electric Additional Paid-in Capital	DTE Electric Retained Earnings	DTE Electric Accumulated Other Comprehensive Income (Loss)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Implementation of ASU 2016-01	$ 0		$ 5	$ (5)		$ 0			$ 3	$ (3)
Beginning Balance (in shares) at Dec. 31, 2017	179,386,967	179,387,000				138,632,324	138,632,000
Beginning Balance at Dec. 31, 2017	$ 9,990	$ 3,989	5,643	(120)	$ 478
Beginning Balance at Dec. 31, 2017	9,512					$ 6,265	$ 1,386	$ 2,920	1,956	3
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net Income (Loss)	587		595		(8)
Net Income	595					303			303
Dividends declared on common stock	(481)		(481)			$ (230)			(230)
Issuance of common stock (in shares)		160,000
Issuance of common stock	16	$ 16
Contribution of common stock to pension plan (in shares)		1,751,000
Contribution of common stock to pension plan	175	$ 175
Benefit obligations, net of tax	5			5
Foreign currency translation	(1)			(1)
Stock-based compensation, net contributions from noncontrolling interests, and other (in shares)		475,000
Stock-based compensation, net contributions from noncontrolling interests, and other	$ 27	$ 25	(2)		4
Ending Balance (in shares) at Jun. 30, 2018	181,772,574	181,773,000				138,632,324	138,632,000
Ending Balance at Jun. 30, 2018	$ 10,318	$ 4,205	$ 5,760	$ (121)	$ 474
Ending Balance at Jun. 30, 2018	$ 9,844					$ 6,338	$ 1,386	$ 2,920	$ 2,032	$ 0

XML

Organization and Basis of Presentation

6 Months Ended

Jun. 30, 2018

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Organization and Basis of Presentation

ORGANIZATION AND BASIS OF PRESENTATION

Corporate Structure

DTE Energy owns the following businesses:

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

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

• Other businesses involved in 1) services related to the gathering, transportation, and storage of natural gas; 2) power and industrial projects; and 3) energy marketing and trading operations.

DTE Electric and DTE Gas are regulated by the MPSC. Certain activities of DTE Electric and DTE Gas, as well as various other aspects of businesses under DTE Energy, are regulated by the FERC. In addition, the Registrants are regulated by other federal and state regulatory agencies including the NRC, the EPA, the MDEQ, and for DTE Energy, the CFTC.

Basis of Presentation

The Consolidated Financial Statements should be read in conjunction with the Combined Notes to Consolidated Financial Statements included in the combined DTE Energy and DTE Electric 2017 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, 2018.

The information in these combined notes relates to each of the Registrants as noted in the Index of Combined Notes to Consolidated Financial Statements. However, DTE Electric does not make any representation as to information related solely to DTE Energy or the subsidiaries of DTE Energy other than itself.

Certain prior year balances for DTE Energy were reclassified to match the current year's Consolidated Financial Statements presentation.

Due to the implementation of ASU 2017-07, amounts previously included in Operation and maintenance were reclassified to Non-operating retirement benefits, net on the Consolidated Statements of Operations. See Note 3 to the Consolidated Financial Statements, "New Accounting Pronouncements."

The Dividends Declared per Common Share for the three and six months ended June 30, 2017 on DTE Energy’s Consolidated Statements of Operations were revised to reflect two dividend declarations in the second quarter of 2017, or $1.65 and $2.48 per share, for the three and six month periods, respectively.  The financial statements previously reflected one dividend declaration of $0.83 and $1.65 per share for the three and six-months period ended June 30, 2017, respectively.  This revision was not material to DTE Energy's Consolidated Financial Statements.

Principles of Consolidation

The Registrants consolidate all majority-owned subsidiaries and investments in entities in which they have controlling influence. Non-majority owned investments are accounted for using the equity method when the Registrants are able to significantly influence the operating policies of the investee. When the Registrants do not influence the operating policies of an investee, the cost method is used. These Consolidated Financial Statements also reflect the Registrants' proportionate interests in certain jointly-owned utility plants. The Registrants eliminate all intercompany balances and transactions.

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

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

DTE Energy owns a 55% interest in SGG, which owns and operates midstream natural gas assets. SGG has contracts through which certain construction risk is designed to pass-through to the customers, with DTE Energy retaining operational and customer default risk. SGG is a VIE with DTE Energy as the primary beneficiary.

The Registrants have variable interests in NEXUS, which include DTE Energy's 50% ownership interest and DTE Electric's transportation services contract. NEXUS is a joint venture which is in the process of constructing a 255-mile pipeline to transport Utica and Marcellus shale gas to Ohio, Michigan, and Ontario market centers. NEXUS is a VIE as it has insufficient equity at risk to finance its activities. The Registrants are not the primary beneficiaries, as the power to direct significant activities is shared between the owners of the equity interests. DTE Energy accounts for its ownership interest in NEXUS under the equity method.

The Registrants hold ownership interests in certain limited partnerships. The limited partnerships include investment funds which support regional development and economic growth, as well as an operational business providing energy-related products. These entities are generally VIEs as a result of certain characteristics of the limited partnership voting rights. The ownership interests are accounted for under the equity method as the Registrants are not the primary beneficiaries.

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

The maximum risk exposure for consolidated VIEs is reflected on the Registrants' Consolidated Statements of Financial Position and in Note 11 to the Consolidated Financial Statements, "Commitments and Contingencies," related to the REF guarantees and indemnities. For non-consolidated VIEs, the maximum risk exposure of the Registrants is generally limited to their investment, notes receivable, future funding commitments, and amounts which DTE Energy has guaranteed. See Note 11 to the Consolidated Financial Statements, "Commitments and Contingencies," for further discussion of the NEXUS guarantee arrangements.

The following table summarizes the major Consolidated Statements of Financial Position items for consolidated VIEs as of June 30, 2018 and December 31, 2017. 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.

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

	June 30, 2018						December 31, 2017
	SGG(a)		Other		Total		SGG(a)		Other		Total
	(In millions)
ASSETS
Cash and cash equivalents	$	28	$	16	$	44	$	23	$	14	$	37
Restricted cash	—		8		8		—		8		8
Accounts receivable	10		32		42		11		42		53
Inventories	3		67		70		3		114		117
Property, plant, and equipment, net	389		68		457		400		75		475
Goodwill	25		—		25		25		—		25
Intangible assets	564		—		564		572		—		572
Other current and long-term assets	2		1		3		4		—		4
	$	1,021	$	192	$	1,213	$	1,038	$	253	$	1,291
LIABILITIES
Accounts payable and accrued current liabilities	$	5	$	32	$	37	$	26	$	47	$	73
Current portion long-term debt, including capital leases	—		3		3		—		4		4
Mortgage bonds, notes, and other	—		—		—		—		1		1
Other current and long-term liabilities	7		15		22		1		16		17
	$	12	$	50	$	62	$	27	$	68	$	95

_____________________________________

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

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

	June 30, 2018		December 31, 2017
	(In millions)
Investments in equity method investees	$	1,028	$	811
Notes receivable	$	18	$	17
Future funding commitments	$	416	$	598

XML

Significant Accounting Policies

6 Months Ended

Jun. 30, 2018

Accounting Policies [Abstract]

Significant Accounting Policies

SIGNIFICANT ACCOUNTING POLICIES

Other Income

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(In millions)
Equity earnings of equity method investees	$	32	$	25	$	53	$	51
Income from REF entities	25		22		48		40
Contract services	12		4		32		8
Allowance for equity funds used during construction	6		5		13		12
Gains from equity securities	1		5		1		13
Other	6		5		16		6
	$	82	$	66	$	163	$	130

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(In millions)
Contract services	$	13	$	5	$	33	$	9
Allowance for equity funds used during construction	4		4		9		10
Gains from equity securities allocated from DTE Energy	1		5		1		13
Other	4		3		6		4
	$	22	$	17	$	49	$	36

Changes in Accumulated Other Comprehensive Income (Loss)

For the three and six months endedJune 30, 2018 and 2017, 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. For further discussion regarding changes in Accumulated other comprehensive income (loss), see Note 3 to the Consolidated Financial Statements, "New Accounting Pronouncements."

Income Taxes

The 2018 estimated annual effective tax rates for DTE Energy and DTE Electric are 12% and 22%, respectively. These tax rates are affected by estimated annual permanent items, including AFUDC equity, production tax credits, and other flow-through items, as well as discrete items that may occur in any given period, but are not consistent from period to period.

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

	Effective Tax Rate
	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
DTE Energy	7	%	25	%	13	%	23	%
DTE Electric	21	%	35	%	23	%	35	%

The 18%decrease and the 10%decrease in DTE Energy's effective tax rate for the three and six months endedJune 30, 2018 and 2017, respectively, was primarily due to the reduction of the corporate tax rate from 35% to 21%, which became effective in 2018. The decrease in the effective tax rate for the three months ended June 30, 2018 was also impacted by an increase in annual production tax credits of 4%. The decrease in the effective tax rate for the six months ended June 30, 2018 was partially offset by true-up adjustments to the remeasurement of deferred taxes in 2018 of $21 million, which increased the effective tax rate by 3%, and the reduction of excess tax benefits on stock-based compensation of $11 million, which increased the effective tax rate by 1%. For further discussion regarding the true-up adjustments, see Note 3 to the Consolidated Financial Statements, "New Accounting Pronouncements."

The 14%decrease and the 12%decrease in DTE Electric's effective tax rate for the three and six months endedJune 30, 2018 and 2017, respectively, was primarily due to the reduction of the corporate tax rate from 35% to 21%, which became effective in 2018. The decrease in the effective tax rate for the six months ended June 30, 2018 was partially offset by true-up adjustments to the remeasurement of deferred taxes in 2018 of $8 million, which increased the effective tax rate by 2%.

DTE Energy's total amount of unrecognized tax benefits as of June 30, 2018 was $8 million, which if recognized, would favorably impact its effective tax rate. DTE Electric's total amount of unrecognized tax benefits as of June 30, 2018 was $10 million, which if recognized, would favorably impact its effective tax rate. The Registrants do not anticipate any material changes to the unrecognized tax benefits in the next twelve months.

DTE Electric had income tax receivables with DTE Energy of $12 million at June 30, 2018 and December 31, 2017.

Unrecognized Compensation Costs

As of June 30, 2018, DTE Energy had $98 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 1.52 years.

Allocated Stock-Based Compensation

DTE Electric received an allocation of costs from DTE Energy associated with stock-based compensation of $8 million and $10 million for the three months ended June 30, 2018 and 2017, respectively, while such allocation was $17 million and $18 million for the six months ended June 30, 2018 and 2017, respectively.

Cash, Cash Equivalents, and Restricted Cash

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

The following is a table that provides a reconciliation of DTE Energy's Cash and cash equivalents as well as Restricted cash reported within the Consolidated Statements of Financial Position that sum to the total of the same such amounts shown in the Consolidated Statements of Cash Flows:

	June 30,		December 31,
	2018		2017
	(In millions)
Cash and cash equivalents	$	63	$	66
Restricted cash	23		23
Total cash, cash equivalents, and restricted cash shown in the Consolidated Statements of Cash Flows	$	86	$	89

XML

New Accounting Pronouncements

6 Months Ended

Jun. 30, 2018

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New Accounting Pronouncements

NEW ACCOUNTING PRONOUNCEMENTS

Recently Adopted 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 required 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 to be applied retrospectively. The Registrants adopted the standard effective January 1, 2018, using the modified retrospective approach. Under the modified retrospective approach, the information for periods prior to the adoption date has not been restated and continues to be reported under the accounting standards in effect for those periods. As permitted under the standard, the Registrants have elected to apply the guidance only to those contracts that were not completed at January 1, 2018, and have elected not to restate the impacts of any contract modifications made prior to the earliest period presented.

The adoption of the ASU did not have a significant impact on the Registrants' financial position or results of operations, but required additional disclosures for revenue. See Note 4 to the Consolidated Financial Statements, "Revenue."

In March 2017, the FASB issued ASU No. 2017-07, Compensation — Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. The amendments in this update required that an employer report the service cost component in the same line item or items as other compensation costs arising from services rendered by the pertinent employees during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside of income from operations. The amendments in this update also allow only the service cost component to be eligible for capitalization when applicable. The Registrants adopted the standard effective January 1, 2018. The standard has been applied retrospectively for the presentation of the service cost component and the other components of net periodic pension cost and net periodic postretirement benefit cost in the income statement and prospectively for the capitalization of the service cost component of net periodic pension cost and net periodic postretirement benefit in assets. As permitted by the standard, the Registrants have used benefit cost amounts disclosed for prior periods as the basis for retrospective application in the income statement. As a result of regulatory mechanisms, the impact to the Consolidated Financial Statements was not material for the three and six months endedJune 30, 2018.

In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments — Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities, as amended. The new guidance is intended to improve the recognition and measurement of financial instruments. The guidance 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. The guidance requires equity investments to be generally measured at fair value, with subsequent changes in fair value recognized in net income. The guidance requires entities 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. The Registrants adopted the standard effective January 1, 2018. Upon adoption, DTE Energy and DTE Electric recorded a cumulative-effect adjustment to reclassify $5 million and $3 million of unrealized gains from Accumulated other comprehensive income (loss) to Retained earnings, respectively.

In March 2018, the FASB issued ASU No. 2018-05, Income Taxes (Topic 740): Amendments to SEC paragraphs pursuant to SEC Staff Accounting Bulletin No. 118. The Amendments in this update add various SEC paragraphs pursuant to the issuance of SEC Staff Accounting Bulletin No. 118, Income Tax Accounting Implications of the Tax Cuts and Jobs Act (SAB 118). SAB 118 directs taxpayers to consider the implications of the TCJA as provisional when it does not have the necessary information available, prepared, or analyzed in reasonable detail to complete its accounting for the change in the tax law. As described in Note 10 to the Consolidated Financial Statements, "Income Taxes," within the combined DTE Energy and DTE Electric 2017 Annual Report on Form 10-K and in accordance with SAB 118, the Registrants recorded amounts that were considered provisional. During the six months endedJune 30, 2018, DTE Energy and DTE Electric recorded true-up adjustments to the remeasurement of deferred taxes of $21 million and $8 million, respectively. The impact of the true-up adjustments was an increase in Income Tax Expense, of which $16 million was attributable to the regulated utilities and offset to Regulatory liabilities.The true-up adjustments were a result of further analysis for items subject to further consideration at December 31, 2017, under SAB 118 and primarily related to timing differences not recoverable from DTE Electric and DTE Gas customers. The Registrants will continue to analyze the amounts throughout 2018, which may result in additional changes.

Recently Issued Pronouncements

In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842), as amended. This guidance requires a lessee to account for leases as finance or operating leases, and disclose key information about leasing arrangements. Both types of leases will result in the lessee recognizing a right-of-use asset and a corresponding lease liability on its balance sheet, with differing methodology for income statement recognition, depending on the lease classification. The Registrants will adopt the standard on January 1, 2019. As originally issued, the standard requires a modified retrospective approach for leases existing or entered into after the beginning of the earliest comparative period in the Consolidated Financial Statements. The Registrants expect to elect the package of practical expedients allowing entities to not reassess whether an agreement is a lease, to carryforward the existing lease classification, and to not reassess initial direct costs associated with existing leases. The Registrants also plan to elect the practical expedient allowing entities to not evaluate land easements under the new guidance at adoption if they were not previously accounted for as leases.

A third-party software tool is being implemented that will assist with the initial adoption and ongoing compliance of the standard. The Registrants are compiling lease contracts and abstracting the required data, as well as evaluating new business processes, internal controls, and accounting policies. In addition, the Registrants are monitoring utility industry implementation issues for purchase power agreements, pipeline laterals, and other industry specific arrangements. While the Registrants expect an increase in assets and liabilities, as well as additional disclosures, they are still assessing the impact of this ASU on their Consolidated Financial Statements.

In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments — Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments. The amendments in this update replace the incurred loss impairment methodology in current generally accepted accounting principles with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates. Entities will apply the new guidance as a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is adopted. The ASU is effective for the Registrants beginning after December 15, 2019, and interim periods therein. Early adoption is permitted. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements.

In February 2018, the FASB issued ASU No. 2018-02, Income Statement — Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income. The amendments in this update allow a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the TCJA. The amendments in this update also require entities to disclose their accounting policy for releasing income tax effects from accumulated other comprehensive income. The ASU is effective for the Registrants for fiscal years beginning after December 15, 2018, and interim periods therein. Early adoption is permitted. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements.

XML

Revenue

6 Months Ended

Jun. 30, 2018

Revenue from Contract with Customer [Abstract]

Revenue

REVENUE

Significant Accounting Policy

Upon the adoption of Topic 606, revenue is measured based upon the consideration specified in a contract with a customer at the time when performance obligations are satisfied. Under Topic 606, a performance obligation is a promise in a contract to transfer a distinct good or service or a series of distinct goods or services to the customer. The Registrants recognize revenue when performance obligations are satisfied by transferring control over a product or service to a customer. The Registrants have determined control to be transferred when the product is delivered or the service is provided to the customer. For the three and six months endedJune 30, 2018, recognition of revenue for the Registrants subsequent to the adoption of Topic 606 is substantially similar in amount and approach to that prior to adoption.

Rates for DTE Electric and DTE Gas include provisions to adjust billings for fluctuations in fuel and purchased power costs, cost of natural gas, and certain other costs. Revenues are adjusted for differences between actual costs subject to reconciliation and the amounts billed in current rates. Under or over recovered revenues related to these cost recovery mechanisms are included in Regulatory assets or liabilities on the Registrants' Consolidated Statements of Financial Position and are recovered or returned to customers through adjustments to the billing factors.

For discussion of derivative contracts, see Note 8 to the Consolidated Financial Statements, "Financial and Other Derivative Instruments."

Disaggregation of Revenue

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

	Three Months Ended June 30,		Six Months Ended June 30,
	2018		2018
	(In millions)
Electric(a)
Residential	$	584	$	1,170
Commercial	446		875
Industrial	178		354
Other(b)	68		82
Total Electric operating revenues(c)	$	1,276	$	2,481
Gas
Gas sales	$	180	$	637
End User Transportation	49		134
Intermediate Transportation	11		29
Other(d)	15		5
Total Gas operating revenues(e)	$	255	$	805
Other segment operating revenues(f)
Gas Storage and Pipelines	$	122	$	241
Power and Industrial Projects	$	538	$	1,105
Energy Trading	$	1,164	$	2,662

_______________________________________

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

(b) Includes decreases of $38 million and $77 million to revenues related to TCJA rate reduction reserves for the three and six months endedJune 30, 2018, respectively.

(c) Includes $4 million and $9 million of other revenues which are outside the scope of Topic 606 for the three and six months endedJune 30, 2018, respectively.

(d) Includes an increase of $5 million and a decrease of $27 million to revenues related to TCJA rate reduction reserves for the three and six months endedJune 30, 2018, respectively.

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

(f) Includes revenues outside the scope of Topic 606 primarily related to $399 million and $844 million of contracts accounted for as leases at the Power and Industrial Projects segment for the three and six months endedJune 30, 2018, respectively, and $937 million and $2.1 billion related to derivatives at the Energy Trading segment for the three and six months endedJune 30, 2018, respectively.

Nature of Goods and Services

The following is a description of principal activities, separated by reportable segments, from which DTE Energy generates revenue. For more detailed information about reportable segments, see Note 13 to the Consolidated Financial Statements, “Segment and Related Information.”

The Registrants have contracts with customers which may contain more than one performance obligation. When more than one performance obligation exists in a contract, the consideration under the contract is allocated to the performance obligations based on the relative standalone selling price. DTE Energy generally determines standalone selling prices based on the prices charged to customers or the use of the adjusted market assessment approach. The adjusted market assessment approach involves the evaluation of the market in which DTE Energy sells goods or services and estimating the price that a customer in that market would be willing to pay.

Under Topic 606, when a customer simultaneously receives and consumes the product or service provided, revenue is considered to be recognized over time. Alternatively, if it is determined that the criteria for recognition of revenue over time is not met, the revenue is considered to be recognized at a point in time.

Electric

Electric consists principally of DTE Electric. Electric revenues are primarily comprised of the supply and delivery of electricity, and related capacity. Revenues are primarily associated with cancelable contracts, with the exception of certain long-term contracts with commercial and industrial customers. Revenues, including estimated unbilled amounts, are generally recognized over time based upon volumes delivered or through the passage of time ratably based upon providing a stand-ready service. The Registrants have determined that the above methods represent a faithful depiction of the transfer of control to the customer. Unbilled revenues are typically determined utilizing approved tariff rates and estimated meter volumes. Estimated unbilled amounts recognized in revenue are subject to adjustment in the following reporting period as actual volumes by customer class are known. Revenues are typically subject to tariff rates based upon customer class and type of service, and are billed and received monthly. Tariff rates are determined by the MPSC on a per unit or monthly basis.

Gas

Gas consists principally of DTE Gas. Gas revenues are primarily comprised of the supply and delivery of natural gas, and other services including storage, transportation, and appliance maintenance. Revenues are primarily associated with cancelable contracts with the exception of certain long-term contracts with commercial and industrial customers. Revenues, including estimated unbilled amounts, are generally recognized over time based upon volumes delivered or through the passage of time ratably based upon providing a stand-ready service. DTE Energy has determined that the above methods represent a faithful depiction of the transfer of control to the customer. Unbilled revenues are typically determined using both estimated meter volumes and estimated usage based upon the number of unbilled days and historical temperatures. Estimated unbilled amounts recognized in revenue are subject to adjustment in the following reporting period as actual volumes by customer class and service type are known. Revenues are typically subject to tariff rates or other rates subject to regulatory oversight and are billed and received monthly. Tariff rates are determined by the MPSC on a per unit or monthly basis.

Gas Storage and Pipelines

Gas Storage and Pipelines revenues generally consist of services related to the gathering, transportation, and storage of natural gas. Contracts are primarily long-term in nature. Revenues, including estimated unbilled amounts, are generally recognized over time based upon services provided or through the passage of time ratably based upon providing a stand-ready service. DTE Energy has determined that the above methods represent a faithful depiction of the transfer of control to the customer. Revenues are typically billed and received monthly. Pricing for such revenues may consist of demand rates, commodity rates, transportation rates, and other associated fees. Consideration may consist of both fixed and variable components. Generally, uncertainties in the variable consideration components are resolved and revenues are known at the time of recognition.

Power and Industrial Projects

Power and Industrial Projects revenues consist primarily of contracts accounted for as leases which are outside of the scope of Topic 606. For performance obligations within the scope of Topic 606, the timing of revenue recognition is dependent upon when control over the associated product or service is transferred.

Revenues at Power and Industrial Projects, within the scope of Topic 606, generally consist of sales of blast furnace coke and coke oven gas, electricity, equipment maintenance services, and other energy related products and services. Revenues, including estimated unbilled amounts, for the sale of blast furnace coke are generally recognized at a point in time when the product is delivered, which represents the transfer of control to the customer. Other revenues are generally recognized over time based upon services provided or through the passage of time ratably based upon providing a stand-ready service. DTE Energy has determined that the above methods represent a faithful depiction of the transfer of control to the customer. Market based pricing structures exist in such contracts including adjustments for consumer price or other indices. Consideration may consist of both fixed and variable components. Generally, uncertainties in the variable consideration components are resolved and revenues are known at the time of recognition. Billing terms vary and are generally monthly with payment terms typically within 30 days following billing.

Energy Trading

Energy Trading revenues consist primarily of derivative contracts outside of the scope of Topic 606. For performance obligations within the scope of Topic 606, the timing of revenue recognition is dependent upon when control over the associated product or service is transferred.

Revenues, including estimated unbilled amounts, within the scope of Topic 606 arising from the sale of natural gas, electricity, power capacity, and other energy related products are generally recognized over time based upon volumes delivered or through the passage of time ratably based upon providing a stand-ready service. DTE Energy has determined that the above methods represent a faithful depiction of the transfer of control to the customer. Revenues are known at the time of recognition. Payment for the aforementioned revenues is generally due from customers in the month following delivery.

Revenues associated with RECs are recognized at a point in time when control of the RECs are transferred to the customer which is deemed to be when the subject RECs are entered for transfer to the customer in the applicable regulatory tracking system. Revenues associated with RECs under a wholesale full requirements power contract are deferred until control has been transferred. The deferred revenues represent a contract liability for which payment has been received and the amounts have been estimated using the adjusted market assessment approach. With the exception of RECs, generally all other performance obligations associated with wholesale full requirements power contracts are satisfied over time in conjunction with the delivery of power. At the time power is delivered, DTE Energy may not have control over the RECs as the RECs are not self-generated and may not yet have been procured resulting in deferred revenues.

Deferred Revenue

The following is a summary of deferred revenue activity:

	DTE Energy
	(In millions)
Beginning Balance, January 1, 2018	$	56
Increases due to cash received or receivable, excluding amounts recognized as revenue during the period	29
Revenue recognized that was included in the deferred revenue balance at the beginning of the period	(18		)
Ending Balance, June 30, 2018	$	67

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

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

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

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

	DTE Energy
	(In millions)
2018	$	27
2019	14
2020	2
2021	4
2022	7
2023 and thereafter	13
	$	67

Transaction Price Allocated to the Remaining Performance Obligations

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

Such contracts consist of varying types of performance obligations across the segments, including the supply and delivery of energy related products and services. Contracts with variable volumes and/or variable pricing, including those with pricing provisions tied to a consumer price or other index, have also been excluded as the related consideration under the contract is variable at inception of the contract. Contract lengths vary from cancelable to multi-year.

The Registrants expect to recognize revenue for the following amounts related to fixed consideration associated with remaining performance obligations in each of the future periods noted:

	DTE Energy		DTE Electric
	(In millions)
2018	$	102	$	5
2019	251		8
2020	178		—
2021	135		—
2022	106		—
2023 and thereafter	351		—
Total	$	1,123	$	13

Other Matters

DTE Energy has recognized charges of $31 million and $56 million related to expense recognized for estimated uncollectible accounts receivable for the three and six months endedJune 30, 2018, respectively. DTE Electric has recognized charges of $17 million and $31 million related to expense recognized for estimated uncollectible accounts receivable for the three and six months endedJune 30, 2018, respectively.

XML

Regulatory Matters

6 Months Ended

Jun. 30, 2018

Public Utilities, General Disclosures [Abstract]

Regulatory Matters

REGULATORY MATTERS

2017 Electric Rate Case Filing

DTE Electric filed a rate case with the MPSC on April 19, 2017 requesting an increase in base rates of $231 million based on a projected twelve-month period ending October 31, 2018. On November 1, 2017, DTE Electric self-implemented a base rate increase of $125 million. On April 18, 2018, the MPSC issued an order approving an annual revenue increase of $65.2 million for service rendered on or after May 1, 2018. The MPSC authorized a return on equity of 10.0%. On June 28, 2018, the MPSC issued an order on a rehearing granting in part and denying in part, petitions for rehearings of DTE Electric and other intervenors. As a result, the approved addition to base rates increased from $65.2 million to $74.4 million. DTE Electric has recorded a refund liability of $25 million, representing the total estimated refund due to customers, inclusive of interest, at June 30, 2018. In August 2018, DTE Electric will file to refund its customers based on their pro rata share of the revenue collected through the self-implementation surcharge in effect from November 1, 2017 to May 1, 2018.

2018 Electric Rate Case Filing

DTE Electric filed a rate case with the MPSC on July 6, 2018 requesting an increase in base rates of $328 million based on a projected twelve-month period ending April 30, 2020. The requested increase in base rates is primarily due to an increase in net plant resulting from infrastructure investments, depreciation expense, as requested in the 2016 DTE Main Electric Depreciation Case Filing, and reliability improvement projects. The rate filing also requests an increase in return on equity from 10.0% to 10.5% and includes projected changes in sales, operation and maintenance expenses, and working capital. In addition, the rate filing requests an Infrastructure Recovery Mechanism to recover the incremental revenue requirement associated with certain distribution, fossil generation, and nuclear generation capital expenditures through 2022. Finally, as noted in the 2017 Tax Reform section below, DTE Electric addressed Calculation C in this filing. A final MPSC order in this case is expected by May 2019.

Certificate of Necessity

On July 31, 2017, DTE Electric filed a request for authority to build a 1,100 megawatt natural gas fueled combined cycle generation facility at DTE Electric's Belle River Power Plant. DTE Electric requested the MPSC to issue three CONs for the following: (1) power supplied by the proposed project is needed, (2) the size, fuel type, and other design characteristics of the proposed project represent the most reasonable and prudent means of meeting the power need, and (3) the estimated capital costs of $989 million for the proposed project will be recoverable in rates from DTE Electric's customers. The MPSC issued an order on April 27, 2018 approving DTE Electric's request for the three CONs with recoverable amounts through rates up to $951.8 million.

2017 Gas Rate Case Filing

DTE Gas filed a rate case with the MPSC on November 22, 2017 requesting an increase in base rates of $85.1 million based on a projected twelve-month period ending September 30, 2019. The requested increase in base rates is primarily due to an increase in net plant. The rate filing also requests an increase in return on equity from 10.1% to 10.5% and includes projected changes in sales, operations and maintenance expenses, and working capital. On May 24, 2018, DTE Gas reduced its initial requested increase in base rates to $38.1 million, primarily due to the effects of the TCJA on the original request. To mitigate the impact to its customers resulting from ASU No. 2017-07, Compensation — Retirement Benefits (Topic 715), DTE Gas suggested regulatory accounting treatment, consistent with the methodology approved by the MPSC in the 2017 DTE Electric Rate Case order. As such, beginning January 1, 2018, pension and postretirement cost components previously included as capital overhead are being deferred. For further discussion of ASU No. 2017-07, see Note 3 to the Consolidated Financial Statements, "New Accounting Pronouncements." A final MPSC order in this case is expected by September 2018.

2017 Tax Reform

On December 27, 2017, the MPSC issued an order to consider changes in the rates of all Michigan rate-regulated utilities to reflect the effects of the federal TCJA. On January 19, 2018, DTE Electric and DTE Gas filed information with the MPSC regarding the potential change in revenue requirements due to the TCJA effective January 1, 2018, and outlined their recommended method to flow the current and deferred tax benefits of those impacts to ratepayers.

On February 22, 2018, the MPSC issued an order in this case requiring utilities, including DTE Electric and DTE Gas, to follow a 3-step approach of credits and calculations. The first step is to establish Credit A, through contested cases. Credit A is a going-forward tax credit to reflect the reduction of the corporate tax rate from 35% to 21%. DTE Gas submitted its Credit A filing on March 28, 2018, reflecting a reduction in revenues of $38.2 million. The MPSC approved the $38.2 million reduction on May 30, 2018, to be effective July 1, 2018. DTE Electric filed its Credit A application on May 18, 2018, reflecting a reduction in revenues of $157 million. On July 24, 2018, the MPSC issued an order approving a settlement in DTE Electric's Credit A filing reflecting a reduction in revenues of $157 million. Rates reflecting this reduction will be effective August 1, 2018. The second step is to establish Credit B, through contested cases. Credit B is a backward-looking tax credit to reflect the reduction of the corporate rate of 35% to 21%, for the period January 1, 2018 through the date Credit A is established. The Credit B filing is required within sixty days after Credit A is implemented. For Credit B, DTE Electric and DTE Gas have been deferring the impact of the reduction to the corporate tax rate since January 1, 2018. The third step is to perform Calculation C, through contested cases. Calculation C will address all remaining issues relative to the new tax law, which is primarily the remeasurement of deferred taxes and how the amounts deferred as Regulatory liabilities will flow to ratepayers. DTE Gas is required to file Calculation C no later than October 1, 2018. DTE Electric addressed Calculation C in its general rate case filed July 6, 2018.

XML

Earnings Per Share

6 Months Ended

Jun. 30, 2018

Earnings Per Share [Abstract]

Earnings Per Share

EARNINGS PER SHARE

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

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(In millions, except per share amounts)
Basic Earnings per Share
Net Income Attributable to DTE Energy Company	$	234	$	177	$	595	$	577
Less: Allocation of earnings to net restricted stock awards	—		—		1		1
Net income available to common shareholders — basic	$	234	$	177	$	594	$	576
Average number of common shares outstanding — basic	181		179		180		179
Basic Earnings per Common Share	$	1.29	$	0.99	$	3.29	$	3.21
Diluted Earnings per Share
Net Income Attributable to DTE Energy Company	$	234	$	177	$	595	$	577
Less: Allocation of earnings to net restricted stock awards	—		—		1		1
Net income available to common shareholders — diluted	$	234	$	177	$	594	$	576
Average number of common shares outstanding — diluted	181		179		180		179
Diluted Earnings per Common Share(a)	$	1.29	$	0.99	$	3.29	$	3.21

_______________________________________

(a) The 2016 Equity Units excluded from the calculation of diluted EPS were approximately 6.6 million and 6.3 million for the three months ended June 30, 2018 and 2017, respectively, and 6.6 million for the six months endedJune 30, 2018 and 2017, as the dilutive stock price threshold was not met.

XML

Fair Value

6 Months Ended

Jun. 30, 2018

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, 2018 and December 31, 2017. 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:

	June 30, 2018																	December 31, 2017
	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)	$	16		$	3		$	—		$	—	$	—		$	19		$	16		$	3		$	—		$	—	$	—		$	19
Nuclear decommissioning trusts
Equity securities	938			—			—			—		—			938			978			—			—			—		—			978
Fixed income securities	6			521			—			—		—			527			18			477			—			—		—			495
Private equity securities	—			—			—			10		—			10			—			—			—			5		—			5
Cash equivalents	9			—			—			—		—			9			14			—			—			—		—			14
Other investments(d)
Equity securities	120			—			—			—		—			120			118			—			—			—		—			118
Fixed income securities	69			—			—			—		—			69			72			—			—			—		—			72
Cash equivalents	4			—			—			—		—			4			4			—			—			—		—			4
Derivative assets
Commodity contracts
Natural gas	51			80			59			—		(119		)	71			148			112			97			—		(256		)	101
Electricity	—			159			22			—		(146		)	35			—			243			42			—		(241		)	44
Other	—			—			15			—		—			15			—			—			9			—		—			9
Foreign currency exchange contracts	—			2			—			—		—			2			—			1			—			—		(1		)	—
Total derivative assets	51			241			96			—		(265		)	123			148			356			148			—		(498		)	154
Total	$	1,213		$	765		$	96		$	10	$	(265	)	$	1,819		$	1,368		$	836		$	148		$	5	$	(498	)	$	1,859
Liabilities
Derivative liabilities
Commodity contracts
Natural gas	$	(53	)	$	(55	)	$	(84	)	$	—	$	119		$	(73	)	$	(141	)	$	(111	)	$	(126	)	$	—	$	263		$	(115	)
Electricity	(1		)	(144		)	(35		)	—		146			(34		)	—			(245		)	(30		)	—		246			(29		)
Other	—			—			—			—		—			—			—			—			(1		)	—		1			—
Foreign currency exchange contracts	—			—			—			—		—			—			—			(3		)	—			—		1			(2		)
Total derivative liabilities	(54		)	(199		)	(119		)	—		265			(107		)	(141		)	(359		)	(157		)	—		511			(146		)
Total	$	(54	)	$	(199	)	$	(119	)	$	—	$	265		$	(107	)	$	(141	)	$	(359	)	$	(157	)	$	—	$	511		$	(146	)
Net Assets (Liabilities) at end of period	$	1,159		$	566		$	(23	)	$	10	$	—		$	1,712		$	1,227		$	477		$	(9	)	$	5	$	13		$	1,713
Assets
Current	$	67		$	181		$	62		$	—	$	(213	)	$	97		$	157		$	298		$	104		$	—	$	(437	)	$	122
Noncurrent	1,146			584			34			10		(52		)	1,722			1,211			538			44			5		(61		)	1,737
Total Assets	$	1,213		$	765		$	96		$	10	$	(265	)	$	1,819		$	1,368		$	836		$	148		$	5	$	(498	)	$	1,859
Liabilities
Current	$	(47	)	$	(158	)	$	(51	)	$	—	$	213		$	(43	)	$	(137	)	$	(313	)	$	(108	)	$	—	$	459		$	(99	)
Noncurrent	(7		)	(41		)	(68		)	—		52			(64		)	(4		)	(46		)	(49		)	—		52			(47		)
Total Liabilities	$	(54	)	$	(199	)	$	(119	)	$	—	$	265		$	(107	)	$	(141	)	$	(359	)	$	(157	)	$	—	$	511		$	(146	)
Net Assets (Liabilities) at end of period	$	1,159		$	566		$	(23	)	$	10	$	—		$	1,712		$	1,227		$	477		$	(9	)	$	5	$	13		$	1,713

_______________________________________

(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, 2018, equity securities of $19 million consisted of $8 million and $11 million of cash equivalents included in Restricted cash and Other investments on DTE Energy's Consolidated Statements of Financial Position, respectively. At December 31, 2017, equity securities of $19 million consisted of $8 million and $11 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, 2018										December 31, 2017
	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)	$	8	$	3	$	—	$	—	$	11	$	8	$	3	$	—	$	—	$	11
Nuclear decommissioning trusts
Equity securities	938		—		—		—		938		978		—		—		—		978
Fixed income securities	6		521		—		—		527		18		477		—		—		495
Private equity securities	—		—				10		10		—		—		—		5		5
Cash equivalents	9		—		—		—		9		14		—		—		—		14
Other investments
Equity securities	11		—		—		—		11		11		—		—		—		11
Derivative assets — FTRs	—		—		15		—		15		—		—		9		—		9
Total	$	972	$	524	$	15	$	10	$	1,521	$	1,029	$	480	$	9	$	5	$	1,523
Assets
Current	$	8	$	3	$	15	$	—	$	26	$	8	$	3	$	9	$	—	$	20
Noncurrent	964		521		—		10		1,495		1,021		477		—		5		1,503
Total Assets	$	972	$	524	$	15	$	10	$	1,521	$	1,029	$	480	$	9	$	5	$	1,523

_______________________________________

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

(b) At June 30, 2018, equity securities of $11 million consisted of cash equivalents included in Other investments on DTE Electric's Consolidated Statements of Financial Position. At December 31, 2017, equity securities of $11 million consisted of cash equivalents included in Other investments on DTE Electric's Consolidated Statements of Financial Position.

Cash Equivalents

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

Nuclear Decommissioning Trusts and Other Investments

The nuclear decommissioning trusts and other investments hold debt and equity securities directly and indirectly through institutional mutual funds and commingled funds. Other assets such as private market investments are used to enhance long-term returns while improving portfolio diversification. All pricing for investments in this category are classified as NAV assets. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. Non-exchange-traded fixed income securities are valued based upon quotations available from brokers or pricing services. The institutional mutual funds hold exchange-traded equity or debt securities (exchange and non-exchange traded) and are valued based on publicly available NAVs. A primary price source is identified by asset type, class, or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustee determines that another price source is considered preferable. The Registrants have obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices. Additionally, the Registrants selectively corroborate the fair value of securities by comparison of market-based price sources. Investment policies and procedures are determined by DTE Energy's Trust Investments Department which reports to DTE Energy's Vice President and Treasurer.

Derivative Assets and Liabilities

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

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

	Three Months Ended June 30, 2018												Three Months Ended June 30, 2017
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of March 31	$	(10	)	$	(13	)	$	4		$	(19	)	$	(15	)	$	(6	)	$	(2	)	$	(23	)
Transfers into Level 3 from Level 2	—			—			—			—			—			—			—			—
Transfers from Level 3 into Level 2	—			—			—			—			—			—			—			—
Total gains (losses)
Included in earnings	(28		)	18			1			(9		)	(6		)	21			—			15
Recorded in Regulatory liabilities	—			—			15			15			—			—			11			11
Purchases, issuances, and settlements
Settlements	13			(18		)	(5		)	(10		)	4			(9		)	(4		)	(9		)
Net Assets (Liabilities) as of June 30	$	(25	)	$	(13	)	$	15		$	(23	)	$	(17	)	$	6		$	5		$	(6	)
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, 2018 and 2017 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	$	(20	)	$	4		$	(2	)	$	(18	)	$	(20	)	$	20		$	—		$	—

	Six Months Ended June 30, 2018												Six Months Ended June 30, 2017
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of December 31	$	(29	)	$	12		$	8		$	(9	)	$	(96	)	$	9		$	(1	)	$	(88	)
Transfers into Level 3 from Level 2	—			—			—			$	—		—			—			—			—
Transfers from Level 3 into Level 2	(3		)	—			—			(3		)	—			—			—			—
Total gains (losses)
Included in earnings	(98		)	4			1			(93		)	46			11			1			58
Recorded in Regulatory liabilities	—			—			15			15			—			—			13			13
Purchases, issuances, and settlements
Settlements	105			(29		)	(9		)	67			33			(14		)	(8		)	11
Net Assets (Liabilities) as of June 30	$	(25	)	$	(13	)	$	15		$	(23	)	$	(17	)	$	6		$	5		$	(6	)
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, 2018 and 2017 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	$	(78	)	$	(6	)	$	(2	)	$	(86	)	$	16		$	17		$	(1	)	$	32

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

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(In millions)
Net Assets as of beginning of period	$	5		$	1		$	9		$	2
Change in fair value recorded in Regulatory liabilities	15			11			15			13
Purchases, issuances, and settlements
Settlements	(5		)	(4		)	(9		)	(7		)
Net Assets as of June 30	$	15		$	8		$	15		$	8
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, 2018 and 2017 and reflected in DTE Electric's Consolidated Statements of Financial Position	$	15		$	8		$	15		$	8

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, 2018 and 2017, and there were no transfers from or into Level 3 for DTE Electric during the same periods.

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

	June 30, 2018
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	59	$	(84	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.28	)	—	$	4.30	/MMBtu	$	(0.13	)/MMBtu
Electricity	$	22	$	(35	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(7	)	—	$	7	/MWh	$	—

	December 31, 2017
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	97	$	(126	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.10	)	—	$	9.75	/MMBtu	$	(0.03	)/MMBtu
Electricity	$	42	$	(30	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(5	)	—	$	15	/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 following table presents the carrying amount and fair value of financial instruments for DTE Energy:

	June 30, 2018								December 31, 2017
	Carrying		Fair Value						Carrying		Fair Value
	Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3
	(In millions)
Notes receivable(a), excluding capital leases	$	37	$	—	$	—	$	37	$	38	$	—	$	—	$	38
Dividends payable	$	321	$	321	$	—	$	—	$	158	$	158	$	—	$	—
Short-term borrowings	$	474	$	—	$	474	$	—	$	621	$	—	$	621	$	—
Notes payable — Other(b), excluding capital leases	$	11	$	—	$	—	$	11	$	12	$	—	$	—	$	12
Long-term debt(c)	$	12,708	$	1,889	$	10,092	$	1,122	$	12,288	$	1,939	$	10,571	$	764

_______________________________________

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

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

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

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

	June 30, 2018								December 31, 2017
	Carrying		Fair Value						Carrying		Fair Value
	Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3
	(In millions)
Short-term borrowings — affiliates	$	75	$	—	$	—	$	75	$	116	$	—	$	—	$	116
Short-term borrowings — other	$	130	$	—	$	130	$	—	$	238	$	—	$	238	$	—
Notes payable — Other(b), excluding capital leases	$	2	$	—	$	—	$	2	$	2	$	—	$	—	$	2
Long-term debt(c)	$	6,537	$	—	$	6,305	$	495	$	6,017	$	—	$	6,441	$	171

_______________________________________

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

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

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

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

Nuclear Decommissioning Trust Funds

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

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

	June 30, 2018		December 31, 2017
	(In millions)
Fermi 2	$	1,467	$	1,475
Fermi 1	3		3
Low-level radioactive waste	14		14
	$	1,484	$	1,492

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,
	2018			2017			2018			2017
	(In millions)
Realized gains	$	19		$	26		$	42		$	49
Realized losses	$	(6	)	$	(8	)	$	(15	)	$	(16	)
Proceeds from sale of securities	$	280		$	311		$	616		$	705

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

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

	June 30, 2018							December 31, 2017
	Fair Value		Unrealized Gains		Unrealized Losses			Fair Value		Unrealized Gains		Unrealized Losses
	(In millions)
Equity securities	$	938	$	300	$	(43	)	$	978	$	320	$	(32	)
Fixed income securities	527		7		(8		)	495		13		(3		)
Private equity securities	10		—		—			5		—		—
Cash equivalents	9		—		—			14		—		—
	$	1,484	$	307	$	(51	)	$	1,492	$	333	$	(35	)

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

	June 30, 2018
	(In millions)
Due within one year	$	24
Due after one through five years	103
Due after five through ten years	113
Due after ten years	287
	$	527

Other Securities

At June 30, 2018 and December 31, 2017, the Registrants' securities, included in Other investments on the Consolidated Statements of Financial Position, were comprised primarily of money market and equity securities. For the three months ended June 30, 2018 and 2017, gains related to equity securities were $1 million and $5 million, respectively, for the Registrants. For the six months ended June 30, 2018 and 2017, losses related to equity securities were $1 million and gains related to equity securities were $13 million, respectively, for the Registrants. Gains or losses related to the Rabbi Trust assets are allocated from DTE Energy to DTE Electric.

XML

Financial and Other Derivative Instruments

6 Months Ended

Jun. 30, 2018

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 2021. Substantially all of these contracts meet the normal purchases and normal sales exception and are therefore accounted for under the accrual method. DTE Gas may also sell forward transportation and storage capacity contracts. Forward transportation and storage contracts are generally not derivatives and are therefore accounted for under the accrual method.

Gas Storage and Pipelines — This segment is primarily engaged in services related to the gathering, transportation, and storage of natural gas. Primarily fixed-priced contracts are used in the marketing and management of transportation and storage services. Generally, these contracts are not derivatives and are therefore accounted for under the accrual method.

Power and Industrial Projects — This segment manages and operates energy and pulverized coal projects, a coke battery, reduced emissions fuel projects, landfill gas recovery, and power generation assets. Primarily fixed-price contracts are used in the marketing and management of the segment assets. These contracts are generally not derivatives and are therefore accounted for under the accrual method.

Energy Trading — Commodity Price Risk — Energy Trading markets and trades electricity, natural gas physical products, and energy financial instruments, and provides energy and asset management services utilizing energy commodity derivative instruments. Forwards, futures, options, and swap agreements are used to manage exposure to the risk of market price and volume fluctuations in its operations. These derivatives are accounted for by recording changes in fair value to earnings unless hedge accounting criteria are met.

Energy Trading — Foreign Currency Exchange Risk — Energy Trading has foreign currency exchange forward contracts to economically hedge fixed Canadian dollar commitments existing under natural gas and power purchase and sale contracts and natural gas transportation contracts. Energy Trading enters into these contracts to mitigate price volatility with respect to fluctuations of the Canadian dollar relative to the U.S. dollar. These derivatives are accounted for by recording changes in fair value to earnings unless hedge accounting criteria are met.

Corporate and Other — Interest Rate Risk — DTE Energy may use interest rate swaps, treasury locks, and other derivatives to hedge the risk associated with interest rate market volatility.

Credit Risk — DTE Energy maintains credit policies that significantly minimize overall credit risk. These policies include an evaluation of potential customers’ and counterparties’ financial condition, including the viability of underlying productive assets, credit rating, collateral requirements, or other credit enhancements such as letters of credit or guarantees. DTE Energy generally uses standardized agreements that allow the netting of positive and negative transactions associated with a single counterparty. DTE Energy maintains a provision for credit losses based on factors surrounding the credit risk of its customers, historical trends, and other information. Based on DTE Energy's credit policies and its June 30, 2018 provision for credit losses, DTE Energy’s exposure to counterparty nonperformance is not expected to have a material adverse effect on DTE Energy's Consolidated Financial Statements.

Derivative Activities

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

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

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

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

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

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

	June 30, 2018					December 31, 2017
	Derivative Assets		Derivative Liabilities			Derivative Assets		Derivative Liabilities
	(In millions)
Derivatives not designated as hedging instruments
Commodity contracts
Natural gas	$	190	$	(192	)	$	357	$	(378	)
Electricity	181		(180		)	285		(275		)
Other	15		—			9		(1		)
Foreign currency exchange contracts	2		—			1		(3		)
Total derivatives not designated as hedging instruments	$	388	$	(372	)	$	652	$	(657	)
Current	$	291	$	(256	)	$	540	$	(558	)
Noncurrent	97		(116		)	112		(99		)
Total derivatives	$	388	$	(372	)	$	652	$	(657	)

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

	June 30, 2018		December 31, 2017
	(In millions)
FTRs — Other current assets	$	15	$	9
Total derivatives not designated as hedging instruments	$	15	$	9

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 $1 million and $4 million outstanding at June 30, 2018 and December 31, 2017, 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 $6 million and $4 million at June 30, 2018 and December 31, 2017, 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.

For DTE Energy, the total cash collateral posted, net of cash collateral received, was $19 million and $28 million as of June 30, 2018 and December 31, 2017, respectively. DTE Energy had no cash collateral related to unrealized positions to net against Derivative assets and liabilities as of June 30, 2018. DTE Energy had $9 million of cash collateral related to unrealized positions to net against Derivative assets while Derivative liabilities are shown net of cash collateral of $22 million as of December 31, 2017. DTE Energy recorded cash collateral paid of $24 million and cash collateral received of $5 million not related to unrealized derivative positions as of June 30, 2018. DTE Energy recorded cash collateral paid of $18 million and cash collateral received of $3 million not related to unrealized derivative positions as of December 31, 2017. 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:

	June 30, 2018									December 31, 2017
	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	$	190		$	(119	)	$	71		$	357		$	(256	)	$	101
Electricity	181			(146		)	35			285			(241		)	44
Other	15			—			15			9			—			9
Foreign currency exchange contracts	2			—			2			1			(1		)	—
Total derivative assets	$	388		$	(265	)	$	123		$	652		$	(498	)	$	154
Derivative liabilities
Commodity contracts
Natural gas	$	(192	)	$	119		$	(73	)	$	(378	)	$	263		$	(115	)
Electricity	(180		)	146			(34		)	(275		)	246			(29		)
Other	—			—			—			(1		)	1			—
Foreign currency exchange contracts	—			—			—			(3		)	1			(2		)
Total derivative liabilities	$	(372	)	$	265		$	(107	)	$	(657	)	$	511		$	(146	)

The following table presents the netting offsets of Derivative assets and liabilities showing the reconciliation of derivative instruments to DTE Energy's Consolidated Statements of Financial Position:

	June 30, 2018												December 31, 2017
	Derivative Assets						Derivative Liabilities						Derivative Assets						Derivative Liabilities
	Current			Noncurrent			Current			Noncurrent			Current			Noncurrent			Current			Noncurrent
	(In millions)
Total fair value of derivatives	$	291		$	97		$	(256	)	$	(116	)	$	540		$	112		$	(558	)	$	(99	)
Counterparty netting	(213		)	(52		)	213			52			(437		)	(52		)	437			52
Collateral adjustment	—			—			—			—			—			(9		)	22			—
Total derivatives as reported	$	78		$	45		$	(43	)	$	(64	)	$	103		$	51		$	(99	)	$	(47	)

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

Derivatives not Designated as Hedging Instruments	Location of Gain (Loss) Recognized in Income on Derivatives	Gain (Loss) Recognized in Income on Derivatives for the Three Months Ended June 30,						Gain (Loss) Recognized in Income on Derivatives for the Six Months Ended June 30,
		2018			2017			2018			2017
		(In millions)
Commodity contracts
Natural gas	Operating Revenues — Non-utility operations	$	(48	)	$	20		$	(158	)	$	77
Natural gas	Fuel, purchased power, and gas — non-utility	16			(15		)	68			46
Electricity	Operating Revenues — Non-utility operations	28			13			11			6
Other	Operating Revenues — Non-utility operations	2			(1		)	1			(1		)
Foreign currency exchange contracts	Operating Revenues — Non-utility operations	2			(1		)	4			(1		)
Total		$	—		$	16		$	(74	)	$	127

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, 2018:

Commodity	Number of Units
Natural gas (MMBtu)	1,908,431,324
Electricity (MWh)	39,463,885
Foreign currency exchange (Canadian dollars)	101,077,223

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, 2018, 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 $508 million.

As of June 30, 2018, DTE Energy had $283 million of derivatives in net liability positions, for which hard triggers exist. There is nocollateral that has been posted against such liabilities, including cash and letters of credit. Associated derivative net asset positions for which contractual offset exists were $247 million. The net remaining amount of $36 million is derived from the $508 millionnoted above.

XML

Long-Term Debt

6 Months Ended

Jun. 30, 2018

Debt Disclosure [Abstract]

Long-Term Debt

LONG-TERM DEBT

Debt Issuances

In 2018, the following debt was issued:

Company	Month	Type	Interest Rate	Maturity Date	Amount
					(In millions)
DTE Electric	May	Mortgage Bonds(a)	4.05%	2048	$	525
					$	525

_______________________________________

(a) Bonds were issued as Green Bonds and the proceeds will be used to finance expenditures for solar and wind energy, payments under power purchase agreements for solar and wind energy, and energy optimization programs.

Debt Redemptions

In 2018, the following debt was redeemed:

Company	Month	Type	Interest Rate	Maturity Date	Amount
					(In millions)
DTE Gas	April	Senior Notes	6.04%	2018	$	100
DTE Energy	Various	Other Long-Term Debt	Various	2018	2
					$	102

In June 2018, DTE Gas agreed to issue $195 million of 3.81% First Mortgage Bonds due 2028 and $125 million of 4.14% First Mortgage Bonds due 2048 to a group of institutional investors in a private placement transaction. These bonds are expected to close and fund in August 2018. Proceeds will be used for the repayment of short-term borrowings and for general corporate purposes.

XML

Short-Term Credit Arrangements and Borrowings

6 Months Ended

Jun. 30, 2018

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, 2018, the total funded debt to total capitalization ratios for DTE Energy, DTE Electric, and DTE Gas were 0.54 to 1, 0.51 to 1, and 0.45 to 1, respectively, and were in compliance with this financial covenant.

The availability under the facilities in place at June 30, 2018 is shown in the following table:

	DTE Energy		DTE Electric		DTE Gas		Total
	(In millions)
Unsecured letter of credit facility, expiring in February 2019	$	150	$	—	$	—	$	150
Unsecured letter of credit facility, expiring in September 2019	70		—		—		70
Unsecured revolving credit facility, expiring April 2022	1,200		400		300		1,900
	1,420		400		300		2,120
Amounts outstanding at June 30, 2018
Commercial paper issuances	177		130		167		474
Letters of credit	147		—		—		147
	324		130		167		621
Net availability at June 30, 2018	$	1,096	$	270	$	133	$	1,499

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

In conjunction with maintaining certain exchange traded risk management positions, DTE Energy may be required to post collateral with its clearing agent. DTE Energy has a demand financing agreement for up to $100 million with its clearing agent. The agreement, as amended, also allows for up to $50 million of additional margin financing provided that DTE Energy posts a letter of credit for the incremental amount and allows the right of setoff with posted collateral. At June 30, 2018, the capacity under this facility was $125 million. The amount outstanding under this agreement was $30 million and $56 million at June 30, 2018 and December 31, 2017, respectively, and was fully offset by the posted collateral.

XML

Commitments and Contingencies

6 Months Ended

Jun. 30, 2018

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

COMMITMENTS AND CONTINGENCIES

Environmental

DTE Electric

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

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

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

In August 2010, the U.S. Department of Justice, at the request of the EPA, brought a civil suit in the U.S. District Court for the Eastern District of Michigan against DTE Energy and DTE Electric, related to the June 2010 NOV/FOV and the outage work performed at Unit 2 of the Monroe Power Plant. In August 2011, the U.S. District Court judge granted DTE Energy's motion for summary judgment in the civil case, dismissing the case and entering judgment in favor of DTE Energy and DTE Electric. In October 2011, the EPA filed a Notice of Appeal to the Court of Appeals for the Sixth Circuit. In March 2013, the Court of Appeals remanded the case to the U.S. District Court for review of the procedural component of the New Source Review notification requirements. In September 2013, the EPA filed a motion seeking leave to amend their complaint regarding the June 2010 NOV/FOV adding additional claims related to outage work performed at the Trenton Channel and Belle River Power Plants as well as additional claims related to work performed at the Monroe Power Plant. In March 2014, the U.S. District Court judge again granted DTE Energy's motion for summary judgment dismissing the civil case related to Monroe Unit 2. In April 2014, the U.S. District Court judge granted motions filed by the EPA and the Sierra Club to amend their New Source Review complaint adding additional claims for Monroe Units 1, 2, and 3, Belle River Units 1 and 2, and Trenton Channel Unit 9. In October 2014, the EPA and the U.S. Department of Justice filed a notice of appeal of the U.S. District Court judge's dismissal of the Monroe Unit 2 case. The amended New Source Review claims were all stayed pending resolution of the appeal by the Court of Appeals for the Sixth Circuit. On January 10, 2017, a divided panel of the Court reversed the decision of the U.S. District Court. On May 8, 2017, DTE Energy and DTE Electric filed a motion to stay the mandate pending filing of a petition for writ of certiorari with the U.S. Supreme Court. The Sixth Circuit granted the motion on May 16, 2017, staying the claims in the U.S. District Court until the U.S. Supreme Court disposes of the case. DTE Electric and DTE Energy filed a petition for writ of certiorari on July 31, 2017. On December 11, 2017, the U.S. Supreme Court denied certiorari. As a result of the Supreme Court electing not to review the matter, the case was sent back to the U.S. District Court for further proceedings and on June 14, 2018 the case was stayed for 180 days pending settlement negotiations. The proceedings at the District Court are currently stayed while the parties discuss potential resolution of the matter.

The Registrants believe that the plants and generating units identified by the EPA and the Sierra Club have complied with all applicable federal environmental regulations. Depending upon the outcome of the litigation and further discussions with the EPA regarding the two NOVs/FOVs, DTE Electric could be required to install additional pollution control equipment at some or all of the power plants in question, implement early retirement of facilities where control equipment is not economical, engage in supplemental environmental programs, and/or pay fines. The Registrants cannot predict the financial impact or outcome of this matter, or the timing of its resolution.

The EPA has implemented regulatory actions under the Clean Air Act to address emissions of GHGs from the utility sector and other sectors of the economy. Among these actions, in 2015 the EPA finalized performance standards for emissions of carbon dioxide from new and existing EGUs. In February 2016, the U.S. Supreme Court granted petitioners' requests for a stay of the carbon rules for existing EGUs (also known as the EPA Clean Power Plan) pending final review by the courts. The Clean Power Plan has no legal effect while the stay is in place. On March 28, 2017, a presidential executive order was issued on "Promoting Energy Independence and Economic Growth." The order instructs the EPA to review, and if appropriate, suspend, revise or rescind the Clean Power Plan rule. Following the issuance of this order, the federal government requested the U.S. Court of Appeals for the D.C. Circuit to hold all legal challenges in abeyance until the review of these regulations is completed. On October 10, 2017, the EPA proposed to rescind the Clean Power Plan and announced its intent to issue an ANPR seeking input as to whether it should replace the rule and, if so, what form it should take. It is not possible to determine the potential impact of the EPA's repeal and possible replacement of the 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 $2.4 billion through 2017. DTE Electric does not anticipate additional capital expenditures through 2024.

Water — In response to an EPA regulation, DTE Electric was required to examine alternatives for reducing the environmental impacts of the cooling water intake structures at several of its facilities. Based on the results of completed studies and expected future studies, DTE Electric may be required to install technologies to reduce the impacts of the water intake structures. A final rule became effective in October 2014. The final rule requires studies to be completed and submitted as part of the National Pollutant Discharge Elimination System (NPDES) permit application process to determine the type of technology needed to reduce impacts to fish. DTE Electric has initiated the process of completing the required studies. Final compliance for the installation of any required technology will be determined by each state on a case by case, site specific basis. DTE Electric is currently evaluating the compliance options and working with the State of Michigan on evaluating whether any controls are needed. These evaluations/studies may require modifications to some existing intake structures. It is not possible to quantify the impact of this rulemaking at this time.

Contaminated and Other Sites — Prior to the construction of major interstate natural gas pipelines, gas for heating and other uses was manufactured locally from processes involving coal, coke, or oil. The facilities, which produced gas, have been designated as MGP sites. DTE Electric conducted remedial investigations at contaminated sites, including three former MGP sites. The investigations have revealed contamination related to the by-products of gas manufacturing at each MGP site. In addition to the MGP sites, DTE Electric is also in the process of cleaning up other contaminated sites, including the area surrounding an ash landfill, electrical distribution substations, electric generating power plants, and underground and aboveground storage tank locations. The findings of these investigations indicated that the estimated cost to remediate these sites is expected to be incurred over the next several years. At June 30, 2018 and December 31, 2017, DTE Electric had $5 million and $6 million, respectively, accrued for remediation. Any change in assumptions, such as remediation techniques, nature and extent of contamination, and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect DTE Electric’s financial position and cash flows. DTE Electric believes the likelihood of a material change to the accrued amount is remote based on current knowledge of the conditions at each site.

Coal Combustion Residuals and Effluent Limitations Guidelines — A final EPA rule for the disposal of coal combustion residuals, commonly known as coal ash, became effective in October 2015, and was revised in October 2016. On March 15, 2018, the EPA published a proposed rule for public comment that is expected to be issued in final form in 2019. Some of the proposed rule provisions could change compliance and closure plans for CCR units if included in the final rule. DTE Electric owns and operates three permitted engineered coal ash storage facilities to dispose of coal ash from coal-fired power plants and operates a number of smaller impoundments at its power plants. CCR obligations vary based on plant life, but include the installation of monitoring wells, compliance with groundwater standards, and the closure of landfills and basins at the end of the useful life of the associated power plant or as a basin becomes inactive.

In November 2015, the EPA finalized the ELG Rule for the steam electric power generating industry which may require additional controls to be installed between 2018 and 2023. On April 12, 2017, the EPA granted a petition for reconsideration of the ELG Rule. The EPA also signed an administrative stay of the ELG Rule’s compliance deadlines for fly ash transport water, bottom ash transport water, and flue gas desulfurization (FGD) wastewater, among others. On June 6, 2017, the EPA published in the Federal Register a proposed rule to postpone certain applicable deadlines within the ELG rule. The final rule was published on September 18, 2017, which extended the earliest compliance deadlines for the FGD wastewater and bottom ash transport until November 1, 2020 in order for the EPA to propose and finalize a new ruling. The ELG compliance requirements, final deadlines, and compliance costs will not be known until the EPA completes its reconsideration of the ELG Rule.

DTE Gas

Contaminated and Other Sites — DTE Gas owns or previously owned, 14 former MGP sites. Investigations have revealed contamination related to the by-products of gas manufacturing at each site. Cleanup of six of the MGP sites is complete, and the sites are closed. DTE Gas has also completed partial closure of six 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, 2018 and December 31, 2017, DTE Gas had $37 million and $41 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.

Other

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

Michigan's Phase 1 non-attainment area includes DTE Energy facilities in southwest Detroit and areas of Wayne County. Modeling runs by the MDEQ suggest that emission reductions may be required by significant sources of SO₂ emissions in these areas, including DTE Electric power plants and DTE Energy's Michigan coke battery facility. As part of the state implementation plan process, DTE Energy has worked with the MDEQ to develop air permits reflecting significant SO₂ emission reductions that, in combination with other non-DTE Energy sources' emission reduction strategies, will help the state attain the standard and sustain its attainment. Since several non-DTE Energy sources are also part of the proposed compliance plan, DTE Energy is unable to determine the full impact of the final required emissions reductions at this time.

Michigan's Phase 2 non-attainment area includes DTE Electric facilities in St. Clair County. State implementation plan (SIP) submittal and EPA approval describing the control strategy and timeline for demonstrating compliance with the new SO₂ standard is the next step in the process, expected to be completed by the end of the year. DTE Energy is currently working with the MDEQ to develop the required SIP. DTE Energy is unable to determine the full impact of the SIP strategy.

Synthetic Fuel Guarantees

DTE Energy discontinued the operations of its synthetic fuel production facilities throughout the United States as of December 31, 2007. DTE Energy provided certain guarantees and indemnities in conjunction with the sales of interests in its synfuel facilities. The guarantees cover potential commercial, environmental, oil price, and tax-related obligations that will survive until 90 days after expiration of all applicable statutes of limitations. DTE Energy estimates that its maximum potential liability under these guarantees at June 30, 2018 was approximately $400 million. Payments under these guarantees are considered remote.

REF Guarantees

DTE Energy has provided certain guarantees and indemnities in conjunction with the sales of interests in or lease of its REF facilities. The guarantees cover potential commercial, environmental, and tax-related obligations that will survive until 90 days after expiration of all applicable statutes of limitations. DTE Energy estimates that its maximum potential liability under these guarantees at June 30, 2018 was $453 million. Payments under these guarantees are considered remote.

NEXUS Guarantees

NEXUS entered into certain 15-year capacity lease agreements for the transportation of natural gas with DTE Gas and Texas Eastern Transmission, LP, an unrelated third party. Pursuant to the terms of those agreements, in December 2016, DTE Energy executed separate guarantee agreements with DTE Gas and Texas Eastern Transmission, LP, with maximum potential payments totaling $84 million and $23 million at June 30, 2018, respectively; each representing 50% of all payment obligations due and payable by NEXUS. Should NEXUS fail to perform under the terms of those agreements, DTE Energy is required to perform on its behalf. Each guarantee terminates at the earlier of (i) such time as all of the guaranteed obligations have been fully performed, or (ii) two months following the end of the primary term of the capacity lease agreements. Subsequent to the NEXUS in-service date, the amount of each guarantee decreases annually as payments are made by NEXUS to each of the aforementioned counterparties. Payments under these guarantees are considered remote.

Other Guarantees

In certain limited circumstances, the Registrants enter into contractual guarantees. The Registrants may guarantee another entity’s obligation in the event it fails to perform and may provide guarantees in certain indemnification agreements. Finally, the Registrants may provide indirect guarantees for the indebtedness of others. DTE Energy’s guarantees are not individually material with maximum potential payments totaling $56 million at June 30, 2018. Payments under these guarantees are considered remote.

DTE Energy is periodically required to obtain performance surety bonds in support of obligations to various governmental entities and other companies in connection with its operations. As of June 30, 2018, DTE Energy had $59 million of performance bonds outstanding. In the event that such bonds are called for nonperformance, DTE Energy would be obligated to reimburse the issuer of the performance bond. DTE Energy is released from the performance bonds as the contractual performance is completed and does not believe that a material amount of any currently outstanding performance bonds will be called.

Labor Contracts

There are several bargaining units for DTE Energy subsidiaries' approximate 5,000 represented employees, including DTE Electric's approximate 2,700 represented employees. The majority of the represented employees are under contracts that expire in 2020 and 2021.

Purchase Commitments

Utility capital expenditures, expenditures for non-utility businesses, and contributions to equity method investees will be approximately $3.6 billion and $1.9 billion in 2018 for DTE Energy and DTE Electric, respectively. The Registrants have made certain commitments in connection with the estimated 2018 annual capital expenditures and contributions to equity method investees.

Other Contingencies

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

For a discussion of contingencies related to regulatory matters and derivatives, see Notes 5 and 8 to the Consolidated Financial Statements, "Regulatory Matters" and "Financial and Other Derivative Instruments," respectively.

XML

Retirement Benefits and Trusteed Assets

6 Months Ended

Jun. 30, 2018

Defined Benefit Plan [Abstract]

Retirement Benefits and Trusteed Assets

RETIREMENT BENEFITS AND TRUSTEED ASSETS

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

	Pension Benefits						Other Postretirement Benefits
	2018			2017			2018			2017
Three Months Ended June 30,	(In millions)
Service cost	$	25		$	23		$	7		$	6
Interest cost	50			53			17			19
Expected return on plan assets	(83		)	(77		)	(35		)	(32		)
Amortization of:
Net actuarial loss	45			43			2			4
Prior service credit	—			—			—			(4		)
Net periodic benefit cost (credit)	$	37		$	42		$	(9	)	$	(7	)

	Pension Benefits						Other Postretirement Benefits
	2018			2017			2018			2017
Six Months Ended June 30,	(In millions)
Service cost	$	50		$	47		$	14		$	13
Interest cost	100			107			34			37
Expected return on plan assets	(165		)	(155		)	(71		)	(65		)
Amortization of:
Net actuarial loss	89			86			5			7
Prior service credit	—			—			—			(7		)
Net periodic benefit cost (credit)	$	74		$	85		$	(18	)	$	(15	)

DTE Electric participates in various plans that provide pension and other postretirement benefits for DTE Energy and its affiliates. The plans are sponsored by DTE Energy's subsidiary, DTE Energy Corporate Services, LLC. DTE Electric accounts for its participation in DTE Energy's qualified and nonqualified pension plans by applying multiemployer accounting. DTE Electric accounts for its participation in other postretirement benefit plans by applying multiple-employer accounting. Within multiemployer and multiple-employer plans, participants pool plan assets for investment purposes and to reduce the cost of plan administration. The primary difference between plan types is assets contributed in multiemployer plans can be used to provide benefits for all participating employers, while assets contributed within a multiple-employer plan are restricted for use by the contributing employer. As a result of multiemployer accounting treatment, capitalized costs associated with these plans are reflected in Property, plant, and equipment in DTE Electric's Consolidated Financial Statements. The same capitalized costs are reflected as Regulatory assets and liabilities in DTE Energy's Consolidated Financial Statements. Plan participants of all plans are solely DTE Energy and affiliate participants.

DTE Energy's subsidiaries are responsible for their share of qualified and nonqualified pension benefit costs. DTE Electric's allocated portion of pension benefit costs included in capital expenditures and operating and maintenance expense were $30 million and $34 million for the three months ended June 30, 2018 and 2017, respectively, and $60 million and $69 million for the six months endedJune 30, 2018 and 2017, respectively. These amounts include recognized contractual termination benefit charges, curtailment gains, and settlement charges.

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

	Other Postretirement Benefits
	2018			2017
Three Months Ended June 30,	(In millions)
Service cost	$	5		$	5
Interest cost	14			14
Expected return on plan assets	(25		)	(22		)
Amortization of:
Net actuarial loss	2			2
Prior service credit	—			(3		)
Net periodic benefit credit	$	(4	)	$	(4	)

	Other Postretirement Benefits
	2018			2017
Six Months Ended June 30,	(In millions)
Service cost	$	10		$	10
Interest cost	27			28
Expected return on plan assets	(49		)	(45		)
Amortization of:
Net actuarial loss	4			4
Prior service credit	—			(5		)
Net periodic benefit credit	$	(8	)	$	(8	)

Pension and Other Postretirement Contributions

During 2018, DTE Energy contributed the following amounts of DTE Energy common stock to the DTE Energy Company Affiliates Employee Benefit Plans Master Trust:

Date	Number of Shares	Price per Share	Amount
			(In millions)
March 7, 2018	1,751,401	$99.92	$	175

The above contribution was made on behalf of DTE Electric, who paid DTE Energy cash consideration of $175 million in March 2018. At the discretion of management and depending upon financial market conditions, DTE Energy may make additional contributions up to $25 million to its pension plans in 2018, with no additional contributions planned from DTE Electric.

DTE Energy does not anticipate making any contributions to the other postretirement benefit plans in 2018.

XML

Segment and Related Information

6 Months Ended

Jun. 30, 2018

Segment Reporting [Abstract]

Segment and Related Information

SEGMENT AND RELATED INFORMATION

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

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

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

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

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

Energy Trading consists of energy marketing and trading operations.

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

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

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(In millions)
Electric	$	13	$	13	$	26	$	25
Gas	4		2		6		5
Gas Storage and Pipelines	14		15		22		22
Power and Industrial Projects	162		156		317		324
Energy Trading	5		8		12		19
Corporate and Other	—		—		1		1
	$	198	$	194	$	384	$	396

Financial data of DTE Energy's business segments follows:

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(In millions)
Operating Revenues — Utility operations
Electric	$	1,276		$	1,218		$	2,481		$	2,393
Gas	255			220			805			777
Operating Revenues — Non-utility operations
Gas Storage and Pipelines	122			113			241			218
Power and Industrial Projects	538			507			1,105			1,055
Energy Trading	1,164			991			2,662			2,043
Corporate and Other	2			—			2			1
Reconciliation and Eliminations	(198		)	(194		)	(384		)	(396		)
Total	$	3,159		$	2,855		$	6,912		$	6,091

Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	163		$	138		$	303		$	244
Gas	14			1			118			108
Gas Storage and Pipelines	60			40			122			85
Power and Industrial Projects	43			30			88			60
Energy Trading	(5		)	—			26			96
Corporate and Other	(41		)	(32		)	(62		)	(16		)
Net Income Attributable to DTE Energy Company	$	234		$	177		$	595		$	577

XML

Significant Accounting Policies (Policies)

6 Months Ended

Jun. 30, 2018

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 2017 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, 2018.

The information in these combined notes relates to each of the Registrants as noted in the Index of Combined Notes to Consolidated Financial Statements. However, DTE Electric does not make any representation as to information related solely to DTE Energy or the subsidiaries of DTE Energy other than itself.

Reclassification

Certain prior year balances for DTE Energy were reclassified to match the current year's Consolidated Financial Statements presentation.

Principles of Consolidation

Principles of Consolidation

The Registrants consolidate all majority-owned subsidiaries and investments in entities in which they have controlling influence. Non-majority owned investments are accounted for using the equity method when the Registrants are able to significantly influence the operating policies of the investee. When the Registrants do not influence the operating policies of an investee, the cost method is used. These Consolidated Financial Statements also reflect the Registrants' proportionate interests in certain jointly-owned utility plants. The Registrants eliminate all intercompany balances and transactions.

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

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

DTE Energy owns a 55% interest in SGG, which owns and operates midstream natural gas assets. SGG has contracts through which certain construction risk is designed to pass-through to the customers, with DTE Energy retaining operational and customer default risk. SGG is a VIE with DTE Energy as the primary beneficiary.

The Registrants have variable interests in NEXUS, which include DTE Energy's 50% ownership interest and DTE Electric's transportation services contract. NEXUS is a joint venture which is in the process of constructing a 255-mile pipeline to transport Utica and Marcellus shale gas to Ohio, Michigan, and Ontario market centers. NEXUS is a VIE as it has insufficient equity at risk to finance its activities. The Registrants are not the primary beneficiaries, as the power to direct significant activities is shared between the owners of the equity interests. DTE Energy accounts for its ownership interest in NEXUS under the equity method.

The Registrants hold ownership interests in certain limited partnerships. The limited partnerships include investment funds which support regional development and economic growth, as well as an operational business providing energy-related products. These entities are generally VIEs as a result of certain characteristics of the limited partnership voting rights. The ownership interests are accounted for under the equity method as the Registrants are not the primary beneficiaries.

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

The maximum risk exposure for consolidated VIEs is reflected on the Registrants' Consolidated Statements of Financial Position and in Note 11 to the Consolidated Financial Statements, "Commitments and Contingencies," related to the REF guarantees and indemnities. For non-consolidated VIEs, the maximum risk exposure of the Registrants is generally limited to their investment, notes receivable, future funding commitments, and amounts which DTE Energy has guaranteed. See Note 11 to the Consolidated Financial Statements, "Commitments and Contingencies," for further discussion of the NEXUS guarantee arrangements.

Changes in Accumulated Other Comprehensive Income (Loss)

Changes in Accumulated Other Comprehensive Income (Loss)

For the three and six months endedJune 30, 2018 and 2017, 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. For further discussion regarding changes in Accumulated other comprehensive income (loss), see Note 3 to the Consolidated Financial Statements, "New Accounting Pronouncements."

Cash, Cash Equivalents, and Restricted Cash

Cash, Cash Equivalents, and Restricted Cash

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

Recently Adopted and Recently Issued Pronouncements

Recently Adopted Pronouncements

In 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 required 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 to be applied retrospectively. The Registrants adopted the standard effective January 1, 2018, using the modified retrospective approach. Under the modified retrospective approach, the information for periods prior to the adoption date has not been restated and continues to be reported under the accounting standards in effect for those periods. As permitted under the standard, the Registrants have elected to apply the guidance only to those contracts that were not completed at January 1, 2018, and have elected not to restate the impacts of any contract modifications made prior to the earliest period presented.

The adoption of the ASU did not have a significant impact on the Registrants' financial position or results of operations, but required additional disclosures for revenue. See Note 4 to the Consolidated Financial Statements, "Revenue."

In March 2017, the FASB issued ASU No. 2017-07, Compensation — Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. The amendments in this update required that an employer report the service cost component in the same line item or items as other compensation costs arising from services rendered by the pertinent employees during the period. The other components of net benefit cost are required to be presented in the income statement separately from the service cost component and outside of income from operations. The amendments in this update also allow only the service cost component to be eligible for capitalization when applicable. The Registrants adopted the standard effective January 1, 2018. The standard has been applied retrospectively for the presentation of the service cost component and the other components of net periodic pension cost and net periodic postretirement benefit cost in the income statement and prospectively for the capitalization of the service cost component of net periodic pension cost and net periodic postretirement benefit in assets. As permitted by the standard, the Registrants have used benefit cost amounts disclosed for prior periods as the basis for retrospective application in the income statement. As a result of regulatory mechanisms, the impact to the Consolidated Financial Statements was not material for the three and six months endedJune 30, 2018.

In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments — Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities, as amended. The new guidance is intended to improve the recognition and measurement of financial instruments. The guidance 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. The guidance requires equity investments to be generally measured at fair value, with subsequent changes in fair value recognized in net income. The guidance requires entities 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. The Registrants adopted the standard effective January 1, 2018. Upon adoption, DTE Energy and DTE Electric recorded a cumulative-effect adjustment to reclassify $5 million and $3 million of unrealized gains from Accumulated other comprehensive income (loss) to Retained earnings, respectively.

In March 2018, the FASB issued ASU No. 2018-05, Income Taxes (Topic 740): Amendments to SEC paragraphs pursuant to SEC Staff Accounting Bulletin No. 118. The Amendments in this update add various SEC paragraphs pursuant to the issuance of SEC Staff Accounting Bulletin No. 118, Income Tax Accounting Implications of the Tax Cuts and Jobs Act (SAB 118). SAB 118 directs taxpayers to consider the implications of the TCJA as provisional when it does not have the necessary information available, prepared, or analyzed in reasonable detail to complete its accounting for the change in the tax law. As described in Note 10 to the Consolidated Financial Statements, "Income Taxes," within the combined DTE Energy and DTE Electric 2017 Annual Report on Form 10-K and in accordance with SAB 118, the Registrants recorded amounts that were considered provisional. During the six months endedJune 30, 2018, DTE Energy and DTE Electric recorded true-up adjustments to the remeasurement of deferred taxes of $21 million and $8 million, respectively. The impact of the true-up adjustments was an increase in Income Tax Expense, of which $16 million was attributable to the regulated utilities and offset to Regulatory liabilities.The true-up adjustments were a result of further analysis for items subject to further consideration at December 31, 2017, under SAB 118 and primarily related to timing differences not recoverable from DTE Electric and DTE Gas customers. The Registrants will continue to analyze the amounts throughout 2018, which may result in additional changes.

Recently Issued Pronouncements

In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842), as amended. This guidance requires a lessee to account for leases as finance or operating leases, and disclose key information about leasing arrangements. Both types of leases will result in the lessee recognizing a right-of-use asset and a corresponding lease liability on its balance sheet, with differing methodology for income statement recognition, depending on the lease classification. The Registrants will adopt the standard on January 1, 2019. As originally issued, the standard requires a modified retrospective approach for leases existing or entered into after the beginning of the earliest comparative period in the Consolidated Financial Statements. The Registrants expect to elect the package of practical expedients allowing entities to not reassess whether an agreement is a lease, to carryforward the existing lease classification, and to not reassess initial direct costs associated with existing leases. The Registrants also plan to elect the practical expedient allowing entities to not evaluate land easements under the new guidance at adoption if they were not previously accounted for as leases.

A third-party software tool is being implemented that will assist with the initial adoption and ongoing compliance of the standard. The Registrants are compiling lease contracts and abstracting the required data, as well as evaluating new business processes, internal controls, and accounting policies. In addition, the Registrants are monitoring utility industry implementation issues for purchase power agreements, pipeline laterals, and other industry specific arrangements. While the Registrants expect an increase in assets and liabilities, as well as additional disclosures, they are still assessing the impact of this ASU on their Consolidated Financial Statements.

In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments — Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments. The amendments in this update replace the incurred loss impairment methodology in current generally accepted accounting principles with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information to inform credit loss estimates. Entities will apply the new guidance as a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which the guidance is adopted. The ASU is effective for the Registrants beginning after December 15, 2019, and interim periods therein. Early adoption is permitted. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements.

In February 2018, the FASB issued ASU No. 2018-02, Income Statement — Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income. The amendments in this update allow a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the TCJA. The amendments in this update also require entities to disclose their accounting policy for releasing income tax effects from accumulated other comprehensive income. The ASU is effective for the Registrants for fiscal years beginning after December 15, 2018, and interim periods therein. Early adoption is permitted. The Registrants are currently assessing the impact of this standard on their Consolidated Financial Statements.

Revenue Recognition

Upon the adoption of Topic 606, revenue is measured based upon the consideration specified in a contract with a customer at the time when performance obligations are satisfied. Under Topic 606, a performance obligation is a promise in a contract to transfer a distinct good or service or a series of distinct goods or services to the customer. The Registrants recognize revenue when performance obligations are satisfied by transferring control over a product or service to a customer. The Registrants have determined control to be transferred when the product is delivered or the service is provided to the customer. For the three and six months endedJune 30, 2018, recognition of revenue for the Registrants subsequent to the adoption of Topic 606 is substantially similar in amount and approach to that prior to adoption.

Rates for DTE Electric and DTE Gas include provisions to adjust billings for fluctuations in fuel and purchased power costs, cost of natural gas, and certain other costs. Revenues are adjusted for differences between actual costs subject to reconciliation and the amounts billed in current rates. Under or over recovered revenues related to these cost recovery mechanisms are included in Regulatory assets or liabilities on the Registrants' Consolidated Statements of Financial Position and are recovered or returned to customers through adjustments to the billing factors.

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, 2018 and December 31, 2017. 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. Other assets such as private market investments are used to enhance long-term returns while improving portfolio diversification. All pricing for investments in this category are classified as NAV assets. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. Non-exchange-traded fixed income securities are valued based upon quotations available from brokers or pricing services. The institutional mutual funds hold exchange-traded equity or debt securities (exchange and non-exchange traded) and are valued based on publicly available NAVs. A primary price source is identified by asset type, class, or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustee determines that another price source is considered 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

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

Fair Value Transfer

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

Derivatives

The Registrants recognize all derivatives at their fair value as Derivative assets or liabilities on their respective Consolidated Statements of Financial Position unless they qualify for certain scope exceptions, including the normal purchases and normal sales exception. Further, derivatives that qualify and are designated for hedge accounting are classified as either hedges of a forecasted transaction or the variability of cash flows to be received or paid related to a recognized asset or liability (cash flow hedge); or as hedges of the fair value of a recognized asset or liability or of an unrecognized firm commitment (fair value hedge). For cash flow hedges, the portion of the derivative gain or loss that is effective in offsetting the change in the value of the underlying exposure is deferred in Accumulated other comprehensive income (loss) and later reclassified into earnings when the underlying transaction occurs. Gains or losses from the ineffective portion of cash flow hedges are recognized in earnings immediately. For fair value hedges, changes in fair values for the derivative and hedged item are recognized in earnings each period. For derivatives that do not qualify or are not designated for hedge accounting, changes in fair value are recognized in earnings each period.

The Registrants’ primary market risk exposure is associated with commodity prices, credit, and interest rates. The Registrants have risk management policies to monitor and manage market risks. The Registrants use derivative instruments to manage some of the exposure. DTE Energy uses derivative instruments for trading purposes in its Energy Trading segment. Contracts classified as derivative instruments include electricity, natural gas, oil, certain coal forwards, futures, options, swaps, and foreign currency exchange contracts. Items not classified as derivatives include natural gas inventory, pipeline transportation contracts, renewable energy credits, and natural gas storage assets.

DTE Electric — DTE Electric generates, purchases, distributes, and sells electricity. DTE Electric uses forward 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 2021. Substantially all of these contracts meet the normal purchases and normal sales exception and are therefore accounted for under the accrual method. DTE Gas may also sell forward transportation and storage capacity contracts. Forward transportation and storage contracts are generally not derivatives and are therefore accounted for under the accrual method.

Gas Storage and Pipelines — This segment is primarily engaged in services related to the gathering, transportation, and storage of natural gas. Primarily fixed-priced contracts are used in the marketing and management of transportation and storage services. Generally, these contracts are not derivatives and are therefore accounted for under the accrual method.

Power and Industrial Projects — This segment manages and operates energy and pulverized coal projects, a coke battery, reduced emissions fuel projects, landfill gas recovery, and power generation assets. Primarily fixed-price contracts are used in the marketing and management of the segment assets. These contracts are generally not derivatives and are therefore accounted for under the accrual method.

Energy Trading — Commodity Price Risk — Energy Trading markets and trades electricity, natural gas physical products, and energy financial instruments, and provides energy and asset management services utilizing energy commodity derivative instruments. Forwards, futures, options, and swap agreements are used to manage exposure to the risk of market price and volume fluctuations in its operations. These derivatives are accounted for by recording changes in fair value to earnings unless hedge accounting criteria are met.

Energy Trading — Foreign Currency Exchange Risk — Energy Trading has foreign currency exchange forward contracts to economically hedge fixed Canadian dollar commitments existing under natural gas and power purchase and sale contracts and natural gas transportation contracts. Energy Trading enters into these contracts to mitigate price volatility with respect to fluctuations of the Canadian dollar relative to the U.S. dollar. These derivatives are accounted for by recording changes in fair value to earnings unless hedge accounting criteria are met.

Corporate and Other — Interest Rate Risk — DTE Energy may use interest rate swaps, treasury locks, and other derivatives to hedge the risk associated with interest rate market volatility.

Credit Risk — DTE Energy maintains credit policies that significantly minimize overall credit risk. These policies include an evaluation of potential customers’ and counterparties’ financial condition, including the viability of underlying productive assets, credit rating, collateral requirements, or other credit enhancements such as letters of credit or guarantees. DTE Energy generally uses standardized agreements that allow the netting of positive and negative transactions associated with a single counterparty. DTE Energy maintains a provision for credit losses based on factors surrounding the credit risk of its customers, historical trends, and other information. Based on DTE Energy's credit policies and its June 30, 2018 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 $1 million and $4 million outstanding at June 30, 2018 and December 31, 2017, 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 $6 million and $4 million at June 30, 2018 and December 31, 2017, respectively. Such balances of letters of credit are excluded from the tables below and are not netted with the recognized assets and liabilities in DTE Energy's Consolidated Statements of Financial Position.

For contracts with certain clearing agents, the fair value of derivative instruments is netted against realized positions with the net balance reflected as either 1) a Derivative asset or liability or 2) an Account receivable or payable. Other than certain clearing agents, Accounts receivable and Accounts payable that are subject to netting arrangements have not been offset against the fair value of Derivative assets and liabilities.

Derivatives, Methods of Accounting, Derivatives Not Designated or Qualifying as Hedges

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

Income Tax

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

XML

Organization and Basis of Presentation (Tables)

6 Months Ended

Jun. 30, 2018

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, 2018 and December 31, 2017. 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.

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

	June 30, 2018						December 31, 2017
	SGG(a)		Other		Total		SGG(a)		Other		Total
	(In millions)
ASSETS
Cash and cash equivalents	$	28	$	16	$	44	$	23	$	14	$	37
Restricted cash	—		8		8		—		8		8
Accounts receivable	10		32		42		11		42		53
Inventories	3		67		70		3		114		117
Property, plant, and equipment, net	389		68		457		400		75		475
Goodwill	25		—		25		25		—		25
Intangible assets	564		—		564		572		—		572
Other current and long-term assets	2		1		3		4		—		4
	$	1,021	$	192	$	1,213	$	1,038	$	253	$	1,291
LIABILITIES
Accounts payable and accrued current liabilities	$	5	$	32	$	37	$	26	$	47	$	73
Current portion long-term debt, including capital leases	—		3		3		—		4		4
Mortgage bonds, notes, and other	—		—		—		—		1		1
Other current and long-term liabilities	7		15		22		1		16		17
	$	12	$	50	$	62	$	27	$	68	$	95

_____________________________________

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

Summary of Amounts for Non-Consolidated Variable Interest Entities

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

	June 30, 2018		December 31, 2017
	(In millions)
Investments in equity method investees	$	1,028	$	811
Notes receivable	$	18	$	17
Future funding commitments	$	416	$	598

XML

Significant Accounting Policies (Tables)

6 Months Ended

Jun. 30, 2018

Accounting Policies [Abstract]

Schedule of Other Income

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(In millions)
Equity earnings of equity method investees	$	32	$	25	$	53	$	51
Income from REF entities	25		22		48		40
Contract services	12		4		32		8
Allowance for equity funds used during construction	6		5		13		12
Gains from equity securities	1		5		1		13
Other	6		5		16		6
	$	82	$	66	$	163	$	130

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(In millions)
Contract services	$	13	$	5	$	33	$	9
Allowance for equity funds used during construction	4		4		9		10
Gains from equity securities allocated from DTE Energy	1		5		1		13
Other	4		3		6		4
	$	22	$	17	$	49	$	36

Schedule of Effective Tax Rate

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

	Effective Tax Rate
	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
DTE Energy	7	%	25	%	13	%	23	%
DTE Electric	21	%	35	%	23	%	35	%

Schedule of Cash and Cash Equivalents

The following is a table that provides a reconciliation of DTE Energy's Cash and cash equivalents as well as Restricted cash reported within the Consolidated Statements of Financial Position that sum to the total of the same such amounts shown in the Consolidated Statements of Cash Flows:

	June 30,		December 31,
	2018		2017
	(In millions)
Cash and cash equivalents	$	63	$	66
Restricted cash	23		23
Total cash, cash equivalents, and restricted cash shown in the Consolidated Statements of Cash Flows	$	86	$	89

Schedule of Restricted Cash

The following is a table that provides a reconciliation of DTE Energy's Cash and cash equivalents as well as Restricted cash reported within the Consolidated Statements of Financial Position that sum to the total of the same such amounts shown in the Consolidated Statements of Cash Flows:

	June 30,		December 31,
	2018		2017
	(In millions)
Cash and cash equivalents	$	63	$	66
Restricted cash	23		23
Total cash, cash equivalents, and restricted cash shown in the Consolidated Statements of Cash Flows	$	86	$	89

XML

Revenue (Tables)

6 Months Ended

Jun. 30, 2018

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

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

	Three Months Ended June 30,		Six Months Ended June 30,
	2018		2018
	(In millions)
Electric(a)
Residential	$	584	$	1,170
Commercial	446		875
Industrial	178		354
Other(b)	68		82
Total Electric operating revenues(c)	$	1,276	$	2,481
Gas
Gas sales	$	180	$	637
End User Transportation	49		134
Intermediate Transportation	11		29
Other(d)	15		5
Total Gas operating revenues(e)	$	255	$	805
Other segment operating revenues(f)
Gas Storage and Pipelines	$	122	$	241
Power and Industrial Projects	$	538	$	1,105
Energy Trading	$	1,164	$	2,662

_______________________________________

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

(b) Includes decreases of $38 million and $77 million to revenues related to TCJA rate reduction reserves for the three and six months endedJune 30, 2018, respectively.

(c) Includes $4 million and $9 million of other revenues which are outside the scope of Topic 606 for the three and six months endedJune 30, 2018, respectively.

(d) Includes an increase of $5 million and a decrease of $27 million to revenues related to TCJA rate reduction reserves for the three and six months endedJune 30, 2018, respectively.

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

(f) Includes revenues outside the scope of Topic 606 primarily related to $399 million and $844 million of contracts accounted for as leases at the Power and Industrial Projects segment for the three and six months endedJune 30, 2018, respectively, and $937 million and $2.1 billion related to derivatives at the Energy Trading segment for the three and six months endedJune 30, 2018, respectively.

Summary of Deferred Revenue Activity

The following is a summary of deferred revenue activity:

	DTE Energy
	(In millions)
Beginning Balance, January 1, 2018	$	56
Increases due to cash received or receivable, excluding amounts recognized as revenue during the period	29
Revenue recognized that was included in the deferred revenue balance at the beginning of the period	(18		)
Ending Balance, June 30, 2018	$	67

Deferred Revenue Amounts Expected to be Recognized as Revenue in Future Periods

The Registrants expect to recognize revenue for the following amounts related to fixed consideration associated with remaining performance obligations in each of the future periods noted:

	DTE Energy		DTE Electric
	(In millions)
2018	$	102	$	5
2019	251		8
2020	178		—
2021	135		—
2022	106		—
2023 and thereafter	351		—
Total	$	1,123	$	13

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

	DTE Energy
	(In millions)
2018	$	27
2019	14
2020	2
2021	4
2022	7
2023 and thereafter	13
	$	67

XML

Earnings Per Share (Tables)

6 Months Ended

Jun. 30, 2018

Earnings Per Share [Abstract]

Schedule of Earnings Per Share, Basic and Diluted

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

	Three Months Ended June 30,				Six Months Ended June 30,
	2018		2017		2018		2017
	(In millions, except per share amounts)
Basic Earnings per Share
Net Income Attributable to DTE Energy Company	$	234	$	177	$	595	$	577
Less: Allocation of earnings to net restricted stock awards	—		—		1		1
Net income available to common shareholders — basic	$	234	$	177	$	594	$	576
Average number of common shares outstanding — basic	181		179		180		179
Basic Earnings per Common Share	$	1.29	$	0.99	$	3.29	$	3.21
Diluted Earnings per Share
Net Income Attributable to DTE Energy Company	$	234	$	177	$	595	$	577
Less: Allocation of earnings to net restricted stock awards	—		—		1		1
Net income available to common shareholders — diluted	$	234	$	177	$	594	$	576
Average number of common shares outstanding — diluted	181		179		180		179
Diluted Earnings per Common Share(a)	$	1.29	$	0.99	$	3.29	$	3.21

_______________________________________

(a) The 2016 Equity Units excluded from the calculation of diluted EPS were approximately 6.6 million and 6.3 million for the three months ended June 30, 2018 and 2017, respectively, and 6.6 million for the six months endedJune 30, 2018 and 2017, as the dilutive stock price threshold was not met.

XML

Fair Value (Tables)

6 Months Ended

Jun. 30, 2018

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:

	June 30, 2018																	December 31, 2017
	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)	$	16		$	3		$	—		$	—	$	—		$	19		$	16		$	3		$	—		$	—	$	—		$	19
Nuclear decommissioning trusts
Equity securities	938			—			—			—		—			938			978			—			—			—		—			978
Fixed income securities	6			521			—			—		—			527			18			477			—			—		—			495
Private equity securities	—			—			—			10		—			10			—			—			—			5		—			5
Cash equivalents	9			—			—			—		—			9			14			—			—			—		—			14
Other investments(d)
Equity securities	120			—			—			—		—			120			118			—			—			—		—			118
Fixed income securities	69			—			—			—		—			69			72			—			—			—		—			72
Cash equivalents	4			—			—			—		—			4			4			—			—			—		—			4
Derivative assets
Commodity contracts
Natural gas	51			80			59			—		(119		)	71			148			112			97			—		(256		)	101
Electricity	—			159			22			—		(146		)	35			—			243			42			—		(241		)	44
Other	—			—			15			—		—			15			—			—			9			—		—			9
Foreign currency exchange contracts	—			2			—			—		—			2			—			1			—			—		(1		)	—
Total derivative assets	51			241			96			—		(265		)	123			148			356			148			—		(498		)	154
Total	$	1,213		$	765		$	96		$	10	$	(265	)	$	1,819		$	1,368		$	836		$	148		$	5	$	(498	)	$	1,859
Liabilities
Derivative liabilities
Commodity contracts
Natural gas	$	(53	)	$	(55	)	$	(84	)	$	—	$	119		$	(73	)	$	(141	)	$	(111	)	$	(126	)	$	—	$	263		$	(115	)
Electricity	(1		)	(144		)	(35		)	—		146			(34		)	—			(245		)	(30		)	—		246			(29		)
Other	—			—			—			—		—			—			—			—			(1		)	—		1			—
Foreign currency exchange contracts	—			—			—			—		—			—			—			(3		)	—			—		1			(2		)
Total derivative liabilities	(54		)	(199		)	(119		)	—		265			(107		)	(141		)	(359		)	(157		)	—		511			(146		)
Total	$	(54	)	$	(199	)	$	(119	)	$	—	$	265		$	(107	)	$	(141	)	$	(359	)	$	(157	)	$	—	$	511		$	(146	)
Net Assets (Liabilities) at end of period	$	1,159		$	566		$	(23	)	$	10	$	—		$	1,712		$	1,227		$	477		$	(9	)	$	5	$	13		$	1,713
Assets
Current	$	67		$	181		$	62		$	—	$	(213	)	$	97		$	157		$	298		$	104		$	—	$	(437	)	$	122
Noncurrent	1,146			584			34			10		(52		)	1,722			1,211			538			44			5		(61		)	1,737
Total Assets	$	1,213		$	765		$	96		$	10	$	(265	)	$	1,819		$	1,368		$	836		$	148		$	5	$	(498	)	$	1,859
Liabilities
Current	$	(47	)	$	(158	)	$	(51	)	$	—	$	213		$	(43	)	$	(137	)	$	(313	)	$	(108	)	$	—	$	459		$	(99	)
Noncurrent	(7		)	(41		)	(68		)	—		52			(64		)	(4		)	(46		)	(49		)	—		52			(47		)
Total Liabilities	$	(54	)	$	(199	)	$	(119	)	$	—	$	265		$	(107	)	$	(141	)	$	(359	)	$	(157	)	$	—	$	511		$	(146	)
Net Assets (Liabilities) at end of period	$	1,159		$	566		$	(23	)	$	10	$	—		$	1,712		$	1,227		$	477		$	(9	)	$	5	$	13		$	1,713

_______________________________________

(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, 2018, equity securities of $19 million consisted of $8 million and $11 million of cash equivalents included in Restricted cash and Other investments on DTE Energy's Consolidated Statements of Financial Position, respectively. At December 31, 2017, equity securities of $19 million consisted of $8 million and $11 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, 2018										December 31, 2017
	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)	$	8	$	3	$	—	$	—	$	11	$	8	$	3	$	—	$	—	$	11
Nuclear decommissioning trusts
Equity securities	938		—		—		—		938		978		—		—		—		978
Fixed income securities	6		521		—		—		527		18		477		—		—		495
Private equity securities	—		—				10		10		—		—		—		5		5
Cash equivalents	9		—		—		—		9		14		—		—		—		14
Other investments
Equity securities	11		—		—		—		11		11		—		—		—		11
Derivative assets — FTRs	—		—		15		—		15		—		—		9		—		9
Total	$	972	$	524	$	15	$	10	$	1,521	$	1,029	$	480	$	9	$	5	$	1,523
Assets
Current	$	8	$	3	$	15	$	—	$	26	$	8	$	3	$	9	$	—	$	20
Noncurrent	964		521		—		10		1,495		1,021		477		—		5		1,503
Total Assets	$	972	$	524	$	15	$	10	$	1,521	$	1,029	$	480	$	9	$	5	$	1,523

_______________________________________

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

(b) At June 30, 2018, equity securities of $11 million consisted of cash equivalents included in Other investments on DTE Electric's Consolidated Statements of Financial Position. At December 31, 2017, equity securities of $11 million consisted of cash equivalents included in Other investments on DTE Electric's Consolidated Statements of Financial Position.

Reconciliation of Level 3 Assets and Liabilities Measured at Fair Value on a Recurring Basis

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

	Three Months Ended June 30, 2018												Three Months Ended June 30, 2017
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of March 31	$	(10	)	$	(13	)	$	4		$	(19	)	$	(15	)	$	(6	)	$	(2	)	$	(23	)
Transfers into Level 3 from Level 2	—			—			—			—			—			—			—			—
Transfers from Level 3 into Level 2	—			—			—			—			—			—			—			—
Total gains (losses)
Included in earnings	(28		)	18			1			(9		)	(6		)	21			—			15
Recorded in Regulatory liabilities	—			—			15			15			—			—			11			11
Purchases, issuances, and settlements
Settlements	13			(18		)	(5		)	(10		)	4			(9		)	(4		)	(9		)
Net Assets (Liabilities) as of June 30	$	(25	)	$	(13	)	$	15		$	(23	)	$	(17	)	$	6		$	5		$	(6	)
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, 2018 and 2017 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	$	(20	)	$	4		$	(2	)	$	(18	)	$	(20	)	$	20		$	—		$	—

	Six Months Ended June 30, 2018												Six Months Ended June 30, 2017
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of December 31	$	(29	)	$	12		$	8		$	(9	)	$	(96	)	$	9		$	(1	)	$	(88	)
Transfers into Level 3 from Level 2	—			—			—			$	—		—			—			—			—
Transfers from Level 3 into Level 2	(3		)	—			—			(3		)	—			—			—			—
Total gains (losses)
Included in earnings	(98		)	4			1			(93		)	46			11			1			58
Recorded in Regulatory liabilities	—			—			15			15			—			—			13			13
Purchases, issuances, and settlements
Settlements	105			(29		)	(9		)	67			33			(14		)	(8		)	11
Net Assets (Liabilities) as of June 30	$	(25	)	$	(13	)	$	15		$	(23	)	$	(17	)	$	6		$	5		$	(6	)
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, 2018 and 2017 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	$	(78	)	$	(6	)	$	(2	)	$	(86	)	$	16		$	17		$	(1	)	$	32

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

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(In millions)
Net Assets as of beginning of period	$	5		$	1		$	9		$	2
Change in fair value recorded in Regulatory liabilities	15			11			15			13
Purchases, issuances, and settlements
Settlements	(5		)	(4		)	(9		)	(7		)
Net Assets as of June 30	$	15		$	8		$	15		$	8
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, 2018 and 2017 and reflected in DTE Electric's Consolidated Statements of Financial Position	$	15		$	8		$	15		$	8

Unobservable Inputs Related to Level 3 Assets and Liabilities

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

	June 30, 2018
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	59	$	(84	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.28	)	—	$	4.30	/MMBtu	$	(0.13	)/MMBtu
Electricity	$	22	$	(35	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(7	)	—	$	7	/MWh	$	—

	December 31, 2017
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	97	$	(126	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.10	)	—	$	9.75	/MMBtu	$	(0.03	)/MMBtu
Electricity	$	42	$	(30	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(5	)	—	$	15	/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:

	June 30, 2018								December 31, 2017
	Carrying		Fair Value						Carrying		Fair Value
	Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3
	(In millions)
Notes receivable(a), excluding capital leases	$	37	$	—	$	—	$	37	$	38	$	—	$	—	$	38
Dividends payable	$	321	$	321	$	—	$	—	$	158	$	158	$	—	$	—
Short-term borrowings	$	474	$	—	$	474	$	—	$	621	$	—	$	621	$	—
Notes payable — Other(b), excluding capital leases	$	11	$	—	$	—	$	11	$	12	$	—	$	—	$	12
Long-term debt(c)	$	12,708	$	1,889	$	10,092	$	1,122	$	12,288	$	1,939	$	10,571	$	764

_______________________________________

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

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

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

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

	June 30, 2018								December 31, 2017
	Carrying		Fair Value						Carrying		Fair Value
	Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3
	(In millions)
Short-term borrowings — affiliates	$	75	$	—	$	—	$	75	$	116	$	—	$	—	$	116
Short-term borrowings — other	$	130	$	—	$	130	$	—	$	238	$	—	$	238	$	—
Notes payable — Other(b), excluding capital leases	$	2	$	—	$	—	$	2	$	2	$	—	$	—	$	2
Long-term debt(c)	$	6,537	$	—	$	6,305	$	495	$	6,017	$	—	$	6,441	$	171

_______________________________________

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

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

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

Fair Value of Nuclear Decommissioning Trust Fund Assets

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

	June 30, 2018		December 31, 2017
	(In millions)
Fermi 2	$	1,467	$	1,475
Fermi 1	3		3
Low-level radioactive waste	14		14
	$	1,484	$	1,492

Schedule of Realized Gains and Losses and Proceeds from Sale of Securities by Nuclear Decommissioning Trust Funds

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

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(In millions)
Realized gains	$	19		$	26		$	42		$	49
Realized losses	$	(6	)	$	(8	)	$	(15	)	$	(16	)
Proceeds from sale of securities	$	280		$	311		$	616		$	705

Fair Value and Unrealized Gains and Losses for Nuclear Decommissioning Trust Funds

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

	June 30, 2018							December 31, 2017
	Fair Value		Unrealized Gains		Unrealized Losses			Fair Value		Unrealized Gains		Unrealized Losses
	(In millions)
Equity securities	$	938	$	300	$	(43	)	$	978	$	320	$	(32	)
Fixed income securities	527		7		(8		)	495		13		(3		)
Private equity securities	10		—		—			5		—		—
Cash equivalents	9		—		—			14		—		—
	$	1,484	$	307	$	(51	)	$	1,492	$	333	$	(35	)

Fair Value of the Fixed Income Securities Held in Nuclear Decommissioning Trust Funds

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

	June 30, 2018
	(In millions)
Due within one year	$	24
Due after one through five years	103
Due after five through ten years	113
Due after ten years	287
	$	527

XML

Financial and Other Derivative Instruments (Tables)

6 Months Ended

Jun. 30, 2018

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair Value of Derivative Instruments

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

	June 30, 2018					December 31, 2017
	Derivative Assets		Derivative Liabilities			Derivative Assets		Derivative Liabilities
	(In millions)
Derivatives not designated as hedging instruments
Commodity contracts
Natural gas	$	190	$	(192	)	$	357	$	(378	)
Electricity	181		(180		)	285		(275		)
Other	15		—			9		(1		)
Foreign currency exchange contracts	2		—			1		(3		)
Total derivatives not designated as hedging instruments	$	388	$	(372	)	$	652	$	(657	)
Current	$	291	$	(256	)	$	540	$	(558	)
Noncurrent	97		(116		)	112		(99		)
Total derivatives	$	388	$	(372	)	$	652	$	(657	)

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

	June 30, 2018		December 31, 2017
	(In millions)
FTRs — Other current assets	$	15	$	9
Total derivatives not designated as hedging instruments	$	15	$	9

Netting Offsets of Derivative Assets and Liabilities

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

	June 30, 2018									December 31, 2017
	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	$	190		$	(119	)	$	71		$	357		$	(256	)	$	101
Electricity	181			(146		)	35			285			(241		)	44
Other	15			—			15			9			—			9
Foreign currency exchange contracts	2			—			2			1			(1		)	—
Total derivative assets	$	388		$	(265	)	$	123		$	652		$	(498	)	$	154
Derivative liabilities
Commodity contracts
Natural gas	$	(192	)	$	119		$	(73	)	$	(378	)	$	263		$	(115	)
Electricity	(180		)	146			(34		)	(275		)	246			(29		)
Other	—			—			—			(1		)	1			—
Foreign currency exchange contracts	—			—			—			(3		)	1			(2		)
Total derivative liabilities	$	(372	)	$	265		$	(107	)	$	(657	)	$	511		$	(146	)

Netting Offsets of Derivative Assets and Liabilities Reconciliation to the Statements of Financial Position

The following table presents the netting offsets of Derivative assets and liabilities showing the reconciliation of derivative instruments to DTE Energy's Consolidated Statements of Financial Position:

	June 30, 2018												December 31, 2017
	Derivative Assets						Derivative Liabilities						Derivative Assets						Derivative Liabilities
	Current			Noncurrent			Current			Noncurrent			Current			Noncurrent			Current			Noncurrent
	(In millions)
Total fair value of derivatives	$	291		$	97		$	(256	)	$	(116	)	$	540		$	112		$	(558	)	$	(99	)
Counterparty netting	(213		)	(52		)	213			52			(437		)	(52		)	437			52
Collateral adjustment	—			—			—			—			—			(9		)	22			—
Total derivatives as reported	$	78		$	45		$	(43	)	$	(64	)	$	103		$	51		$	(99	)	$	(47	)

Gain (Loss) Recognized in Income on Derivatives

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

Derivatives not Designated as Hedging Instruments	Location of Gain (Loss) Recognized in Income on Derivatives	Gain (Loss) Recognized in Income on Derivatives for the Three Months Ended June 30,						Gain (Loss) Recognized in Income on Derivatives for the Six Months Ended June 30,
		2018			2017			2018			2017
		(In millions)
Commodity contracts
Natural gas	Operating Revenues — Non-utility operations	$	(48	)	$	20		$	(158	)	$	77
Natural gas	Fuel, purchased power, and gas — non-utility	16			(15		)	68			46
Electricity	Operating Revenues — Non-utility operations	28			13			11			6
Other	Operating Revenues — Non-utility operations	2			(1		)	1			(1		)
Foreign currency exchange contracts	Operating Revenues — Non-utility operations	2			(1		)	4			(1		)
Total		$	—		$	16		$	(74	)	$	127

Volume of Commodity Contracts

The following represents the cumulative gross volume of DTE Energy's derivative contracts outstanding as of June 30, 2018:

Commodity	Number of Units
Natural gas (MMBtu)	1,908,431,324
Electricity (MWh)	39,463,885
Foreign currency exchange (Canadian dollars)	101,077,223

XML

Long-Term Debt (Tables)

6 Months Ended

Jun. 30, 2018

Debt Disclosure [Abstract]

Schedule of Issued Debt

In 2018, the following debt was issued:

Company	Month	Type	Interest Rate	Maturity Date	Amount
					(In millions)
DTE Electric	May	Mortgage Bonds(a)	4.05%	2048	$	525
					$	525

_______________________________________

(a) Bonds were issued as Green Bonds and the proceeds will be used to finance expenditures for solar and wind energy, payments under power purchase agreements for solar and wind energy, and energy optimization programs.

Schedule of Debt Redemptions

In 2018, the following debt was redeemed:

Company	Month	Type	Interest Rate	Maturity Date	Amount
					(In millions)
DTE Gas	April	Senior Notes	6.04%	2018	$	100
DTE Energy	Various	Other Long-Term Debt	Various	2018	2
					$	102

XML

Short-Term Credit Arrangements and Borrowings (Tables)

6 Months Ended

Jun. 30, 2018

Short-term Debt [Abstract]

Schedule of Line of Credit Facilities

The availability under the facilities in place at June 30, 2018 is shown in the following table:

	DTE Energy		DTE Electric		DTE Gas		Total
	(In millions)
Unsecured letter of credit facility, expiring in February 2019	$	150	$	—	$	—	$	150
Unsecured letter of credit facility, expiring in September 2019	70		—		—		70
Unsecured revolving credit facility, expiring April 2022	1,200		400		300		1,900
	1,420		400		300		2,120
Amounts outstanding at June 30, 2018
Commercial paper issuances	177		130		167		474
Letters of credit	147		—		—		147
	324		130		167		621
Net availability at June 30, 2018	$	1,096	$	270	$	133	$	1,499

XML

Retirement Benefits and Trusteed Assets (Tables)

6 Months Ended

Jun. 30, 2018

Defined Benefit Plan [Abstract]

Schedule of Net Periodic Benefit Costs (Credits)

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

	Other Postretirement Benefits
	2018			2017
Three Months Ended June 30,	(In millions)
Service cost	$	5		$	5
Interest cost	14			14
Expected return on plan assets	(25		)	(22		)
Amortization of:
Net actuarial loss	2			2
Prior service credit	—			(3		)
Net periodic benefit credit	$	(4	)	$	(4	)

	Other Postretirement Benefits
	2018			2017
Six Months Ended June 30,	(In millions)
Service cost	$	10		$	10
Interest cost	27			28
Expected return on plan assets	(49		)	(45		)
Amortization of:
Net actuarial loss	4			4
Prior service credit	—			(5		)
Net periodic benefit credit	$	(8	)	$	(8	)

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
	2018			2017			2018			2017
Three Months Ended June 30,	(In millions)
Service cost	$	25		$	23		$	7		$	6
Interest cost	50			53			17			19
Expected return on plan assets	(83		)	(77		)	(35		)	(32		)
Amortization of:
Net actuarial loss	45			43			2			4
Prior service credit	—			—			—			(4		)
Net periodic benefit cost (credit)	$	37		$	42		$	(9	)	$	(7	)

	Pension Benefits						Other Postretirement Benefits
	2018			2017			2018			2017
Six Months Ended June 30,	(In millions)
Service cost	$	50		$	47		$	14		$	13
Interest cost	100			107			34			37
Expected return on plan assets	(165		)	(155		)	(71		)	(65		)
Amortization of:
Net actuarial loss	89			86			5			7
Prior service credit	—			—			—			(7		)
Net periodic benefit cost (credit)	$	74		$	85		$	(18	)	$	(15	)

Schedule of Defined Benefit Plans Disclosures

During 2018, DTE Energy contributed the following amounts of DTE Energy common stock to the DTE Energy Company Affiliates Employee Benefit Plans Master Trust:

Date	Number of Shares	Price per Share	Amount
			(In millions)
March 7, 2018	1,751,401	$99.92	$	175

XML

Segment and Related Information (Tables)

6 Months Ended

Jun. 30, 2018

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,
	2018		2017		2018		2017
	(In millions)
Electric	$	13	$	13	$	26	$	25
Gas	4		2		6		5
Gas Storage and Pipelines	14		15		22		22
Power and Industrial Projects	162		156		317		324
Energy Trading	5		8		12		19
Corporate and Other	—		—		1		1
	$	198	$	194	$	384	$	396

Financial data of DTE Energy's business segments follows:

	Three Months Ended June 30,						Six Months Ended June 30,
	2018			2017			2018			2017
	(In millions)
Operating Revenues — Utility operations
Electric	$	1,276		$	1,218		$	2,481		$	2,393
Gas	255			220			805			777
Operating Revenues — Non-utility operations
Gas Storage and Pipelines	122			113			241			218
Power and Industrial Projects	538			507			1,105			1,055
Energy Trading	1,164			991			2,662			2,043
Corporate and Other	2			—			2			1
Reconciliation and Eliminations	(198		)	(194		)	(384		)	(396		)
Total	$	3,159		$	2,855		$	6,912		$	6,091

Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	163		$	138		$	303		$	244
Gas	14			1			118			108
Gas Storage and Pipelines	60			40			122			85
Power and Industrial Projects	43			30			88			60
Energy Trading	(5		)	—			26			96
Corporate and Other	(41		)	(32		)	(62		)	(16		)
Net Income Attributable to DTE Energy Company	$	234		$	177		$	595		$	577

XML

Organization and Basis of Presentation (Details Textuals) $ / shares in Units, customer in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018 USD ($) customer $ / shares	Jun. 30, 2017 declaration $ / shares	Jun. 30, 2018 USD ($) customer $ / shares	Jun. 30, 2017 $ / shares
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Number of electric utility customers | customer	2.2		2.2
Number of gas utility customers | customer	1.3		1.3
Number of dividend declarations | declaration		2
Dividends declared per common share (in dollars per share) | $ / shares	$ 1.77	$ 1.65	$ 2.65	$ 2.48
Significant potential exposure | $	$ 0		$ 0
DTE Electric
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Significant potential exposure | $	$ 0		$ 0
NEXUS pipeline
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Ownership interest	50.00%		50.00%
West Virginia | Midstream Natural Gas Assets
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Percent of assets acquired	55.00%		55.00%
Previously Reported
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Number of dividend declarations | declaration		1
Dividends declared per common share (in dollars per share) | $ / shares		$ 0.83		$ 1.65

XML

Organization and Basis of Presentation (Consolidated Variable Interest Entities) (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
ASSETS
Cash and cash equivalents	$ 63	$ 66
Restricted cash	23	23
Accounts receivable	1,690	1,758
Property, plant, and equipment, net	21,239	20,721
Goodwill	2,293	2,293
Intangible assets	862	867
Total Assets	34,330	33,767
LIABILITIES
Current portion long-term debt, including capital leases	5	109
Mortgage bonds, notes, and other	11,560	11,039
Variable interest entity, primary beneficiary, restricted
ASSETS
Cash and cash equivalents	44	37
Restricted cash	8	8
Accounts receivable	42	53
Inventories	70	117
Property, plant, and equipment, net	457	475
Goodwill	25	25
Intangible assets	564	572
Other current and long-term assets	3	4
Total Assets	1,213	1,291
LIABILITIES
Accounts payable and accrued current liabilities	37	73
Current portion long-term debt, including capital leases	3	4
Mortgage bonds, notes, and other	0	1
Other current and long-term liabilities	22	17
Total liabilities	62	95
SGG
ASSETS
Cash and cash equivalents	28	23
Restricted cash	0	0
Accounts receivable	10	11
Inventories	3	3
Property, plant, and equipment, net	389	400
Goodwill	25	25
Intangible assets	564	572
Other current and long-term assets	2	4
Total Assets	1,021	1,038
LIABILITIES
Accounts payable and accrued current liabilities	5	26
Current portion long-term debt, including capital leases	0	0
Mortgage bonds, notes, and other	0	0
Other current and long-term liabilities	7	1
Total liabilities	$ 12	27
VIE ownership and non-ownership percentage	100.00%
VIE ownership percentage	55.00%
Other
ASSETS
Cash and cash equivalents	$ 16	14
Restricted cash	8	8
Accounts receivable	32	42
Inventories	67	114
Property, plant, and equipment, net	68	75
Goodwill	0	0
Intangible assets	0	0
Other current and long-term assets	1	0
Total Assets	192	253
LIABILITIES
Accounts payable and accrued current liabilities	32	47
Current portion long-term debt, including capital leases	3	4
Mortgage bonds, notes, and other	0	1
Other current and long-term liabilities	15	16
Total liabilities	$ 50	$ 68

XML

Organization and Basis of Presentation (Non-Consolidated Variable Interest Entities) (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Variable Interest Entity [Line Items]
Investments in equity method investees	$ 1,326	$ 1,073
Notes receivable	69	73
Variable interest entity, non-consolidated
Variable Interest Entity [Line Items]
Investments in equity method investees	1,028	811
Notes receivable	18	17
Future funding commitments	$ 416	$ 598

XML

Significant Accounting Policies Significant Accounting Policies (Other Income) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Schedule of Other Nonoperating Income, by Component [Line Items]
Equity earnings of equity method investees	$ 32	$ 25	$ 53	$ 51
Income from REF entities	25	22	48	40
Contract services	12	4	32	8
Allowance for equity funds used during construction	6	5	13	12
Gains from equity securities	1	5	1	13
Other	6	5	16	6
Total other income	82	66	163	130
DTE Electric
Schedule of Other Nonoperating Income, by Component [Line Items]
Contract services	13	5	33	9
Allowance for equity funds used during construction	4	4	9	10
Gains from equity securities	1	5	1	13
Other	4	3	6	4
Total other income	$ 22	$ 17	$ 49	$ 36

XML

Significant Accounting Policies (Details Textuals) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2018	Dec. 31, 2017
Significant Accounting Policies [Line Items]
Estimated annual effective tax rates	7.00%	25.00%	13.00%	23.00%
Effective tax rate increase (decrease)	(18.00%)		(10.00%)
Increase in annual production tax credits	4.00%
True-up adjustment to the remeasurement of deferred taxes			$ 21
Measurement period increase (decrease) in effective tax rate			3.00%
ASU 2016-09 excess tax benefit amount			$ 11
ASU 2016-09 excess tax benefit (percentage)			1.00%
Unrecognized tax benefits	$ 8		$ 8
Unrecognized compensation cost	$ 98		$ 98
Recognition period (in years)			1 year 6 months 7 days
DTE Electric
Significant Accounting Policies [Line Items]
Estimated annual effective tax rates	21.00%	35.00%	23.00%	35.00%
Effective tax rate increase (decrease)	(14.00%)		(12.00%)
True-up adjustment to the remeasurement of deferred taxes			$ 8
Measurement period increase (decrease) in effective tax rate			2.00%
Unrecognized tax benefits	$ 10		$ 10
DTE Electric | DTE Energy
Significant Accounting Policies [Line Items]
Income tax receivable	12		12			$ 12
Allocated costs	$ 8	$ 10	$ 17	$ 18
Forecast
Significant Accounting Policies [Line Items]
Estimated annual effective tax rates					12.00%
Forecast | DTE Electric
Significant Accounting Policies [Line Items]
Estimated annual effective tax rates					22.00%

XML

Significant Accounting Policies (Income Taxes) (Details)	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Schedule of Income Taxes [Line Items]
Effective Tax Rate	7.00%	25.00%	13.00%	23.00%
DTE Electric
Schedule of Income Taxes [Line Items]
Effective Tax Rate	21.00%	35.00%	23.00%	35.00%

XML

Significant Accounting Policies (Cash and Restricted Cash) (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017	Jun. 30, 2017	Dec. 31, 2016
Accounting Policies [Abstract]
Cash and cash equivalents	$ 63	$ 66
Restricted cash	23	23
Total cash, cash equivalents, and restricted cash shown in the Consolidated Statements of Cash Flows	$ 86	$ 89	$ 84	$ 113

XML

New Accounting Pronouncements - Narrative (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Implementation of ASU 2016-01		$ 0
True-up adjustment to the remeasurement of deferred taxes	$ 21
DTE Electric
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Implementation of ASU 2016-01		0
True-up adjustment to the remeasurement of deferred taxes	8
Other Regulatory Assets (Liabilities)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
True-up adjustment to the remeasurement of deferred taxes	$ 16
Accumulated Other Comprehensive Income (Loss)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Implementation of ASU 2016-01		(5)
Accumulated Other Comprehensive Income (Loss) | DTE Electric
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Implementation of ASU 2016-01		(3)
Accumulated Other Comprehensive Income (Loss) | Accounting Standards Update 2016-01
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Implementation of ASU 2016-01		(5)
Accumulated Other Comprehensive Income (Loss) | Accounting Standards Update 2016-01 | DTE Electric
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Implementation of ASU 2016-01		(3)
Retained Earnings
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Implementation of ASU 2016-01		5
Retained Earnings | DTE Electric
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Implementation of ASU 2016-01		3
Retained Earnings | Accounting Standards Update 2016-01
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Implementation of ASU 2016-01		5
Retained Earnings | Accounting Standards Update 2016-01 | DTE Electric
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Implementation of ASU 2016-01		$ 3

XML

Revenue - Disaggregation of Revenue (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Disaggregation of Revenue [Line Items]
Revenues	$ 3,159	$ 2,855	$ 6,912	$ 6,091
Electric
Disaggregation of Revenue [Line Items]
Revenues	1,276		2,481
Increase (decrease) of revenue due to Tax Cuts and Jobs Act	(38)		(77)
Electric | Other
Disaggregation of Revenue [Line Items]
Revenues	4		9
Electric | Residential
Disaggregation of Revenue [Line Items]
Revenues	584		1,170
Electric | Commercial
Disaggregation of Revenue [Line Items]
Revenues	446		875
Electric | Industrial
Disaggregation of Revenue [Line Items]
Revenues	178		354
Electric | Other
Disaggregation of Revenue [Line Items]
Revenues	68		82
Gas
Disaggregation of Revenue [Line Items]
Revenues	255		805
Increase (decrease) of revenue due to Tax Cuts and Jobs Act	5		(27)
Gas | Other
Disaggregation of Revenue [Line Items]
Revenues	2		4
Gas | Alternative Revenue Programs
Disaggregation of Revenue [Line Items]
Revenues	(1)		(4)
Gas | Other
Disaggregation of Revenue [Line Items]
Revenues	15		5
Gas | Gas sales
Disaggregation of Revenue [Line Items]
Revenues	180		637
Gas | End User Transportation
Disaggregation of Revenue [Line Items]
Revenues	49		134
Gas | Intermediate Transportation
Disaggregation of Revenue [Line Items]
Revenues	11		29
Gas Storage and Pipelines
Disaggregation of Revenue [Line Items]
Revenues	122		241
Power and Industrial Projects
Disaggregation of Revenue [Line Items]
Revenues	538		1,105
Lease revenue outside scope of Topic 606	399		844
Energy Trading
Disaggregation of Revenue [Line Items]
Revenues	1,164		2,662
Gain (loss) on derivative outside scope of Topic 606	$ 937		$ 2,100

XML

Revenue - Narrative (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2018
Revenue from External Customer [Line Items]
Allowance for doubtful accounts receivable write-offs	$ 31	$ 56
DTE Electric
Revenue from External Customer [Line Items]
Allowance for doubtful accounts receivable write-offs	$ 17	$ 31
Other | Power and Industrial Projects
Revenue from External Customer [Line Items]
Payment terms		30 days

XML

Revenue - Deferred Revenue (Details) $ in Millions	6 Months Ended
	Jun. 30, 2018 USD ($)
Contract Liability [Roll Forward]
Beginning Balance	$ 56
Increases due to cash received or receivable, excluding amounts recognized as revenue during the period	29
Revenue recognized that was included in the deferred revenue balance at the beginning of the period	(18)
Ending Balance	$ 67

XML

Revenue - Expected Recognition of Deferred Revenue (Details) $ in Millions	Jun. 30, 2018 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 27
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 14
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 2
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 4
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 7
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 13
Remaining performance obligation, expected timing of satisfaction
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 67

XML

Revenue - Expected Timing of Performance Obligation Satisfaction (Details) $ in Millions	Jun. 30, 2018 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 27
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 14
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 2
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 4
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 7
Remaining performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 13
Remaining performance obligation, expected timing of satisfaction
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 67
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 102
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-01-01 | DTE Electric
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 5
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 251
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | DTE Electric
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 8
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 178
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | DTE Electric
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 0
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 135
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | DTE Electric
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 0
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 106
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | DTE Electric
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 0
Remaining performance obligation, expected timing of satisfaction	1 year
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 351
Remaining performance obligation, expected timing of satisfaction
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | DTE Electric
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 0
Remaining performance obligation, expected timing of satisfaction
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 1,123
Fixed-price Contract | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | DTE Electric
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Remaining performance obligation	$ 13

XML

Regulatory Matters (Details Textuals) $ in Millions	Jul. 24, 2018 USD ($)	Jul. 06, 2018 USD ($)	Jun. 28, 2018 USD ($)	May 30, 2018 USD ($)	May 24, 2018 USD ($)	May 18, 2018 USD ($)	Apr. 18, 2018 USD ($)	Mar. 28, 2018 USD ($)	Nov. 22, 2017 USD ($)	Nov. 01, 2017 USD ($)	Apr. 19, 2017 USD ($)	Jun. 30, 2018 USD ($)	Apr. 27, 2018 USD ($) certificate	Jul. 31, 2017 USD ($) certificate MW
DTE Electric
Public Utilities, General Disclosures [Line Items]
Reduction of revenue due to Tax Cuts and Jobs Act, requested						$ 157.0
DTE Electric | Subsequent event
Public Utilities, General Disclosures [Line Items]
Reduction of revenue due to Tax Cuts and Jobs Act, approved	$ 157.0
DTE Electric | MPSC | Electric Rate Case Filing 2017
Public Utilities, General Disclosures [Line Items]
Requested rate increase										$ 125.0	$ 231.0
Approved rate increase			$ 74.4				$ 65.2
Return on equity percent							10.00%
DTE Electric | MPSC | Electric Rate Case Filing 2017 | Refundable self-implemented rates
Public Utilities, General Disclosures [Line Items]
Regulatory liabilities												$ 25.0
DTE Electric | MPSC | Electric Rate Case Filing 2018 | Subsequent event
Public Utilities, General Disclosures [Line Items]
Requested rate increase		$ 328.0
Return on equity percent		10.00%
Return on equity requested percent		10.50%
DTE Electric | MPSC | Certificate of Necessity Request
Public Utilities, General Disclosures [Line Items]
Amount of power associated with natural gas fueled combined cycle generation facility requesting to build | MW														1,100
Number of certificates of necessity requested to be issued | certificate														3
Estimated capital costs														$ 989.0
Number of certificates of necessity approved for issuance | certificate													3
Approved recoverable amounts, maximum rate													$ 951.8
DTE Gas
Public Utilities, General Disclosures [Line Items]
Reduction of revenue due to Tax Cuts and Jobs Act, requested								$ 38.2
Reduction of revenue due to Tax Cuts and Jobs Act, approved				$ 38.2
DTE Gas | MPSC | DTE Gas Rate Case Filing 2017
Public Utilities, General Disclosures [Line Items]
Requested rate increase					$ 38.1				$ 85.1
Return on equity percent									10.10%
Return on equity requested percent									10.50%

XML

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Basic Earnings per Share
Net Income Attributable to DTE Energy Company	$ 234	$ 177	$ 595	$ 577
Less: Allocation of earnings to net restricted stock awards	0	0	1	1
Net income available to common shareholders — basic	$ 234	$ 177	$ 594	$ 576
Average number of common shares outstanding — basic (in shares)	181.0	179.0	180.0	179.0
Basic Earnings per Common Share (in dollars per share)	$ 1.29	$ 0.99	$ 3.29	$ 3.21
Diluted Earnings per Share
Net Income Attributable to DTE Energy Company	$ 234	$ 177	$ 595	$ 577
Less: Allocation of earnings to net restricted stock awards	0	0	1	1
Net income available to common shareholders — diluted	$ 234	$ 177	$ 594	$ 576
Average number of common shares outstanding — diluted (in shares)	181.0	179.0	180.0	179.0
Diluted Earnings per Common Share (in dollars per share)	$ 1.29	$ 0.99	$ 3.29	$ 3.21
Antidilutive securities excluded from computation of earnings per share (in shares)	6.6	6.3	6.6	6.6

XML

Fair Value (Assets and Liabilities Recorded at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Derivative assets
Derivative assets, gross	$ 388	$ 652
Derivative asset, netting	(265)	(498)
Derivative assets, net	123	154
Derivative liabilities
Derivative liabilities, gross	(372)	(657)
Derivative liability, netting	265	511
Derivative liabilities, net	(107)	(146)
Current liabilities
Derivative liabilities
Derivative liabilities, gross	(256)	(558)
Noncurrent liabilities
Derivative liabilities
Derivative liabilities, gross	(116)	(99)
Natural gas
Derivative assets
Derivative assets, gross	190	357
Derivative asset, netting	(119)	(256)
Derivative assets, net	71	101
Derivative liabilities
Derivative liabilities, gross	(192)	(378)
Derivative liability, netting	119	263
Derivative liabilities, net	(73)	(115)
Electricity
Derivative assets
Derivative assets, gross	181	285
Derivative asset, netting	(146)	(241)
Derivative assets, net	35	44
Derivative liabilities
Derivative liabilities, gross	(180)	(275)
Derivative liability, netting	146	246
Derivative liabilities, net	(34)	(29)
Other
Derivative assets
Derivative assets, gross	15	9
Derivative asset, netting	0	0
Derivative assets, net	15	9
Derivative liabilities
Derivative liabilities, gross	0	(1)
Derivative liability, netting	0	1
Derivative liabilities, net	0	0
Foreign currency exchange contracts
Derivative assets
Derivative assets, gross	2	1
Derivative asset, netting	0	(1)
Derivative assets, net	2	0
Derivative liabilities
Derivative liabilities, gross	0	(3)
Derivative liability, netting	0	1
Derivative liabilities, net	0	(2)
Recurring
Assets
Cash equivalents	19	19
Derivative assets
Derivative asset, netting	(265)	(498)
Derivative assets, net	123	154
Total assets	1,819	1,859
Derivative liabilities
Derivative liability, netting	265	511
Derivative liabilities, net	(107)	(146)
Net Assets (Liabilities) at the end of the period	1,712	1,713
Net Assets (Liabilities) at the end of the period, netting	0	13
Recurring | DTE Electric
Assets
Cash equivalents	11	11
Derivative assets
Total assets	1,521	1,523
Recurring | Current assets
Derivative assets
Derivative asset, netting	(213)	(437)
Total assets	97	122
Recurring | Current assets | DTE Electric
Derivative assets
Total assets	26	20
Recurring | Noncurrent assets
Derivative assets
Derivative asset, netting	(52)	(61)
Total assets	1,722	1,737
Recurring | Noncurrent assets | DTE Electric
Derivative assets
Total assets	1,495	1,503
Recurring | Current liabilities
Derivative liabilities
Derivative liability, netting	213	459
Derivative liabilities, net	(43)	(99)
Recurring | Noncurrent liabilities
Derivative liabilities
Derivative liability, netting	52	52
Derivative liabilities, net	(64)	(47)
Recurring | Restricted assets
Assets
Cash equivalents	8	8
Recurring | Other
Assets
Cash equivalents	11	11
Recurring | Other | DTE Electric
Assets
Cash equivalents	11	11
Recurring | Natural gas
Derivative assets
Derivative asset, netting	(119)	(256)
Derivative assets, net	71	101
Derivative liabilities
Derivative liability, netting	119	263
Derivative liabilities, net	(73)	(115)
Recurring | Electricity
Derivative assets
Derivative asset, netting	(146)	(241)
Derivative assets, net	35	44
Derivative liabilities
Derivative liability, netting	146	246
Derivative liabilities, net	(34)	(29)
Recurring | Other
Derivative assets
Derivative asset, netting	0	0
Derivative assets, net	15	9
Derivative liabilities
Derivative liability, netting	0	1
Derivative liabilities, net	0	0
Recurring | Foreign currency exchange contracts
Derivative assets
Derivative asset, netting	0	(1)
Derivative assets, net	2	0
Derivative liabilities
Derivative liability, netting	0	1
Derivative liabilities, net	0	(2)
Recurring | Derivative assets — FTRs | DTE Electric
Derivative assets
Derivative assets, net	15	9
Recurring | Cash equivalents
Assets
Nuclear decommissioning trusts	9	14
Other investments	4	4
Recurring | Cash equivalents | DTE Electric
Assets
Nuclear decommissioning trusts	9	14
Recurring | Private equity securities
Assets
Nuclear decommissioning trusts	10	5
Recurring | Private equity securities | DTE Electric
Assets
Nuclear decommissioning trusts	10	5
Recurring | Equity securities
Assets
Nuclear decommissioning trusts	938	978
Other investments	120	118
Recurring | Equity securities | DTE Electric
Assets
Nuclear decommissioning trusts	938	978
Other investments	11	11
Recurring | Fixed income securities
Assets
Nuclear decommissioning trusts	527	495
Other investments	69	72
Recurring | Fixed income securities | DTE Electric
Assets
Nuclear decommissioning trusts	527	495
Recurring | Level 1
Assets
Cash equivalents	16	16
Derivative assets
Derivative assets, gross	51	148
Total assets	1,213	1,368
Derivative liabilities
Derivative liabilities, gross	(54)	(141)
Net Assets (Liabilities) at the end of the period	1,159	1,227
Recurring | Level 1 | DTE Electric
Assets
Cash equivalents	8	8
Derivative assets
Total assets	972	1,029
Recurring | Level 1 | Current assets
Derivative assets
Total assets	67	157
Recurring | Level 1 | Current assets | DTE Electric
Derivative assets
Total assets	8	8
Recurring | Level 1 | Noncurrent assets
Derivative assets
Total assets	1,146	1,211
Recurring | Level 1 | Noncurrent assets | DTE Electric
Derivative assets
Total assets	964	1,021
Recurring | Level 1 | Current liabilities
Derivative liabilities
Derivative liabilities, gross	(47)	(137)
Recurring | Level 1 | Noncurrent liabilities
Derivative liabilities
Derivative liabilities, gross	(7)	(4)
Recurring | Level 1 | Natural gas
Derivative assets
Derivative assets, gross	51	148
Derivative liabilities
Derivative liabilities, gross	(53)	(141)
Recurring | Level 1 | Electricity
Derivative assets
Derivative assets, gross	0	0
Derivative liabilities
Derivative liabilities, gross	(1)	0
Recurring | Level 1 | Other
Derivative assets
Derivative assets, gross	0	0
Derivative liabilities
Derivative liabilities, gross	0	0
Recurring | Level 1 | Foreign currency exchange contracts
Derivative assets
Derivative assets, gross	0	0
Derivative liabilities
Derivative liabilities, gross	0	0
Recurring | Level 1 | Derivative assets — FTRs | DTE Electric
Derivative assets
Derivative assets, net	0	0
Recurring | Level 1 | Cash equivalents
Assets
Nuclear decommissioning trusts	9	14
Other investments	4	4
Recurring | Level 1 | Cash equivalents | DTE Electric
Assets
Nuclear decommissioning trusts	9	14
Recurring | Level 1 | Private equity securities
Assets
Nuclear decommissioning trusts	0	0
Recurring | Level 1 | Private equity securities | DTE Electric
Assets
Nuclear decommissioning trusts	0	0
Recurring | Level 1 | Equity securities
Assets
Nuclear decommissioning trusts	938	978
Other investments	120	118
Recurring | Level 1 | Equity securities | DTE Electric
Assets
Nuclear decommissioning trusts	938	978
Other investments	11	11
Recurring | Level 1 | Fixed income securities
Assets
Nuclear decommissioning trusts	6	18
Other investments	69	72
Recurring | Level 1 | Fixed income securities | DTE Electric
Assets
Nuclear decommissioning trusts	6	18
Recurring | Level 2
Assets
Cash equivalents	3	3
Derivative assets
Derivative assets, gross	241	356
Total assets	765	836
Derivative liabilities
Derivative liabilities, gross	(199)	(359)
Net Assets (Liabilities) at the end of the period	566	477
Recurring | Level 2 | DTE Electric
Assets
Cash equivalents	3	3
Derivative assets
Total assets	524	480
Recurring | Level 2 | Current assets
Derivative assets
Total assets	181	298
Recurring | Level 2 | Current assets | DTE Electric
Derivative assets
Total assets	3	3
Recurring | Level 2 | Noncurrent assets
Derivative assets
Total assets	584	538
Recurring | Level 2 | Noncurrent assets | DTE Electric
Derivative assets
Total assets	521	477
Recurring | Level 2 | Current liabilities
Derivative liabilities
Derivative liabilities, gross	(158)	(313)
Recurring | Level 2 | Noncurrent liabilities
Derivative liabilities
Derivative liabilities, gross	(41)	(46)
Recurring | Level 2 | Natural gas
Derivative assets
Derivative assets, gross	80	112
Derivative liabilities
Derivative liabilities, gross	(55)	(111)
Recurring | Level 2 | Electricity
Derivative assets
Derivative assets, gross	159	243
Derivative liabilities
Derivative liabilities, gross	(144)	(245)
Recurring | Level 2 | Other
Derivative assets
Derivative assets, gross	0	0
Derivative liabilities
Derivative liabilities, gross	0	0
Recurring | Level 2 | Foreign currency exchange contracts
Derivative assets
Derivative assets, gross	2	1
Derivative liabilities
Derivative liabilities, gross	0	(3)
Recurring | Level 2 | Derivative assets — FTRs | DTE Electric
Derivative assets
Derivative assets, net	0	0
Recurring | Level 2 | Cash equivalents
Assets
Nuclear decommissioning trusts	0	0
Other investments	0	0
Recurring | Level 2 | Cash equivalents | DTE Electric
Assets
Nuclear decommissioning trusts	0	0
Recurring | Level 2 | Private equity securities
Assets
Nuclear decommissioning trusts	0	0
Recurring | Level 2 | Private equity securities | DTE Electric
Assets
Nuclear decommissioning trusts	0	0
Recurring | Level 2 | Equity securities
Assets
Nuclear decommissioning trusts	0	0
Other investments	0	0
Recurring | Level 2 | Equity securities | DTE Electric
Assets
Nuclear decommissioning trusts	0	0
Other investments	0	0
Recurring | Level 2 | Fixed income securities
Assets
Nuclear decommissioning trusts	521	477
Other investments	0	0
Recurring | Level 2 | Fixed income securities | DTE Electric
Assets
Nuclear decommissioning trusts	521	477
Recurring | Level 3
Assets
Cash equivalents	0	0
Derivative assets
Derivative assets, gross	96	148
Total assets	96	148
Derivative liabilities
Derivative liabilities, gross	(119)	(157)
Net Assets (Liabilities) at the end of the period	(23)	(9)
Recurring | Level 3 | DTE Electric
Assets
Cash equivalents	0	0
Derivative assets
Total assets	15	9
Recurring | Level 3 | Current assets
Derivative assets
Total assets	62	104
Recurring | Level 3 | Current assets | DTE Electric
Derivative assets
Total assets	15	9
Recurring | Level 3 | Noncurrent assets
Derivative assets
Total assets	34	44
Recurring | Level 3 | Noncurrent assets | DTE Electric
Derivative assets
Total assets	0	0
Recurring | Level 3 | Current liabilities
Derivative liabilities
Derivative liabilities, gross	(51)	(108)
Recurring | Level 3 | Noncurrent liabilities
Derivative liabilities
Derivative liabilities, gross	(68)	(49)
Recurring | Level 3 | Natural gas
Derivative assets
Derivative assets, gross	59	97
Derivative liabilities
Derivative liabilities, gross	(84)	(126)
Recurring | Level 3 | Electricity
Derivative assets
Derivative assets, gross	22	42
Derivative liabilities
Derivative liabilities, gross	(35)	(30)
Recurring | Level 3 | Other
Derivative assets
Derivative assets, gross	15	9
Derivative liabilities
Derivative liabilities, gross	0	(1)
Recurring | Level 3 | Foreign currency exchange contracts
Derivative assets
Derivative assets, gross	0	0
Derivative liabilities
Derivative liabilities, gross	0	0
Recurring | Level 3 | Derivative assets — FTRs | DTE Electric
Derivative assets
Derivative assets, net	15	9
Recurring | Level 3 | Cash equivalents
Assets
Nuclear decommissioning trusts	0	0
Other investments	0	0
Recurring | Level 3 | Cash equivalents | DTE Electric
Assets
Nuclear decommissioning trusts	0	0
Recurring | Level 3 | Private equity securities
Assets
Nuclear decommissioning trusts	0	0
Recurring | Level 3 | Private equity securities | DTE Electric
Assets
Nuclear decommissioning trusts		0
Recurring | Level 3 | Equity securities
Assets
Nuclear decommissioning trusts	0	0
Other investments	0	0
Recurring | Level 3 | Equity securities | DTE Electric
Assets
Nuclear decommissioning trusts	0	0
Other investments	0	0
Recurring | Level 3 | Fixed income securities
Assets
Nuclear decommissioning trusts	0	0
Other investments	0	0
Recurring | Level 3 | Fixed income securities | DTE Electric
Assets
Nuclear decommissioning trusts	0	0
Recurring | Other
Derivative assets
Total assets	10	5
Derivative liabilities
Net Assets (Liabilities) at the end of the period	10	5
Recurring | Other | DTE Electric
Derivative assets
Total assets	10	5
Recurring | Other | Noncurrent assets
Derivative assets
Total assets	10	5
Recurring | Other | Noncurrent assets | DTE Electric
Derivative assets
Total assets	10	5
Recurring | Other | Private equity securities
Assets
Nuclear decommissioning trusts	10	5
Recurring | Other | Private equity securities | DTE Electric
Assets
Nuclear decommissioning trusts	$ 10	$ 5

XML

Fair Value (Reconciliation of Level 3 Assets and Liabilities at Fair Value on a Recurring Basis) (Details) - Recurring - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net Assets (Liabilities) as of beginning of period	$ (19)	$ (23)	$ (9)	$ (88)
Transfers into Level 3 from Level 2	0	0	0	0
Transfers from Level 3 into Level 2	0	0	(3)	0
Total gains (losses):
Included in earnings	(9)	15	(93)	58
Recorded in/Change in fair value recorded in Regulatory liabilities	15	11	15	13
Purchases, issuances, and settlements
Settlements	(10)	(9)	67	11
Net Assets (Liabilities) as of end of period	(23)	(6)	(23)	(6)
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, 2018 and 2017 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	(18)	0	(86)	32
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	5	1	9	2
Total gains (losses):
Recorded in/Change in fair value recorded in Regulatory liabilities	15	11	15	13
Purchases, issuances, and settlements
Settlements	(5)	(4)	(9)	(7)
Net Assets (Liabilities) as of end of period	15	8	15	8
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, 2018 and 2017 and reflected in DTE Electric's Consolidated Statements of Financial Position	15	8	15	8
Natural gas
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net Assets (Liabilities) as of beginning of period	(10)	(15)	(29)	(96)
Transfers into Level 3 from Level 2	0	0	0	0
Transfers from Level 3 into Level 2	0	0	(3)	0
Total gains (losses):
Included in earnings	(28)	(6)	(98)	46
Recorded in/Change in fair value recorded in Regulatory liabilities	0	0	0	0
Purchases, issuances, and settlements
Settlements	13	4	105	33
Net Assets (Liabilities) as of end of period	(25)	(17)	(25)	(17)
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, 2018 and 2017 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	(20)	(20)	(78)	16
Electricity
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net Assets (Liabilities) as of beginning of period	(13)	(6)	12	9
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	18	21	4	11
Recorded in/Change in fair value recorded in Regulatory liabilities	0	0	0	0
Purchases, issuances, and settlements
Settlements	(18)	(9)	(29)	(14)
Net Assets (Liabilities) as of end of period	(13)	6	(13)	6
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, 2018 and 2017 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	20	(6)	17
Other
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Net Assets (Liabilities) as of beginning of period	4	(2)	8	(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	1	0	1	1
Recorded in/Change in fair value recorded in Regulatory liabilities	15	11	15	13
Purchases, issuances, and settlements
Settlements	(5)	(4)	(9)	(8)
Net Assets (Liabilities) as of end of period	15	5	15	5
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, 2018 and 2017 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)	$ 0	$ (2)	$ (1)

XML

Fair Value (Unobservable Inputs related to Level 3 Assets and Liabilities) (Details) $ in Millions	Jun. 30, 2018 USD ($) $ / MMBTU $ / MWh	Dec. 31, 2017 USD ($) $ / MMBTU $ / MWh
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets	$ 388	$ 652
Derivative Liabilities	(372)	(657)
Recurring | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets	96	148
Derivative Liabilities	(119)	(157)
Natural gas
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets	190	357
Derivative Liabilities	(192)	(378)
Natural gas | Recurring | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets	59	97
Derivative Liabilities	(84)	(126)
Electricity
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets	181	285
Derivative Liabilities	(180)	(275)
Electricity | Recurring | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets	22	42
Derivative Liabilities	$ (35)	$ (30)
Forward basis price | Natural gas | Minimum | Discounted Cash Flow | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MMBTU	(1.28)	(1.10)
Forward basis price | Natural gas | Maximum | Discounted Cash Flow | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MMBTU	4.30	9.75
Forward basis price | Natural gas | Weighted Average | Discounted Cash Flow | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MMBTU	(0.13)	(0.03)
Forward basis price | Electricity | Minimum | Discounted Cash Flow | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MWh	(7)	(5)
Forward basis price | Electricity | Maximum | Discounted Cash Flow | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MWh	7	15
Forward basis price | Electricity | Weighted Average | Discounted Cash Flow | Level 3
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price | $ / MWh	0	2

XML

Fair Value (Fair Value of Financial Instruments) (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Carrying amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	$ 37	$ 38
Dividends payable	321	158
Short-term borrowings	474	621
Notes payable — Other, excluding capital leases	11	12
Long-term debt	12,708	12,288
Carrying amount | DTE Electric
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	130	238
Notes payable — Other, excluding capital leases	2	2
Long-term debt	6,537	6,017
Carrying amount | DTE Electric | Affiliates
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	75	116
Fair value | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	0	0
Dividends payable	321	158
Short-term borrowings	0	0
Notes payable — Other, excluding capital leases	0	0
Long-term debt	1,889	1,939
Fair value | Level 1 | DTE Electric
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	0	0
Notes payable — Other, excluding capital leases	0	0
Long-term debt	0	0
Fair value | Level 1 | DTE Electric | Affiliates
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	0	0
Fair value | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	0	0
Dividends payable	0	0
Short-term borrowings	474	621
Notes payable — Other, excluding capital leases	0	0
Long-term debt	10,092	10,571
Fair value | Level 2 | DTE Electric
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	130	238
Notes payable — Other, excluding capital leases	0	0
Long-term debt	6,305	6,441
Fair value | Level 2 | DTE Electric | Affiliates
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	0	0
Fair value | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, excluding capital leases	37	38
Dividends payable	0	0
Short-term borrowings	0	0
Notes payable — Other, excluding capital leases	11	12
Long-term debt	1,122	764
Fair value | Level 3 | DTE Electric
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	0	0
Notes payable — Other, excluding capital leases	2	2
Long-term debt	495	171
Fair value | Level 3 | DTE Electric | Affiliates
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Short-term borrowings	$ 75	$ 116

XML

Fair Value (Fair Value of Nuclear Decommissioning Trust Fund Assets) (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Debt Securities, Available-for-sale [Line Items]
Nuclear decommissioning trust funds	$ 1,484	$ 1,492
DTE Electric
Debt Securities, Available-for-sale [Line Items]
Nuclear decommissioning trust funds	1,484	1,492
DTE Electric | Nuclear decommissioning trust fund
Debt Securities, Available-for-sale [Line Items]
Nuclear decommissioning trust funds	1,484	1,492
DTE Electric | Nuclear decommissioning trust fund | Fermi 2
Debt Securities, Available-for-sale [Line Items]
Nuclear decommissioning trust funds	1,467	1,475
DTE Electric | Nuclear decommissioning trust fund | Fermi 1
Debt Securities, Available-for-sale [Line Items]
Nuclear decommissioning trust funds	3	3
DTE Electric | Nuclear decommissioning trust fund | Low-level radioactive waste
Debt Securities, Available-for-sale [Line Items]
Nuclear decommissioning trust funds	$ 14	$ 14

XML

Fair Value (Gains and Losses and Proceeds from the Sale of Securities by the Nuclear Decommissioning Trust Funds) (Details) - DTE Electric - Nuclear decommissioning trust fund - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Debt Securities, Available-for-sale [Line Items]
Realized gains	$ 19	$ 26	$ 42	$ 49
Realized losses	(6)	(8)	(15)	(16)
Proceeds from sale of securities	$ 280	$ 311	$ 616	$ 705

XML

Fair Value (Fair Value and Unrealized Gains and Losses for the Nuclear Decommissioning Trust Funds) (Details) - DTE Electric - Nuclear decommissioning trust fund - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Debt Securities, Available-for-sale [Line Items]
Fixed income securities, fair value	$ 527	$ 495
Private equity securities, fair value	10	5
Cash equivalents, fair value	9	14
Fair Value	1,484	1,492
Fixed income securities, unrealized gains	7	13
Unrealized Gains	307	333
Fixed income securities, unrealized losses	(8)	(3)
Unrealized Losses	(51)	(35)
Equity securities
Debt Securities, Available-for-sale [Line Items]
Fair Value	938	978
Unrealized Gains	300	320
Unrealized Losses	$ (43)	$ (32)

XML

Fair Value Fair Value (Fair Value of Fixed Income Securities Held in Nuclear Decommissioning Trust Funds (Details) - Fixed income securities - Nuclear decommissioning trust fund $ in Millions	Jun. 30, 2018 USD ($)
Debt Securities, Available-for-sale [Line Items]
Due within one year	$ 24
Due after one through five years	103
Due after five through ten years	113
Due after ten years	287
Available-for-sale securities total	$ 527

XML

Fair Value (Details Textuals) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Fair Value Disclosures [Abstract]
Equity securities realized gains (losses)	$ 1	$ 5	$ 1	$ 13
Equity securities realized loss			$ 1

XML

Financial and Other Derivative Instruments (Fair Value of Derivative Instruments) (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Derivatives, Fair Value [Line Items]
Derivative Assets	$ 388	$ 652
Derivative Liabilities	(372)	(657)
Current derivative assets
Derivatives, Fair Value [Line Items]
Derivative Assets	291	540
Current derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative Liabilities	(256)	(558)
Noncurrent derivative assets
Derivatives, Fair Value [Line Items]
Derivative Assets	97	112
Noncurrent derivative liabilities
Derivatives, Fair Value [Line Items]
Derivative Liabilities	(116)	(99)
Natural gas
Derivatives, Fair Value [Line Items]
Derivative Assets	190	357
Derivative Liabilities	(192)	(378)
Electricity
Derivatives, Fair Value [Line Items]
Derivative Assets	181	285
Derivative Liabilities	(180)	(275)
Other
Derivatives, Fair Value [Line Items]
Derivative Assets	15	9
Derivative Liabilities	0	(1)
Foreign currency exchange contracts
Derivatives, Fair Value [Line Items]
Derivative Assets	2	1
Derivative Liabilities	0	(3)
Derivatives not designated as hedging instruments
Derivatives, Fair Value [Line Items]
Derivative Assets	388	652
Derivative Liabilities	(372)	(657)
Derivatives not designated as hedging instruments | DTE Electric
Derivatives, Fair Value [Line Items]
Derivative Assets	15	9
Derivatives not designated as hedging instruments | Natural gas
Derivatives, Fair Value [Line Items]
Derivative Assets	190	357
Derivative Liabilities	(192)	(378)
Derivatives not designated as hedging instruments | Electricity
Derivatives, Fair Value [Line Items]
Derivative Assets	181	285
Derivative Liabilities	(180)	(275)
Derivatives not designated as hedging instruments | Other
Derivatives, Fair Value [Line Items]
Derivative Assets	15	9
Derivative Liabilities	0	(1)
Derivatives not designated as hedging instruments | Foreign currency exchange contracts
Derivatives, Fair Value [Line Items]
Derivative Assets	2	1
Derivative Liabilities	0	(3)
Derivatives not designated as hedging instruments | FTRs — Other current assets | DTE Electric
Derivatives, Fair Value [Line Items]
Derivative Assets	$ 15	$ 9

XML

Financial and Other Derivative Instruments (Details Textuals) - USD ($)	Jun. 30, 2018	Dec. 31, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Letters of credit that could be used to offset net derivative liabilities	$ 1,000,000	$ 4,000,000
Letters of credit received that could be used to offset net derivative assets	6,000,000	4,000,000
Cash collateral posted, net of cash collateral received	19,000,000	28,000,000
Collateral adjustment on derivative assets	0	9,000,000
Collateral adjustment on derivative liabilities	0	22,000,000
Cash collateral paid	24,000,000	18,000,000
Cash collateral received	5,000,000	$ 3,000,000
Additional collateral, aggregate fair value	508,000,000
Derivative net liability position aggregate fair value	283,000,000
Collateral already posted fair value	0
Derivative net asset position, fair value	247,000,000
Remaining amount of offsets to derivative net liability positions for hard and soft trigger provisions	$ 36,000,000

XML

Financial and Other Derivative Instruments (Netting Offsets of Derivative Assets and Liabilities) (Details) - USD ($) $ in Millions	Jun. 30, 2018	Dec. 31, 2017
Derivative assets
Gross Amounts of Recognized Assets (Liabilities)	$ 388	$ 652
Gross Amounts Offset in the Consolidated Statements of Financial Position	(265)	(498)
Derivative assets, net	123	154
Derivative liabilities
Gross Amounts of Recognized Assets (Liabilities)	(372)	(657)
Gross Amounts Offset in the Consolidated Statements of Financial Position	265	511
Derivative liabilities, net	(107)	(146)
Natural gas
Derivative assets
Gross Amounts of Recognized Assets (Liabilities)	190	357
Gross Amounts Offset in the Consolidated Statements of Financial Position	(119)	(256)
Derivative assets, net	71	101
Derivative liabilities
Gross Amounts of Recognized Assets (Liabilities)	(192)	(378)
Gross Amounts Offset in the Consolidated Statements of Financial Position	119	263
Derivative liabilities, net	(73)	(115)
Electricity
Derivative assets
Gross Amounts of Recognized Assets (Liabilities)	181	285
Gross Amounts Offset in the Consolidated Statements of Financial Position	(146)	(241)
Derivative assets, net	35	44
Derivative liabilities
Gross Amounts of Recognized Assets (Liabilities)	(180)	(275)
Gross Amounts Offset in the Consolidated Statements of Financial Position	146	246
Derivative liabilities, net	(34)	(29)
Other
Derivative assets
Gross Amounts of Recognized Assets (Liabilities)	15	9
Gross Amounts Offset in the Consolidated Statements of Financial Position	0	0
Derivative assets, net	15	9
Derivative liabilities
Gross Amounts of Recognized Assets (Liabilities)	0	(1)
Gross Amounts Offset in the Consolidated Statements of Financial Position	0	1
Derivative liabilities, net	0	0
Foreign currency exchange contracts
Derivative assets
Gross Amounts of Recognized Assets (Liabilities)	2	1
Gross Amounts Offset in the Consolidated Statements of Financial Position	0	(1)
Derivative assets, net	2	0
Derivative liabilities
Gross Amounts of Recognized Assets (Liabilities)	0	(3)
Gross Amounts Offset in the Consolidated Statements of Financial Position	0	1
Derivative liabilities, net	$ 0	$ (2)

XML

Financial and Other Derivative Instruments (Netting Offsets Reconciliation to Balance Sheet) (Details) - USD ($)	Jun. 30, 2018	Dec. 31, 2017
Derivative Assets
Derivative Assets	$ 388,000,000	$ 652,000,000
Collateral adjustment	0	(9,000,000)
Derivative assets, current	78,000,000	103,000,000
Derivative assets, noncurrent	45,000,000	51,000,000
Derivative Liabilities
Derivative Liabilities	(372,000,000)	(657,000,000)
Collateral adjustment	0	22,000,000
Derivative liabilities, current	(43,000,000)	(99,000,000)
Derivative liabilities, noncurrent	(64,000,000)	(47,000,000)
Current derivative assets
Derivative Assets
Derivative Assets	291,000,000	540,000,000
Counterparty netting	(213,000,000)	(437,000,000)
Collateral adjustment	0	0
Derivative assets, current	78,000,000	103,000,000
Noncurrent derivative assets
Derivative Assets
Derivative Assets	97,000,000	112,000,000
Counterparty netting	(52,000,000)	(52,000,000)
Collateral adjustment	0	(9,000,000)
Derivative assets, noncurrent	45,000,000	51,000,000
Current derivative liabilities
Derivative Liabilities
Derivative Liabilities	(256,000,000)	(558,000,000)
Counterparty netting	213,000,000	437,000,000
Collateral adjustment	0	22,000,000
Derivative liabilities, current	(43,000,000)	(99,000,000)
Noncurrent derivative liabilities
Derivative Liabilities
Derivative Liabilities	(116,000,000)	(99,000,000)
Counterparty netting	52,000,000	52,000,000
Collateral adjustment	0	0
Derivative liabilities, noncurrent	$ (64,000,000)	$ (47,000,000)

XML

Financial and Other Derivative Instruments (Effect of Derivatives not Designated as Hedging Instruments on the Consolidated Statement of Operations) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	$ 0	$ 16	$ (74)	$ 127
Natural gas | Operating Revenues — Non-utility operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	(48)	20	(158)	77
Natural gas | Fuel, purchased power, and gas — non-utility
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	16	(15)	68	46
Electricity | Operating Revenues — Non-utility operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	28	13	11	6
Other | Operating Revenues — Non-utility operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	2	(1)	1	(1)
Foreign currency exchange contracts | Operating Revenues — Non-utility operations
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivatives	$ 2	$ (1)	$ 4	$ (1)

XML

Financial and Other Derivative Instruments (Cumulative Gross Volume of Derivative Contracts Outstanding) (Details)	6 Months Ended
	Jun. 30, 2018 CAD ($) MWh MMBTU
Natural gas (MMBtu)
Derivative [Line Items]
Commodity | MMBTU	1,908,431,324
Electricity (MWh)
Derivative [Line Items]
Commodity | MWh	39,463,885
Foreign currency exchange (Canadian dollars)
Derivative [Line Items]
Foreign currency exchange (Canadian dollars) | $	$ 101,077,223

XML

Long-Term Debt (Details) - USD ($)	6 Months Ended
	Jun. 30, 2018	Aug. 31, 2018
Debt Instrument [Line Items]
Debt issued	$ 525,000,000
Debt redeemed	102,000,000
Other Long-Term Debt | DTE Energy
Debt Instrument [Line Items]
Debt redeemed	$ 2,000,000
DTE Electric | Mortgage Bonds | May 2018 4.05% Mortgage Bonds Maturing in 2048
Debt Instrument [Line Items]
Interest rate	4.05%
Debt issued	$ 525,000,000
DTE Gas | Mortgage Bonds | August 2018 3.81% First Mortgage Bonds Maturing 2028 | Forecast
Debt Instrument [Line Items]
Interest rate		3.81%
Debt issued		$ 195,000,000
DTE Gas | Mortgage Bonds | August 2018 3.81% First Mortgage Bonds Maturing 2048 | Forecast
Debt Instrument [Line Items]
Interest rate		4.14%
Debt issued		$ 125,000,000
DTE Gas | Senior Notes | 6.04% Senior Notes Due 2018
Debt Instrument [Line Items]
Interest rate	6.04%
Debt redeemed	$ 100,000,000

XML

Short-Term Credit Arrangements and Borrowings (Details Textuals)	Jun. 30, 2018 USD ($)	Dec. 31, 2017 USD ($)
Short-term Debt [Line Items]
Other outstanding letters of credit	$ 621,000,000
Letter of credit
Short-term Debt [Line Items]
Other outstanding letters of credit	$ 147,000,000
DTE Electric
Short-term Debt [Line Items]
Ratio of indebtedness to net capital	0.51
Other outstanding letters of credit	$ 130,000,000
DTE Electric | Letter of credit
Short-term Debt [Line Items]
Other outstanding letters of credit	$ 0
DTE Gas
Short-term Debt [Line Items]
Ratio of indebtedness to net capital	0.45
Other outstanding letters of credit	$ 167,000,000
DTE Gas | Letter of credit
Short-term Debt [Line Items]
Other outstanding letters of credit	$ 0
DTE Energy
Short-term Debt [Line Items]
Ratio of indebtedness to net capital	0.54
Other outstanding letters of credit	$ 324,000,000
DTE Energy | Letter of credit
Short-term Debt [Line Items]
Other outstanding letters of credit	147,000,000
DTE Energy | Demand financing agreement
Short-term Debt [Line Items]
Maximum borrowing capacity, financing agreement	100,000,000
Maximum additional margin financing	50,000,000
Amount outstanding	30,000,000	$ 56,000,000
DTE Energy | Demand financing agreement plus letter of credit
Short-term Debt [Line Items]
Maximum borrowing capacity, financing agreement	125,000,000
DTE Energy | Other outstanding letters of credit | Letter of credit
Short-term Debt [Line Items]
Other outstanding letters of credit	$ 9,000,000
Maximum
Short-term Debt [Line Items]
Ratio of indebtedness to net capital	0.65

XML

Short-Term Credit Arrangements and Borrowings (Details)	Jun. 30, 2018 USD ($)
Availability under combined facilities
Maximum borrowing capacity	$ 2,120,000,000
Amounts outstanding	621,000,000
Net availability	1,499,000,000
DTE Electric
Availability under combined facilities
Maximum borrowing capacity	400,000,000
Amounts outstanding	130,000,000
Net availability	270,000,000
DTE Gas
Availability under combined facilities
Maximum borrowing capacity	300,000,000
Amounts outstanding	167,000,000
Net availability	133,000,000
DTE Energy
Availability under combined facilities
Maximum borrowing capacity	1,420,000,000
Amounts outstanding	324,000,000
Net availability	1,096,000,000
Letter of credit
Availability under combined facilities
Amounts outstanding	147,000,000
Letter of credit | DTE Electric
Availability under combined facilities
Amounts outstanding	0
Letter of credit | DTE Gas
Availability under combined facilities
Amounts outstanding	0
Letter of credit | DTE Energy
Availability under combined facilities
Amounts outstanding	147,000,000
Letter of credit | Unsecured letter of credit facility, expiring in February 2019
Availability under combined facilities
Maximum borrowing capacity	150,000,000
Letter of credit | Unsecured letter of credit facility, expiring in February 2019 | DTE Electric
Availability under combined facilities
Maximum borrowing capacity	0
Letter of credit | Unsecured letter of credit facility, expiring in February 2019 | DTE Gas
Availability under combined facilities
Maximum borrowing capacity	0
Letter of credit | Unsecured letter of credit facility, expiring in February 2019 | DTE Energy
Availability under combined facilities
Maximum borrowing capacity	150,000,000
Letter of credit | Unsecured letter of credit facility, expiring in September 2019
Availability under combined facilities
Maximum borrowing capacity	70,000,000
Letter of credit | Unsecured letter of credit facility, expiring in September 2019 | DTE Electric
Availability under combined facilities
Maximum borrowing capacity	0
Letter of credit | Unsecured letter of credit facility, expiring in September 2019 | DTE Gas
Availability under combined facilities
Maximum borrowing capacity	0
Letter of credit | Unsecured letter of credit facility, expiring in September 2019 | DTE Energy
Availability under combined facilities
Maximum borrowing capacity	70,000,000
Revolving credit facility | Unsecured revolving credit facility, expiring April 2022
Availability under combined facilities
Maximum borrowing capacity	1,900,000,000
Revolving credit facility | Unsecured revolving credit facility, expiring April 2022 | DTE Electric
Availability under combined facilities
Maximum borrowing capacity	400,000,000
Revolving credit facility | Unsecured revolving credit facility, expiring April 2022 | DTE Gas
Availability under combined facilities
Maximum borrowing capacity	300,000,000
Revolving credit facility | Unsecured revolving credit facility, expiring April 2022 | DTE Energy
Availability under combined facilities
Maximum borrowing capacity	1,200,000,000
Commercial paper issuances
Availability under combined facilities
Amounts outstanding	474,000,000
Commercial paper issuances | DTE Electric
Availability under combined facilities
Amounts outstanding	130,000,000
Commercial paper issuances | DTE Gas
Availability under combined facilities
Amounts outstanding	167,000,000
Commercial paper issuances | DTE Energy
Availability under combined facilities
Amounts outstanding	$ 177,000,000

XML

Commitments and Contingencies (Details Textuals) $ in Millions		6 Months Ended	12 Months Ended
	Jun. 14, 2018	Jun. 30, 2018 USD ($) employee facility NOV site	Dec. 31, 2017 USD ($)	Jul. 31, 2009 plant
Loss Contingencies [Line Items]
Period case was stayed for, pending settlement negotiations	180 days
Unrecorded unconditional purchase obligation		$ 3,600
Workforce subject to collective bargaining arrangements | Labor force concentration risk
Loss Contingencies [Line Items]
Number of employees | employee		5,000
Synthetic fuel
Loss Contingencies [Line Items]
Number of days after expiration of statutes of limitations		90 days
Maximum potential liability		$ 400
Reduced emissions fuel guarantees
Loss Contingencies [Line Items]
Number of days after expiration of statutes of limitations		90 days
Maximum potential liability		$ 453
NEXUS pipeline
Loss Contingencies [Line Items]
Guarantee termination, minimum threshold, period following end of primary term of capacity lease agreements		2 months
Other guarantees
Loss Contingencies [Line Items]
Maximum potential liability		$ 56
Performance surety bonds
Loss Contingencies [Line Items]
Performance bonds outstanding		$ 59
DTE Electric
Loss Contingencies [Line Items]
Number of power plants in violation | plant				5
Number of NOVs/FOVs | NOV		2
Environmental capital expenditures through prior year end			$ 2,400
Number of former MGP sites | site		3
Accrued for remediation		$ 5	6
Number of permitted engineered ash storage facilities owned | facility		3
Unrecorded unconditional purchase obligation		$ 1,900
DTE Electric | Workforce subject to collective bargaining arrangements | Labor force concentration risk
Loss Contingencies [Line Items]
Number of employees | employee		2,700
DTE Gas
Loss Contingencies [Line Items]
Number of former MGP sites | site		14
Accrued for remediation		$ 37	$ 41
Amortization period (in years)		10 years
DTE Gas | NEXUS pipeline
Loss Contingencies [Line Items]
Maximum potential liability		$ 84
Lease agreement term		15 years
Percentage of payment obligations due		50.00%
DTE Gas | Clean up completed and site closed
Loss Contingencies [Line Items]
Number of former MGP sites | site		6
DTE Gas | Partial closure complete
Loss Contingencies [Line Items]
Number of former MGP sites | site		6
Texas Eastern Transmission, LP | NEXUS pipeline
Loss Contingencies [Line Items]
Maximum potential liability		$ 23
Lease agreement term		15 years
Percentage of payment obligations due		50.00%

XML

Retirement Benefits and Trusteed Assets (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 25	$ 23	$ 50	$ 47
Interest cost	50	53	100	107
Expected return on plan assets	(83)	(77)	(165)	(155)
Amortization of net actuarial loss	45	43	89	86
Amortization of prior service credit	0	0	0	0
Net periodic benefit cost (credit)	37	42	74	85
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	7	6	14	13
Interest cost	17	19	34	37
Expected return on plan assets	(35)	(32)	(71)	(65)
Amortization of net actuarial loss	2	4	5	7
Amortization of prior service credit	0	(4)	0	(7)
Net periodic benefit cost (credit)	(9)	(7)	(18)	(15)
Other Postretirement Benefits | DTE Electric
Defined Benefit Plan Disclosure [Line Items]
Service cost	5	5	10	10
Interest cost	14	14	27	28
Expected return on plan assets	(25)	(22)	(49)	(45)
Amortization of net actuarial loss	2	2	4	4
Amortization of prior service credit	0	(3)	0	(5)
Net periodic benefit cost (credit)	$ (4)	$ (4)	$ (8)	$ (8)

XML

Retirement Benefits and Trusteed Assets (Details Textuals) - USD ($)	1 Months Ended	3 Months Ended		6 Months Ended
	Mar. 31, 2018	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Maximum contribution amount		$ 25,000,000		$ 25,000,000
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Maximum contribution amount		0		0
DTE Electric | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Pension cost	$ 175,000,000	30,000,000	$ 34,000,000	60,000,000	$ 69,000,000
Maximum contribution amount		$ 0		$ 0

XML

Retirement Benefits and Trusteed Assets - VEBA Contributions (Details) - USD ($) $ / shares in Units, $ in Millions		6 Months Ended
	Mar. 07, 2018	Jun. 30, 2018
Defined Contribution Plan Disclosure [Line Items]
Amount		$ 175
Pension Benefits
Defined Contribution Plan Disclosure [Line Items]
Number of Shares (in shares)	1,751,401
Price per Share (in dollars per share)	$ 99.92
Amount	$ 175

XML

Segment and Related Information (Details Textuals) customer in Millions	Jun. 30, 2018 customer
Segment Reporting [Abstract]
Number of electric utility customers	2.2
Number of gas utility customers	1.3

XML

Segment and Related Information (Financial Data - Inter-segment Billing) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Segment Reporting Information [Line Items]
Revenues	$ (3,159)	$ (2,855)	$ (6,912)	$ (6,091)
Electric
Segment Reporting Information [Line Items]
Revenues	(1,276)		(2,481)
Gas
Segment Reporting Information [Line Items]
Revenues	(255)		(805)
Gas Storage and Pipelines
Segment Reporting Information [Line Items]
Revenues	(122)		(241)
Power and Industrial Projects
Segment Reporting Information [Line Items]
Revenues	(538)		(1,105)
Energy Trading
Segment Reporting Information [Line Items]
Revenues	(1,164)		(2,662)
Reconciliation and Eliminations
Segment Reporting Information [Line Items]
Revenues	198	194	384	396
Reconciliation and Eliminations | Electric
Segment Reporting Information [Line Items]
Revenues	13	13	26	25
Reconciliation and Eliminations | Gas
Segment Reporting Information [Line Items]
Revenues	4	2	6	5
Reconciliation and Eliminations | Gas Storage and Pipelines
Segment Reporting Information [Line Items]
Revenues	14	15	22	22
Reconciliation and Eliminations | Power and Industrial Projects
Segment Reporting Information [Line Items]
Revenues	162	156	317	324
Reconciliation and Eliminations | Energy Trading
Segment Reporting Information [Line Items]
Revenues	5	8	12	19
Reconciliation and Eliminations | Corporate and Other
Segment Reporting Information [Line Items]
Revenues	$ 0	$ 0	$ 1	$ 1

XML

Segment and Related Information (Financial Data - Operating Revenues including Inter-segment Revenues) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues — Utility operations	$ 1,514	$ 1,423	$ 3,254	$ 3,141
Operating Revenues — Non-utility operations	1,645	1,432	3,658	2,950
Operating Revenues	3,159	2,855	6,912	6,091
Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues — Non-utility operations	(198)	(194)	(384)	(396)
Operating Revenues	(198)	(194)	(384)	(396)
Electric
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	1,276		2,481
Electric | Operating segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues — Utility operations	1,276	1,218	2,481	2,393
Electric | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	(13)	(13)	(26)	(25)
Gas
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	255		805
Gas | Operating segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues — Utility operations	255	220	805	777
Gas | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	(4)	(2)	(6)	(5)
Gas Storage and Pipelines
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	122		241
Gas Storage and Pipelines | Operating segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues — Non-utility operations	122	113	241	218
Gas Storage and Pipelines | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	(14)	(15)	(22)	(22)
Power and Industrial Projects
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	538		1,105
Power and Industrial Projects | Operating segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues — Non-utility operations	538	507	1,105	1,055
Power and Industrial Projects | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	(162)	(156)	(317)	(324)
Energy Trading
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	1,164		2,662
Energy Trading | Operating segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues — Non-utility operations	1,164	991	2,662	2,043
Energy Trading | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	(5)	(8)	(12)	(19)
Corporate and Other | Operating segments
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues — Non-utility operations	2	0	2	1
Corporate and Other | Reconciliation and Eliminations
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	$ 0	$ 0	$ (1)	$ (1)

XML

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, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income Attributable to DTE Energy Company	$ 234	$ 177	$ 595	$ 577
Electric
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income Attributable to DTE Energy Company	163	138	303	244
Gas
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income Attributable to DTE Energy Company	14	1	118	108
Gas Storage and Pipelines
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income Attributable to DTE Energy Company	60	40	122	85
Power and Industrial Projects
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income Attributable to DTE Energy Company	43	30	88	60
Energy Trading
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income Attributable to DTE Energy Company	(5)	0	26	96
Corporate and Other
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income Attributable to DTE Energy Company	$ (41)	$ (32)	$ (62)	$ (16)