UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

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

For the Fiscal Year Ended December 31, ~~2015~~2017



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

1-2198	DTE Electric Company (a Michigan corporation) One Energy Plaza Detroit, Michigan 48226-1279 313-235-4000	38-0478650

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



Registrant	Title of Each Class	Name of Exchange on which Registered
DTE Energy Company (DTE Energy)	Common stock, without par value	New York Stock Exchange

DTE Energy	~~2011~~2012 Series ~~I 6.5%~~C 5.25% Junior Subordinated Debentures due ~~2061~~2062	New York Stock Exchange

DTE Energy	~~2012~~2016 Series CB 5.375% Junior Subordinated Debentures due 2076	New York Stock Exchange

DTE Energy	2016 Series F 6.00% Junior Subordinated Debentures due 2076	New York Stock Exchange

DTE Energy	2017 Series E 5.25% Junior Subordinated Debentures due ~~2062~~2077	New York Stock Exchange

DTE Energy	6.50% Corporate Units	New York Stock Exchange

DTE Electric Company (DTE Electric)	None	None

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

~~DTE Energy NoneDTE Electric None~~



DTE Energy	None	DTE Electric	None

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.



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

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.



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

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

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of the registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.

~~DTE Energy~~ x~~DTE Electric~~ x



DTE Energy	x	DTE Electric	x

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, ~~or a~~ smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated ~~filer” and~~filer,” “smaller reporting ~~company”~~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	~~DTE Energy Yes~~ o No x~~DTE Electric~~ Yes o No x	DTE Electric	Yes o No x

On June 30, ~~2015,~~2017, the aggregate market value of DTE Energy's voting and non voting common equity held by non-affiliates was approximately ~~$12.9 billion(based~~$18.7 billion (based on the New York Stock Exchange closing price on such date).

Number of shares of Common Stock outstanding at January ~~29, 2016:~~31, 2018:



Registrant	Description	Shares
DTE Energy	Common Stock, without par value	~~179,476,008~~179,385,962

DTE Electric	Common Stock, $10 par value, directly-owned by DTE Energy	138,632,324

DOCUMENTS INCORPORATED BY REFERENCE

Certain information in DTE Energy's definitive Proxy Statement for its ~~2016~~2018 Annual Meeting of Common Shareholders to be held May ~~5, 2016,~~3, 2018, which will be filed with the Securities and Exchange Commission pursuant to Regulation 14A, not later than 120 days after the end of the registrant’s fiscal year covered by this report on Form 10-K, is incorporated herein by reference to Part III (Items 10, 11, 12, 13, and 14) of this Form 10-K.

This combined Form 10-K 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 I(1)(a) and (b) of Form 10-K and is therefore filing this form with the reduced disclosure format specified in General Instruction I(2) of Form 10-K.

TABLE OF CONTENTS



		Page
	Definitions	1
	Filing Format	35
	Forward-Looking Statements	35
PART I
Items 1. & 2.	Business and Properties	57
Item 1A.	Risk Factors	1820
Item 1B.	Unresolved Staff Comments	2225
Item 3.	Legal Proceedings	2225
Item 4.	Mine Safety Disclosures	2226
PART II
Item 5.	Market for Registrant’s Common Equity, Related Stockholder Matters, and Issuer Purchases of Equity Securities	2327
Item 6.	Selected Financial Data	2629
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	2629
Item 7A.	Quantitative and Qualitative Disclosures About Market Risk	4752
Item 8.	Financial Statements and Supplementary Data	5055
Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	~~133~~140
Item 9A.	Controls and Procedures	~~133~~140
Item 9B.	Other Information	~~133~~140
PART III
Item 10.	Directors, Executive Officers, and Corporate Governance	~~133~~140
Item 11.	Executive Compensation	~~133~~140
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	~~133~~140
Item 13.	Certain Relationships and Related Transactions, and Director Independence	~~133~~140
Item 14.	Principal Accountant Fees and Services	~~133~~140
PART IV
Item 15.	Exhibits and Financial Statement Schedules	~~135~~142
Item 16.	Form 10-K Summary	152
	Signatures	~~146~~154

~~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.

AMV	Applicable Market Value

ANPR	Advanced Noticed of Proposed Rulemaking

ARO	Asset Retirement Obligation

ASU	Accounting Standards Update issued by the FASB

CCR	Coal Combustion Residuals

CFTC	U.S. Commodity Futures Trading Commission

~~COA~~CON	~~U.S. Court~~Certificate of ~~Appeals for the District of Columbia~~Necessity

DOE	U.S. Department of Energy

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

IRM	Infrastructure Recovery Mechanism

IRS	Internal Revenue Service

~~MBT~~ISO	~~Michigan Business Tax~~Independent System Operator

~~MCIT~~LIBOR	~~Michigan Corporate Income Tax~~London Inter-Bank Offered Rates

~~MCOA~~LLC	~~Michigan Court~~DTE Energy Corporate Services, LLC, a subsidiary of ~~Appeals~~DTE Energy

MDEQ	Michigan Department of Environmental Quality

MGP	Manufactured Gas Plant

MISO	Midcontinent Independent System Operator, Inc.

MPSC	Michigan Public Service Commission

MTM	Mark-to-market




NAV	Net Asset Value

NEIL	Nuclear Electric Insurance Limited

NEXUS	NEXUS Gas Transmission, LLC, a joint venture in which DTE Energy owns 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

NO_x	Nitrogen Oxides

NRC	U.S. Nuclear Regulatory Commission

PLD	City of Detroit's Public Lighting Department

~~DEFINITIONS~~



Production tax credits	Tax credits as authorized under Sections 45K and 45 of the Internal Revenue Code that are designed to stimulate investment in and development of alternate fuel sources. The amount of a production tax credit can vary each year as determined by the IRS.

PSCR	A Power Supply Cost Recovery mechanism authorized by the MPSC that allows DTE Electric to recover through rates its fuel, fuel-related, and purchased power costs.

RDM	A Revenue Decoupling Mechanism authorized by the MPSC that is designed to minimize the impact on revenues of changes in average customer usage.

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.

RSN	Remarketable Senior Notes

RTO	Regional Transmission Organization

SEC	Securities and Exchange Commission

Securitization	DTE Electric financed specific stranded costs at lower interest rates through the sale of rate reduction bonds by a wholly-owned special purpose entity, The Detroit Edison Securitization Funding LLC.

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.

Shenango	Shenango Incorporated is a coke battery plant located in Pittsburgh, PA, that was closed in January 2016 and is included in the Power and Industrial Projects segment.

SO₂	Sulfur Dioxide

TCJA	Tax Cuts and Jobs Act of 2017

TRIA	Terrorism Risk Insurance Program Reauthorization Act of 2015

TRM	A Transitional Reconciliation Mechanism authorized by the MPSC that allows DTE Electric to recover through rates the deferred net incremental revenue requirement associated with the transition of PLD customers to DTE Electric's distribution system.

VEBA	Voluntary Employees Beneficiary Association

VIE	Variable Interest Entity



Units of Measurement

Bcf	Billion cubic feet of natural gas

BTU	~~Heat~~British thermal unit, heat value (energy content) of fuel

kWh	Kilowatthour of electricity

~~Mcf~~MDth/d	~~Thousand cubic feet of gas~~Million dekatherms per day

MMBtu	One million BTU

~~MMcf/d~~	~~Million cubic feet of gas per day~~

MW	Megawatt of electricity

MWh	Megawatthour of electricity

THIS PAGE INTENTIONALLY LEFT BLANK

FILING FORMAT

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

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

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

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

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

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

changes in the 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;

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 ~~construction~~capital projects;

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

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

unplanned outages;

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

employee relations and the impact of collective bargaining agreements;

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

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

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

the effects of competition;

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

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

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

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

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

Part I

Items 1. and 2. Business and Properties

General

In 1995, DTE Energy incorporated in the State of Michigan. DTE Energy's utility operations consist primarily of DTE Electric and DTE Gas. DTE Energy also has three other segments that are engaged in a variety of energy-related businesses.

DTE Electric is a Michigan corporation organized in 1903 and is a wholly-owned subsidiary of DTE Energy. 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 Michigan corporation organized in 1898 and is a wholly-owned subsidiary of DTE Energy. DTE Gas is a public utility engaged in the purchase, storage, transportation, distribution, and sale of natural gas to approximately ~~1.2~~1.3 million customers throughout Michigan and the sale of storage and transportation capacity.

DTE Energy's other businesses are involved in 1) natural gas pipelines, gathering, and storage; 2) power and industrial projects; and 3) energy marketing and trading operations.

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

The Registrants' annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, proxy statements, and all amendments to such reports are available free of charge through the Investors - Reports and Filings page of DTE Energy's website: www.dteenergy.com, as soon as reasonably practicable after they are filed with or furnished to the SEC. ~~The Registrants' previously filed reports and statements are also available at the SEC’s website:~~ ~~www.sec.gov~~.

The DTE Energy Code of Ethics and Standards of Behavior, Board of Directors’ Mission and Guidelines, Board Committee Charters, and Categorical Standards for Director Independence are also posted on the DTE Energy website. The information on DTE Energy’s website is not part of this report or any other report that DTE Energy files with, or furnishes to, the SEC.

Additionally, the public may read and copy any materials the Registrants file with the SEC at the SEC’s Public Reference Room at 100 F Street, NE, Room 1580, Washington, D.C. 20549. The public may obtain information on the operation of the Public Reference Room by calling the SEC at 1-800-SEC-0330. The SEC also maintains an ~~Internet~~internet site that contains reports, proxy and information statements, and other information regarding issuers that file electronically with the SEC at www.sec.gov.

Corporate Structure

~~Based on the following structure,~~ DTE Energy sets strategic goals, allocates resources, and evaluates ~~performance.~~performance based on the following structure. For financial information by segment for the last three years, see Note 2022 to the Consolidated Financial Statements in Item 8 of this Report, "Segment and Related ~~Information".~~Information."

Electric

The 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

The Gas segment consists principally of DTE Gas, which is engaged in the purchase, storage, transportation, distribution, and sale of natural gas to approximately ~~1.2~~1.3 million residential, commercial, and industrial customers throughout Michigan and the sale of ~~gas~~ storage and transportation capacity.

Non-utility Operations

Gas Storage and Pipelines consists of natural gas ~~pipelines,~~pipeline, gathering, transportation, and storage businesses.

Energy Trading consists of energy marketing and trading operations.

Corporate and Other

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

Refer to Management’s Discussion and Analysis in Item 7 of this Report for an in-depth analysis of each segment’s financial results. A description of each business unit follows.

ELECTRIC

Description

DTE Energy's Electric segment consists principally of DTE Electric, an electric utility engaged in the generation, purchase, distribution, and sale of electricity to approximately 2.2 million customers in southeastern Michigan. DTE Electric is regulated by numerous federal and state governmental agencies, including, but not limited to, the MPSC, the FERC, the NRC, the EPA, and the MDEQ. Electricity is generated from fossil-fuel plants, a hydroelectric pumped storage plant, a nuclear plant, wind and other renewable assets and is supplemented with purchased power. The electricity is sold, or distributed through the retail access program, to three major classes of customers: residential, commercial, and industrial, throughout southeastern Michigan.

Operating Revenues by Service


	2015		2014		2013		2017		2016		2015
	(In millions)						(In millions)
Residential	$	2,186	$	2,168	$	2,351	$	2,310	$	2,477	$	2,186
Commercial	1,701		1,761		1,883		1,758		1,754		1,701
Industrial	645		767		799		667		654		645
Other (a)	281		494		45		313		290		281
Subtotal	4,813		5,190		5,078		5,048		5,175		4,813
Interconnection sales (b)	88		93		121		54		50		88
Electric segment Operating Revenues	$	4,901	$	5,283	$	5,199	$	5,102	$	5,225	$	4,901


(a)	Includes revenue associated with the under or over recoveries of tracking mechanisms and for 2015 deferred gain amortization of the previously reversed RDM liability.


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

Weather, economic factors, competition, energy efficiency initiatives, and electricity prices affect sales levels to customers. DTE Electric's peak load and highest total system sales generally occur during the third quarter of the year, driven by air conditioning and other cooling-related demands. DTE Electric's operations are not dependent upon a limited number of customers, and the loss of any one or a few customers would not have a material adverse effect on the results of DTE Electric.

Fuel Supply and Purchased Power

DTE Electric's power is generated from a variety of fuels and is supplemented with purchased power. DTE Electric expects to have an adequate supply of fuel and purchased power to meet its obligation to serve customers. DTE Electric's generating capability is heavily dependent upon the availability of coal. Coal is purchased from various sources in different geographic areas under agreements that vary in both pricing and terms. DTE Electric expects to obtain the majority of its coal requirements through long-term contracts, with the balance to be obtained through short-term agreements and spot purchases. DTE Electric has long-term and short-term contracts for the purchase of approximately ~~37.9~~26.7 million tons of low-sulfur western coal and approximately ~~3.0~~1 million tons of Appalachian coal to be delivered from ~~2016~~2018 to 2021. All of these contracts have pricing schedules. DTE Electric has approximately ~~98%~~94% of the expected coal requirements for ~~2016~~2018 under contract. Given the geographic diversity of supply, DTE Electric believes it can meet its expected generation requirements. DTE Electric leases a fleet of rail cars and has the expected western and eastern coal rail requirements under contract through ~~2018. All of the expected eastern coal rail requirements are under contract through 2016.~~2021. Contracts covering expected vessel transportation requirements for delivery of purchased coal to electric generating facilities are under contract through 2019.

DTE Electric participates in the energy market through MISO. DTE Electric offers its generation in the market on a day-ahead and real-time basis and bids for power in the market to serve its load. DTE Electric is a net purchaser of power that supplements its generation capability to meet customer demand during peak cycles or during major plant outages.

Properties

DTE Electric owns generating facilities that are located in the State of Michigan. Substantially all of DTE Electric's property is subject to the lien of a mortgage.

Generating facilities owned and in service as of December 31, ~~2015~~2017 are shown in the following table:


	Location by Michigan		Net Generation Capacity (a)	Location by Michigan County				Net Generation Capacity^(a)
Facility	County	Year in Service	(MW)		Year in Service		(MW)
Fossil-fueled Steam-Electric
Belle River (b)	St. Clair	1984 and 1985	1,034	Location by Michigan County	St. Clair		1984 and 1985		1,034
Greenwood	St. Clair	1979	785	St. Clair		1979		785
Monroe (c)	Monroe	1971, 1973, and 1974	3,066	Monroe		1971, 1973, and 1974		3,066
River Rouge	Wayne	1957 and 1958	523	Wayne		1958		272
St. Clair	St. Clair	1953, 1954, 1959, 1961, and 1969	1,367	St. Clair		1953, 1954, 1961, and 1969		1,216
Trenton Channel	Wayne	1949 and 1968	630	Wayne		1968		520
			7,405					6,893
Natural gas and Oil-fueled Peaking Units	Various	1966-1971, 1981, 1999, 2002, and 2003	2,009	Various		1966-1971, 1981, 1999, 2002, and 2003		2,033
Nuclear-fueled Steam-Electric Fermi 2	Monroe	1988	1,124	Monroe		1988		1,141
Hydroelectric Pumped Storage Ludington (d)	Mason	1973	958	Mason		1973		1,019
Renewables (e)
Wind
Brookfield Wind Park	Huron	2014	75	Huron		2014		75
Echo Wind Park	Huron	2014	112	Huron		2014		112
Gratiot Wind Park	Gratiot	2011 and 2012	102	Gratiot		2011 and 2012		102
Pinnebog Wind Park				Huron		2016		51
Thumb Wind Project	Huron and Sanilac	2012	110	Huron and Sanilac		2012		110
			399					450
Solar	Various	2010-2015	12
Utility-Owned SolarCurrents				Various		2010-2016		16
Utility Scale Solar				Various		2017		50
			11,907					66
								11,602


(a)	Represents summer net rating for all units with the exception of renewable facilities. The summer net rating is based on operating experience, the physical condition of units, environmental control limitations, and customer requirements for steam, which would otherwise be used for electric generation. Wind and solar facilities reflect name plate capacity.


(b)	The Belle River capability represents DTE Electric’s entitlement to 81% of the capacity and energy of the plant. See Note 67 to the Consolidated Financial Statements in Item 8 of this Report, "Jointly-Owned Utility ~~Plant".~~Plant."


(c)	The Monroe generating plant provided 40% of DTE Electric’s total ~~2015~~2017 power plant generation.


(d)	Represents DTE Electric’s 49% interest in Ludington with a total capability of ~~1,955~~2,080 MW. See Note 67 to the Consolidated Financial Statements in Item 8 of this Report, "Jointly-Owned Utility ~~Plant".~~Plant."


(e)	In addition to the owned renewable facilities described above, DTE Electric has long-term contracts for ~~487~~489 MW of renewable power generated from wind, solar, and biomass facilities.

~~DTE Electric expects to retire Trenton Channel Unit 7 (110 MW)~~See "Capital Investments" in ~~April 2016. Over the next fifteen years, DTE Electric expects to retire additional coal-fired generation~~Management's Discussion and to increase the proportion of its generation mix attributable to natural gas-fired generation and renewables. DTE Electric acquired two simple-cycle natural gas facilities in 2015. In January 2015, DTE Electric acquired a 732 MW simple-cycle natural gas facility in Carson City, Michigan (Montcalm County) that was placed in service in 2002 and 2003. In October 2015, DTE Electric acquired a 350 MW simple-cycle natural gas facility in East China Township, Michigan (St. Clair County) that was placed in service in 2002. These acquisitions are included in Natural gas and Oil-fueled Peaking Units in the table above. See Note 4 to the Consolidated Financial StatementsAnalysis in Item 87 of this Report ~~"Acquisitions~~for information regarding plant retirements and ~~Exit Activities".~~future capital expenditures.

DTE Electric owns and operates ~~676~~692 distribution substations with a capacity of approximately ~~33,729,000~~36,357,000 kilovolt-amperes (kVA) and approximately ~~432,500~~440,500 line transformers with a capacity of approximately ~~23,472,000~~31,777,000 kVA.

Circuit miles of electric distribution lines owned and in service as of December 31, ~~2015~~2017 are shown in the following table:


	Circuit Miles		Circuit Miles
Operating Voltage-Kilovolts (kV)	Overhead	Underground	Overhead	Underground
4.8 kV to 13.2 kV	27,686	14,731	28,479	15,122
24 kV	182	692	182	689
40 kV	2,290	383	2,301	378
120 kV	60	8	61	8
	30,218	15,814	31,023	16,197

There are numerous interconnections that allow the interchange of electricity between DTE Electric and electricity providers external to the DTE Electric service area. These interconnections are generally owned and operated by ITC Transmission, an unrelated company, and connect to neighboring energy companies.

Regulation

DTE Electric is subject to the regulatory jurisdiction of various agencies, including, but not limited to, the MPSC, the FERC, and the NRC. The MPSC issues orders pertaining to rates, recovery of certain costs, including the costs of generating facilities and regulatory assets, conditions of service, accounting, and operating-related matters. DTE Electric's MPSC-approved rates charged to customers have historically been designed to allow for the recovery of costs, plus an authorized rate of return on investments. The FERC regulates DTE Electric with respect to financing authorization and wholesale electric activities. The NRC has regulatory jurisdiction over all phases of the operation, construction, licensing, and decommissioning of DTE Electric's nuclear plant operations. DTE Electric is subject to the requirements of other regulatory agencies with respect to safety, the environment, and health.

See Notes 7, 8, ~~11,~~9, 12, and 1718 to the Consolidated Financial Statements in Item 8 of this Report, "Asset Retirement ~~Obligations",~~Obligations," "Regulatory ~~Matters",~~Matters," "Fair ~~Value",~~Value," and "Commitments and ~~Contingencies".~~Contingencies."

Energy Assistance Programs

Energy assistance programs, funded by the federal government and the State of Michigan, remain critical to DTE Electric’s ability to control its uncollectible accounts receivable and collections expenses. DTE Electric’s uncollectible accounts receivable expense is directly affected by the level of government-funded assistance that qualifying customers receive. DTE Electric works continuously with the State of Michigan and others to determine whether the share of funding allocated to customers is representative of the number of low-income individuals in the service territory. DTE Electric also partners with federal, state, and local officials to attempt to increase the share of low-income funding allocated to customers.

Strategy and Competition

DTE Electric's electrical generation operations seek to provide the energy needs of customers in a cost effective manner. With potential capacity constraints in the MISO region, there will be increased dependency on DTE Electric's generation to provide reliable service and price stability for customers. This generation will require a large investment ~~due to~~in DTE Electric's aging coal fleet, ~~along with increased environmental regulations.~~proposed natural gas fueled combined cycle generation facility, and renewables.

DTE Electric's distribution operations focus is on distributing energy in a safe, cost effective, and reliable manner to customers. DTE Electric seeks to increase operational efficiencies to increase customer satisfaction at an affordable rate.

The electric retail access program in Michigan gives electric customers the option of retail access to alternative electric suppliers, subject to limits. Customers with retail access to alternative electric suppliers represented approximately 10% of retail sales in ~~2015, 2014,~~2017, 2016, and ~~2013~~2015 and consisted primarily of industrial and commercial customers. MPSC rate orders and 2008 energy legislation enacted by the State of Michigan have placed a 10% cap on the total retail access related migration, mitigating some of the unfavorable effects of electric retail access on DTE Electric's financial performance and full service customer rates. Energy legislation passed in 2016 retained the 10% retail access cap with some revisions. DTE Electric expects that customers with retail access to alternative electric suppliers will represent approximately 10% of retail sales in ~~2016.~~2018.

Competition in the regulated electric distribution business is primarily from the on-site generation of industrial customers and from distributed generation applications by industrial and commercial customers. DTE Electric does not expect significant competition for distribution to any group of customers in the near term.

Revenues from year to year will vary due to weather conditions, economic factors, regulatory events, and other risk factors as discussed in the “Risk Factors” in Item 1A. of this Report.

GAS

Description

DTE Energy's Gas segment consists principally of DTE Gas, a natural gas utility engaged in the purchase, storage, transportation, distribution, and sale of natural gas to approximately ~~1.2~~1.3 million residential, commercial, and industrial customers throughout Michigan, and the sale of storage and transportation capacity.

Operating Revenues by Service


	2015		2014		2013		2017		2016		2015
	(In millions)						(In millions)
Gas sales	$	1,019	$	1,233	$	1,093	$	1,002	$	970	$	1,019
End-user transportation	191		218		212		206		189		191
Intermediate transportation	59		68		59		49		50		59
Storage and other	107		117		110
Other							131		115		107
Gas segment Operating Revenues	$	1,376	$	1,636	$	1,474	$	1,388	$	1,324	$	1,376

Gas sales — Includes the sale and delivery of natural gas primarily to residential and small-volume commercial and industrial customers.

End-user transportation — Gas delivery service provided primarily to large-volume commercial and industrial customers. Additionally, the service is provided to residential customers and small-volume commercial and industrial customers who have elected to participate in the gas retail access program. End-user transportation customers purchase natural gas directly from marketers, producers, or brokers and utilize DTE Gas' pipeline network to transport the gas to their facilities or homes.

Intermediate transportation — Gas delivery service is provided to producers, brokers, and other gas companies that own the natural gas, but are not the ultimate consumers. Intermediate transportation customers use DTE Gas' high-pressure transportation system to transport the natural gas to storage fields, pipeline interconnections, or other locations.

~~Storage and other~~Other — Includes revenues from natural gas storage, appliance maintenance, facility development, and other energy-related services.

DTE Gas' natural gas sales, end-user transportation, and intermediate transportation volumes, revenues, and Net Income, are impacted by weather. Given the seasonal nature of the business, revenues and Net Income are concentrated in the first and fourth quarters of the calendar year. By the end of the first quarter, the heating season is largely over, and DTE Gas typically realizes substantially reduced revenues and earnings in the second quarter, and losses in the third quarter. The impacts of changes in annual average customer usage are minimized by the RDM.

DTE Gas operations are not dependent upon a limited number of customers, and the loss of any one or a few customers would not have a material adverse effect on the results of DTE Gas.

Natural Gas Supply

DTE Gas' gas distribution system has a planned maximum daily send-out capacity of 2.4 Bcf, with approximately ~~66%~~65% of the volume coming from underground storage for ~~2015.~~2017. Peak-use requirements are met through utilization of storage facilities, pipeline transportation capacity, and purchased gas supplies. Because of the geographic diversity of supply and its pipeline transportation and storage capacity, DTE Gas is able to reliably meet supply requirements. DTE Gas believes natural gas supply and pipeline capacity will be sufficiently available to meet market demands in the foreseeable future.

DTE Gas purchases natural gas supplies in the open market by contracting with producers and marketers, and maintains a diversified portfolio of natural gas supply contracts. Supplier, producing region, quantity, and available transportation diversify DTE Gas' natural gas supply base. Natural gas supply is obtained from various sources in different geographic areas (Gulf Coast, Mid-Continent, Canada, and Michigan) under agreements that vary in both pricing and terms. Gas supply pricing is generally tied to the New York Mercantile Exchange and published price indices to approximate current market prices combined with MPSC-approved fixed price supplies with varying terms and volumes through ~~2018.~~2020.

DTE Gas is directly connected to interstate pipelines, providing access to most of the major natural gas supply producing regions in the Gulf Coast, Mid-Continent, and Canadian regions. The primary long-term transportation supply contracts at December 31, ~~2015~~2017 are ~~as follows:~~listed below. In addition, DTE Gas has contracted for 75 MDth/d of capacity on the NEXUS Pipeline, for a term of 15-years beginning with the anticipated third quarter 2018 in-service date.


	Availability (MMcf/d)	Contract Expiration	Availability (MDth/d)	Contract Expiration
Great Lakes Gas Transmission L.P.	30	2017	30	2022
Viking Gas Transmission Company	21	2017	21	2022
Vector Pipeline L.P.	50	2017	20	2022
Trunkline Gas Company	51	2017
ANR Pipeline Company	154	2028	204	2028
Panhandle Eastern Pipeline Company	95	2029	125	2029

Properties

DTE Gas owns distribution, storage, and transportation properties that are located in the State of Michigan. The distribution system includes approximately ~~19,000~~19,500 miles of distribution mains, approximately ~~1,165,000~~1,216,000 service pipelines, and approximately ~~1,314,000~~1,262,000 active meters, and DTE Gas owns approximately 2,000 miles of transmission pipelines that deliver natural gas to the distribution districts and interconnect DTE Gas storage fields with the sources of supply and the market areas.

DTE Gas owns storage properties relating to four underground natural gas storage fields with an aggregate working gas storage capacity of approximately ~~141~~139 Bcf. These facilities are important in providing reliable and cost-effective service to DTE Gas customers. In addition, DTE Gas sells storage services to third parties.

Most of DTE Gas' distribution and transportation property is located on property owned by others and used by DTE Gas through easements, permits, or licenses. Substantially all of DTE Gas' property is subject to the lien of a mortgage.

DTE Gas leases a portion of its pipeline system to the Vector Pipeline Partnership (an affiliate) through a capital lease arrangement. See Note 1617 to the Consolidated Financial Statements in Item 8 of the Report, "Capital and Operating ~~Leases".~~Leases."

Regulation

DTE Gas is subject to the regulatory jurisdiction of the MPSC, which issues orders pertaining to rates, recovery of certain costs, including the costs of regulatory assets, conditions of service, accounting, and operating-related matters. DTE Gas' MPSC-approved rates charged to customers have historically been designed to allow for the recovery of costs, plus an authorized rate of return on investments. DTE Gas operates natural gas storage and transportation facilities in Michigan as intrastate facilities regulated by the MPSC and provides intrastate storage and transportation services pursuant to ana MPSC-approved tariff.

DTE Gas also provides interstate storage and transportation services in accordance with an Operating Statement on file with the FERC. The FERC's jurisdiction is limited and extends to the rates, non-discriminatory requirements, and the terms and conditions applicable to storage and transportation provided by DTE Gas in interstate markets. FERC granted DTE Gas authority to provide storage and related services in interstate commerce at market-based rates. DTE Gas provides transportation services in interstate commerce at cost-based rates approved by the MPSC and filed with the FERC.

DTE Gas is subject to the requirements of other regulatory agencies with respect to safety, the environment, and health.

See Notes 89 and 1718 to the Consolidated Financial Statements in Item 8 of this Report, "Regulatory Matters" and "Commitments and ~~Contingencies".~~Contingencies."

Energy Assistance Program

Energy assistance programs, funded by the federal government and the State of Michigan, remain critical to DTE Gas' ability to control its uncollectible accounts receivable and collections expenses. DTE Gas' uncollectible accounts receivable expense is directly affected by the level of government-funded assistance its qualifying customers receive. DTE Gas works continuously with the State of Michigan and others to determine whether the share of funding allocated to customers is representative of the number of low-income individuals in the gas service territory. DTE Gas also partners with federal, state, and local officials to attempt to increase the share of low-income funding allocated to DTE Gas customers.

Strategy and Competition

DTE Gas' strategy is to ensure the safe, reliable, and cost effective delivery of natural gas service within its franchised markets in Michigan. In addition, DTE Gas is promoting the extension of its distribution system to ~~under served~~underserved markets and the increased use of natural gas furnaces, water heaters, and appliances within its current customer base. DTE Gas continues to focus on the reduction of operating costs and the delivery of energy efficiency products and services to its customers, making natural gas service the preferred fuel and even more affordable for its customers.

Competition in the gas business primarily involves other natural gas transportation providers, as well as providers of alternative fuels and energy sources. The primary focus of competition for end-user transportation is cost and reliability. Some large commercial and industrial customers have the ability to switch to alternative fuel sources such as coal, electricity, oil, and steam. If these customers were to choose an alternative fuel source, they would not have a need for DTE Gas' end-user transportation service. DTE Gas competes against alternative fuel sources by providing competitive pricing and reliable service, supported by its storage capacity.

Having an extensive transportation pipeline system has enabled marketing of DTE Gas' storage and transportation services to gas producers, marketers, distribution companies, end-user customers, and other pipeline companies. The business operates in a central geographic location with connections to major Midwestern interstate pipelines that extend throughout the Midwest, eastern United States, and eastern Canada.

DTE Gas' storage capacity is used to store natural gas for delivery to its customers, and is also sold to third parties under a variety of arrangements. Prices for storage arrangements for shorter periods are generally higher, but more volatile, than for longer periods. Prices are influenced primarily by market conditions, weather, and natural gas pricing.

GAS STORAGE AND PIPELINES

Description

Gas Storage and Pipelines ~~controls~~owns natural gas storage fields, ~~intrastate~~ lateral and ~~intrastate~~ gathering pipeline systems, compression and surface facilities, and has ownership interests in interstate pipelines serving the Midwest, Ontario, and Northeast markets. The pipeline and storage assets are primarily supported by long-term, fixed-price revenue contracts.

Properties

Gas Storage and Pipelines holds the following properties:



Property Classification	% Owned	Description	Location
Pipelines
Appalachia Gathering System^(a)	100%	114-mile pipeline delivering Marcellus Shale gas to Texas Eastern Pipeline and Stonewall Gas Gathering system	PA and WV
Stonewall Gas Gathering^(a)	55%	68-mile pipeline connecting Appalachia Gathering System to Columbia Pipeline	WV
Bluestone Pipeline	100%	~~53.3-miles of installed~~59-mile pipeline delivering Marcellus Shale gas to Millennium Pipeline and Tennessee Pipeline	PA and NY
~~Michigan gathering systems~~	~~100%~~	~~Gathers production gas in northern Michigan~~	MI
Susquehanna gathering system	100%	Gathering system delivering Southwestern Energy's Marcellus Shale gas production to Bluestone Pipeline	PA
Vector Pipeline	40%	348-mile pipeline connecting Chicago, Michigan, and Ontario market centers	IL, IN, MI, and Ontario
Millennium Pipeline	26%	~~182-mile~~251-mile pipeline serving markets in the Northeast	NY
Michigan gathering systems	100%	Gathers production gas in northern Michigan	MI
Storage
Washington 10	100%	75 Bcf of storage capacity	MI
Washington 28	50%	16 Bcf of storage capacity	MI


(a)	In October 2016, DTE Energy closed on an acquisition of midstream natural gas assets that are part of the Gas Storage and Pipelines segment. See Note 4 to the Consolidated Financial Statements, "Acquisitions and Exit Activities," for additional information.

The assets of these businesses are well integrated with other DTE Energy operations. Pursuant to an operating agreement, DTE Gas provides physical operations, maintenance, and technical support for the Washington 10 and 28 storage facilities and for the Michigan gathering systems.

In addition, DTE Energy owns a 50% interest in the NEXUS Pipeline, a ~~proposed~~ 255-mile pipeline to transport Utica and Marcellus shale gas to Ohio, Michigan, and Ontario market centers. A FERC application was filed in the fourth quarter of 2015 and was approved in August 2017. Construction has commenced with an ~~estimated~~anticipated third quarter 2018 in-service date.

In May 2017, DTE Energy filed a FERC application for approval of the Birdsboro Pipeline, a 14-mile lateral to serve a new power plant in ~~service date in the fourth quarter of 2017.~~Pennsylvania. DTE Energy is targeting a 2018 in-service date.

Regulation

Gas Storage and Pipelines operates natural gas storage facilities in Michigan as intrastate facilities regulated by the MPSC, and provides intrastate storage and related services pursuant to an MPSC-approved tariff. Gas Storage and Pipelines also provides interstate services in accordance with an Operating Statement on file with the FERC. Vector and Millennium Pipelines provide interstate transportation services in accordance with their FERC-approved tariffs. In addition, Vector is subject to applicable laws, rules and regulations in Canada. NEXUS Pipeline, when operational, will also provide interstate transportation services in accordance with their FERC-approved tariffs. ~~In Pennsylvania,~~ Gas Storage and Pipelines' gathering and pipeline assets are subject to the rules and regulations of the MPSC, Pennsylvania Public Utility ~~Commission. Bluestone Pipeline is regulated in~~Commission, the ~~state of New York by~~West Virginia Public Service Commission, and the New York Public Service Commission.

Strategy and Competition

Gas Storage and Pipelines expects to continue its steady growth plan by expanding existing assets, acquiring and/or developing new assets that are typically supported with long-term customer commitments. ~~Gas Storage and Pipelines has competition from other pipelines and storage providers.~~ The focus will be on opportunities in the Midwest to Northeast region to supply natural gas to meet growing ~~demand.~~demand and displace less attractive supply from certain regions in North America. Much of the growth in demand for natural gas is expected to occur in the ~~Eastern~~eastern Canada and the ~~Northeast~~northeast U.S. regions. Gas Storage and Pipelines believes that the Vector, Millennium, and ~~Millennium~~NEXUS Pipelines are well positioned to provide access routes and low-cost expansion options to these ~~markets. In addition, Gas Storage and Pipelines believes that Millennium Pipeline is well positioned for~~markets due to growth in production from the ~~Marcellus Shale, especially with respect to Marcellus production~~Marcellus/Utica Shales in ~~Northern Pennsylvania.~~Pennsylvania and West Virginia. Gas Storage and Pipelines has ~~an agreement~~agreements with ~~Southwestern Energy Production Company to~~key Marcellus shale producers that support its Bluestone Pipeline, ~~and~~ Susquehanna gathering, ~~system. DTE Energy expects to continue steady growth in the~~AGS, and SGG businesses. Gas Storage and Pipelines ~~business and~~ is evaluating new pipeline and storage investment opportunities that could include additional ~~Millennium~~pipeline and ~~Vector~~gathering expansions, ~~and~~ laterals, ~~Bluestone~~ compression, ~~and laterals, Susquehanna gathering expansions,~~ and other Marcellus/Utica shale midstream development or partnering ~~opportunities, such as the NEXUS Pipeline.~~ opportunities.

Gas Storage and ~~Pipelines' operations~~Pipelines has competition from other pipelines and storage providers. Operations are dependent upon a limited number of customers, and the loss of any one or a few customers could have a material adverse effect on the results of Gas Storage and Pipelines.

POWER AND INDUSTRIAL PROJECTS

Description

Power and Industrial Projects is comprised primarily of projects that deliver energy and utility-type products and services to industrial, commercial, and institutional customers, produce reduced emissions fuel, and sell electricity from renewable energy projects. This business segment provides services using project assets usually located on or near the customers' premises in the steel, automotive, pulp and paper, airport, chemical, and other industries as follows:

Industrial Energy Services

Steel and Petroleum Coke —Power and Industrial Projects produces metallurgical coke from ~~one~~a coke battery with a capacity of 1.0 million tons per year and has an investment in a second coke battery with a capacity of 1.2 million tons per year. Power and Industrial Projects also provides pulverized coal and petroleum coke to the steel, pulp and paper, and other industries.

13Renewable Energy

Wholesale Power and Renewables —Power and Industrial Projects holds ownership interests in, and operates, ~~four~~five renewable generating plants with a capacity of ~~191~~217 MWs. The electric output is sold under long-term power purchase agreements.

Landfill Gas Recovery — Power and Industrial Projects ~~also develops~~has ownership interests in, and operates, twenty-two landfill gas recovery ~~systems that capture~~sites in eight different states. The sites recover methane from landfills and converts the gas to generate electricity, replace fossil fuels in industrial and ~~provide local utilities, industries, and consumers with an opportunity~~manufacturing operations, or refine to ~~use a competitive, renewable source of energy, in addition to providing environmental benefits by reducing GHG emissions.~~pipeline-quality gas, which can then be used as vehicle fuel.

Reduced Emissions Fuel

Reduced Emissions Fuel — Power and Industrial Projects has constructed and placed in service REF facilities at ~~nine~~eleven sites including facilities located at ~~six~~eight third-party owned coal-fired power plants. DTE Energy has sold membership interests in four of the facilities and entered into lease arrangements ~~at two~~in three of the facilities. DTE Energy will continue to optimize these facilities by seeking investors or entering into lease arrangements for facilities operating at DTE Electric and other utility sites. ~~DTE Energy is in the process of relocating an underutilized facility at an existing site to a new third-party owned coal-fired power plant.~~ In addition, DTE Energy has entered into an agreement to operate an REF facility owned by an outside party located at a third-party owned coal-fired power plant. The facilities blend a proprietary additive with coal used in coal-fired power plants, resulting in reduced emissions of nitrogen oxide and mercury. Qualifying facilities are eligible to generate tax credits for ten years upon achieving certain criteria. The value of a tax credit is adjusted annually by an inflation factor published by the IRS. The value of the tax credit is reduced if the reference price of coal exceeds certain thresholds. The economic benefit of the REF facilities is dependent upon the generation of production tax credits.

Properties and Other

The following are significant properties operated by Power and Industrial Projects:



~~Facility~~Business Areas	Location	Service Type
Industrial Energy Services
Steel and Petroleum Coke
Pulverized Coal Operations	MI	Pulverized Coal
Coke Production	MI	Metallurgical Coke Supply
Other Investment in Coke Production and Petroleum Coke	IN and MS	Metallurgical Coke Supply and Pulverized Petroleum Coke
On-Site Energy
Automotive	~~Various sites in~~IN, MI, ~~IN,~~NY, and OH ~~and NY~~	Electric Distribution, Chilled Water, Waste Water, Steam, Cooling Tower Water, Reverse Osmosis Water, Compressed Air, Mist, and Dust Collectors
Airports	MI and PA	Electricity and Hot and Chilled Water
Chemical Manufacturing	~~IL,~~ KY and OH	Electricity, Steam, Natural Gas, Compressed Air, and Wastewater
Consumer Manufacturing	OH	Electricity, Steam, Wastewater, and Sewer
Business Park	PA	Electricity
Hospital and University	CA and IL	Electricity, Steam, and Chilled Water
~~Wholesale Power and Renewables~~Renewable Energy
Pulp and Paper	AL	Electric Generation and Steam
Renewables	CA and MN	Electric Generation
Landfill Gas Recovery	~~Various U.S. sites~~AZ, CA, MI, NC, NY, OH, TX, and UT	Electric Generation and ~~Landfill~~Renewable Natural Gas
~~REF~~Reduced Emissions Fuel	MI, OH, OK, IL, PA, TX, and WI	REF Supply


	2015		2014		2013		2017		2016		2015
	(In millions)						(In millions)
Production Tax Credits Generated (Allocated to DTE Energy)
REF	$	77	$	84	$	44	$	144	$	103	$	77
Power Generation	11		11		8
Renewables							6		8		11
Landfill Gas Recovery	3		2		1		3		3		3
	$	91	$	97	$	53	$	153	$	114	$	91

Regulation

Strategy and Competition

Power and Industrial Projects will continue leveraging its energy-related operating experience and project management capability to develop and grow its steel, on-site energy, and renewable ~~power,~~energy businesses, and optimize the REF businesses. Power and Industrial Projects will also continue to pursue opportunities to provide asset management and operations services to third parties. There are limited competitors for Power and Industrial Projects' existing disparate businesses who provide similar products and services. Power and Industrial Projects' operations are dependent upon a limited number of customers, and the loss of any one or a few customers could have a material adverse effect on the results of Power and Industrial Projects.

Power and Industrial Projects anticipates building around its core strengths in the markets where it operates. In determining the markets in which to compete, Power and Industrial Projects examines closely the regulatory and competitive environment, new and pending legislation, the number of competitors, and its ability to achieve sustainable margins. Power and Industrial Projects plans to maximize the effectiveness of its related businesses as it expands. ~~As Power and Industrial Projects pursues growth opportunities, the first priority will be to achieve value-added returns.~~

Power and Industrial Projects intends to focus on the following areas for growth:

~~Obtaining investors in the REF projects;~~

~~Relocating underutilized REF facilities~~Providing operating services to ~~alternative coal-fired~~owners of on-site industrial power ~~plants which may provide increased production and emission reduction opportunities in 2016 and future years;~~plants;

Acquiring and developing landfill gas recovery facilities, renewable energy projects, and other energy projects which may qualify for tax credits; ~~and~~

~~Providing operating services to owners of on-site industrial and power plants.~~Obtaining investors in the REF projects.

ENERGY TRADING

Description

Energy Trading focuses on physical and financial power and 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's customer base is predominantly utilities, local distribution companies, pipelines, producers and generators, and other marketing and trading companies. Energy Trading enters into derivative financial instruments as part of ~~their~~its marketing and hedging activities. These financial instruments are generally accounted for under the MTM method, which results in the recognition in earnings of unrealized gains and losses from changes in the fair value of the derivatives. Energy Trading utilizes forwards, futures, swaps, and option contracts to mitigate risk associated with marketing and trading activity, as well as for proprietary trading within defined risk guidelines. Energy Trading also provides commodity risk management services to the other businesses within DTE Energy.

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, contracts for pipeline transportation, renewable energy credits, and storage assets are not derivatives. As a result, this segment will experience earnings volatility as derivatives are marked-to-market without revaluing the underlying non-derivative contracts and assets. The business’ 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.

Regulation

Energy Trading has market-based rate authority from the FERC to sell power and blanket authority from the FERC to sell natural gas at market prices. Energy Trading is subject to FERC reporting requirements and market behavior rules. Energy Trading is also subject to the applicable laws, rules, and regulations related to the CFTC, U.S. Department of Homeland Security, and DOE. In addition, Energy Trading is subject to applicable laws, rules, and regulations in Canada.

Strategy and Competition

DTE Energy's strategy for the Energy Trading business is to deliver value-added services to DTE Energy customers. DTE Energy seeks to manage this business in a manner complementary to the growth of DTE Energy's other business segments. Energy Trading focuses on physical marketing and the optimization of its portfolio of energy assets. The segment competes with electric and gas marketers, financial institutions, traders, utilities, and other energy providers. The Energy Trading business is dependent upon the availability of capital and an investment grade credit rating. DTE Energy believes it has ample available capital capacity to support Energy Trading activities. DTE Energy monitors its use of capital closely to ensure that its commitments do not exceed capacity. A material credit restriction would negatively impact Energy Trading's financial performance. Competitors with greater access to capital, or at a lower cost, may have a competitive advantage. DTE Energy has risk management and credit processes to monitor and mitigate risk.

CORPORATE AND OTHER

Description

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

ENVIRONMENTAL MATTERS

The Registrants are subject to extensive environmental regulation and expect to continue recovering environmental costs related to utility operations through rates charged to customers. The following table summarizes DTE Energy's, including DTE Electric's, estimated significant future environmental expenditures based upon current regulations. Pending or future reconsiderations of current regulations may impact the estimated expenditures summarized in the table below. The amounts reported in the table do not include any expenditures related to the EPA Clean Power Plan as discussed below. Actual costs to comply could vary substantially. Additional costs may result as the effects of various substances on the environment are studied and governmental regulations are developed and implemented.



	DTE Electric		DTE Gas		Non-utility		Total
	(In millions)
Water	$	35	$	—	$	—	$	35
Contaminated and other sites	5		35		—		40
Coal combustion residuals and effluent limitations guidelines	295		—		—		295
Estimated total future expenditures through 2024	$	335	$	35	$	—	$	370
Estimated 2018 expenditures	$	10	$	30	$	—	$	40
Estimated 2019 expenditures	$	65	$	—	$	—	$	65

Water — The EPA finalized regulations on cooling water intake in August 2014. DTE Electric is conducting studies to determine the best technology for reducing the environmental impacts of the cooling water intake structures at each of its facilities. DTE Electric may be required to install technologies to reduce the impacts of the cooling water intakes.

The Registrants are also in the process of cleaning up other sites where contamination is present as a result of historical and ongoing utility operations. These other sites include an engineered ash storage facility, electric distribution substations, gas pipelines, electric generating power plants, and underground and aboveground storage tank locations. Cleanup activities associated with these sites will be conducted over the next several years. Any significant change in assumptions, such as remediation techniques, nature and extent of contamination, and regulatory requirements, could impact the estimate of remedial action costs for these sites and affect the Registrants' financial position and cash flows and the rates charged to their customers.

Coal Combustion Residuals and Effluent Limitations Guidelines — In April 2015, the EPA published a final rule for the disposal of coal combustion residuals, commonly known as coal ash. The rule became effective in October 2015. The rule is based on the continued listing of coal ash as a non-hazardous waste and relies on various self-implementation design and performance standards. DTE Electric owns and operates 3 permitted engineered coal ash storage facilities to dispose of coal ash from coal-fired power plants and operates a number of smaller impoundments at its power plants. At certain facilities, the rule requires the installation of monitoring wells, compliance with groundwater standards, and the closure of basins at the end of the useful life of the associated power plant. At other facilities, the rule requires ash laden waters be moved from earthen basins to steel and concrete tanks.

In November 2015, the EPA finalized effluent limitations guidelines for the steam electric power generating industry which may require additional controls to be installed between 2018 and 2023. The initial costs to comply with this rule are under development and estimates are included in the Coal Combustion Residual and Effluent Limitations Guidelines amount in the above table.

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.

Air — DTE Electric is subject to the EPA ozone and fine particulate transport, and acid rain regulations that limit power plant emissions of sulfur dioxide and nitrogen oxides. The EPA and the State of Michigan have also issued emission reduction regulations relating to ozone, fine particulate, regional haze, mercury, and other air pollution. These rules have led to emission controls on fossil-fueled power plants to reduce nitrogen oxides, sulfur dioxide, mercury, and other emissions. These rulemakings could require additional controls for sulfur dioxide, nitrogen oxides, and other hazardous air pollutants over the next few years. DTE Electric does not anticipate additional capital expenditures to comply with air pollution requirements through 2024, pending the results of future rulemakings.

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.

See Management’s Discussion and Analysis in Item 7 of this Report and Notes 8, 9, and 18 to the Consolidated Financial Statements in Item 8 of this Report, "Asset Retirement Obligations," "Regulatory Matters," and "Commitments and Contingencies."

EMPLOYEES

DTE Energy and its subsidiaries had approximately 10,200 employees as of December 31, 2017, of which approximately 5,000 were represented by unions. DTE Electric had approximately 4,700 employees as of December 31, 2017, of which approximately 2,700 were represented by unions. There are several bargaining units for DTE Energy subsidiaries' represented employees. The majority of represented employees for both DTE Energy and DTE Electric are under contracts that expire in 2020 and 2021.

Item 1A. Risk Factors

There are various risks associated with the operations of the Registrants' utility businesses and DTE Energy's non-utility businesses. To provide a framework to understand the operating environment of the Registrants, below is a brief explanation of the more significant risks associated with their businesses. Although the Registrants have tried to identify and discuss key risk factors, others could emerge in the future. Each of the following risks could affect performance.

The Registrants are subject to rate regulation. Electric and gas rates for the utilities are set by the MPSC and the FERC and cannot be changed without regulatory authorization. The Registrants may be negatively impacted by new regulations or interpretations by the MPSC, the FERC, or other regulatory bodies. The Registrants' ability to recover costs may be impacted by the time lag between the incurrence of costs and the recovery of the costs in customers' rates. Regulators also may decide to disallow recovery of certain costs in customers' rates if they determine that those costs do not meet the standards for recovery under current governing laws and regulations. Regulators may also disagree with the Registrants' rate calculations under the various mechanisms that are intended to mitigate the risk to their utilities related to certain aspects of the business. If the Registrants cannot agree with regulators on an appropriate reconciliation of those mechanisms, it may impact the Registrants' ability to recover certain costs through customer rates. Regulators may also decide to eliminate these mechanisms in future rate cases, which may make it more difficult for the Registrants to recover their costs in the rates charged to customers. The Registrants cannot predict what rates the MPSC will authorize in future rate cases. New legislation, regulations, or interpretations could change how the business operates, impact the Registrants' ability to recover costs through rates or the timing of such recovery, or require the Registrants to incur additional expenses.

Changes to Michigan's electric retail access program could negatively impact the Registrants' financial performance. The State of Michigan currently experiences a hybrid market, where the MPSC continues to regulate electric rates for DTE Electric customers, while alternative electric suppliers charge market-based rates. MPSC rate orders, and energy legislation enacted by the State of Michigan, have placed a 10% cap on the total potential retail access migration. However, even with the legislated 10% cap on participation, there continues to be legislative and financial risk associated with the electric retail access program. Electric retail access migration is sensitive to market price and full service electric price changes. The Registrants are required under current regulation to provide full service to retail access customers that choose to return, potentially resulting in the need for additional generating capacity.

Environmental laws and liability may be costly. The Registrants are subject to, and affected by, numerous environmental regulations. These regulations govern air emissions, water quality, wastewater discharge, and disposal of solid and hazardous waste. Compliance with these regulations can significantly increase capital spending, operating expenses, and plant down times, and can negatively affect the affordability of the rates charged to customers.

Uncertainty around future environmental regulations creates difficulty planning long-term capital projects in the Registrants' generation fleet and, for DTE Energy's gas distribution businesses. These laws and regulations require the Registrants to seek a variety of environmental licenses, permits, inspections, and other regulatory approvals. The Registrants could be required to install expensive pollution control measures or limit or cease activities, including the retirement of certain generating plants, based on these regulations. Additionally, the Registrants may become a responsible party for environmental cleanup at sites identified by a regulatory body. The Registrants cannot predict with certainty the amount and timing of future expenditures related to environmental matters because of the difficulty of estimating cleanup costs. There is also uncertainty in quantifying liabilities under environmental laws that impose joint and several liability on potentially responsible parties.

The Registrants may also incur liabilities as a result of potential future requirements to address climate change issues. Proposals for voluntary initiatives and mandatory controls are being discussed both in the United States and worldwide to reduce GHGs such as carbon dioxide, a by-product of burning fossil fuels. If increased regulations of GHG emissions are implemented, the operations of DTE Electric's fossil-fueled generation assets may be significantly impacted. Since there can be no assurances that environmental costs may be recovered through the regulatory process, the Registrants' financial performance may be negatively impacted as a result of environmental matters.

For DTE Energy, future environmental regulation of natural gas extraction techniques, including hydraulic fracturing, being discussed both at the United States federal level and by some states may affect the profitability of natural gas extraction businesses which could affect demand for, and profitability of, DTE Energy's gas transportation businesses.

DTE Energy's non-utility businesses may not perform to its expectations. DTE Energy relies on non-utility operations for an increasing portion of earnings. If DTE Energy's current and contemplated non-utility investments do not perform at expected levels, DTE Energy could experience diminished earnings and a corresponding decline in shareholder value.

DTE Energy relies on cash flows from subsidiaries. DTE Energy is a holding company. Cash flows from the utility and non-utility subsidiaries are required to pay interest expenses and dividends on DTE Energy debt and securities. Should a major subsidiary not be able to pay dividends or transfer cash flows to DTE Energy, its ability to pay interest and dividends would be restricted.

Threats of cyber crime, physical security, and terrorism could affect the Registrants' business. The Registrants may be threatened by issues such as cyber crime, physical security, or terrorism that may disrupt the Registrants' operations, and could harm the Registrants' operating results.

Cyber crime, which includes the use of malware, computer viruses, and other means for disruption or unauthorized access against companies, including the Registrants, has increased in frequency, scope, and potential impact in recent years. The Registrants' industry requires the continued operation of sophisticated information technology systems and network infrastructure. Despite implementation of security measures, all of the Registrants' technology systems are vulnerable to disability or failures due to cyber crime, physical security threats, acts of war or terrorism, and other causes. If the Registrants' information technology systems were to fail and they were unable to recover in a timely way, the Registrants may be unable to fulfill critical business functions, which could have a material adverse effect on the Registrants' business, operating results, and financial condition.

In addition, the Registrants' generation plants and electrical distribution facilities, and DTE Energy's gas pipeline and storage facilities, in particular, may be targets of physical security threats or terrorist activities that could disrupt the Registrants' ability to produce or distribute some portion of their products. The Registrants have increased security as a result of past events and may be required by regulators or by the future threat environment to make investments in security that the Registrants cannot currently predict.

Failure to maintain the security of personally identifiable information could adversely affect the Registrants. In connection with the Registrants' businesses, they collect and retain personally identifiable information of their customers, shareholders, and employees. Customers, shareholders, and employees expect that the Registrants will adequately protect their personal information. The regulatory environment surrounding information security and privacy is increasingly demanding. A significant theft, loss, or fraudulent use of customer, shareholder, employee, or Registrant data by cybercrime or otherwise, could adversely impact the Registrants' reputation, and could result in significant costs, fines, and litigation.

Operation of a nuclear facility subjects the Registrants to risk. Ownership of an operating nuclear generating plant subjects the Registrants to significant additional risks. These risks include, among others, plant security, environmental regulation and remediation, changes in federal nuclear regulation, increased capital expenditures to meet industry requirements, and operational factors that can significantly impact the performance and cost of operating a nuclear facility compared to other generation options. While the Registrants maintain insurance for various nuclear-related risks, there can be no assurances that such insurance will be sufficient to cover the Registrants' costs in the event of an accident or business interruption at the nuclear generating plant, which may affect the Registrants' financial performance. In addition, while the Registrants have a nuclear decommissioning trust fund to finance the decommissioning of the nuclear generating plant, there can be no assurances that such fund will be sufficient to fund the cost of decommissioning. A decline in market value of assets held in decommissioning trust funds due to poor investment performance or other factors may increase the funding requirements for these obligations. Any increase in funding requirements may have a material impact on the Registrants’ liquidity, financial position, or results of operations.

Construction and capital improvements to the Registrants' power facilities, DTE Energy's distribution systems and its Gas Storage and Pipelines business subject them to risk. The Registrants are managing ongoing, and planning future, significant construction and capital improvement projects at DTE Electric's multiple power generation and distribution facilities, at DTE Energy's gas distribution system, and at DTE Energy's Gas Storage and Pipelines business. Many factors that could cause delays or increased prices for these complex projects are beyond the Registrants' control, including the cost of materials and labor, subcontractor performance, timing and issuance of necessary permits or approvals (including required certificates from regulatory agencies), construction disputes, impediments to acquiring rights-of-way or land rights on a timely basis and on acceptable terms, cost overruns, and weather conditions. Failure to complete these projects on schedule and on budget for any reason could adversely affect the Registrants' financial performance, operations, or expected investment returns at the affected facilities, businesses and development projects.

The supply and/or price of energy commodities and/or related services may impact the Registrants' financial results. The Registrants are dependent on coal for much of their electrical generating capacity. DTE Energy's access to natural gas supplies is critical to ensure reliability of service for utility gas customers. DTE Energy's non-utility businesses are also dependent upon supplies and prices of energy commodities and services. Price fluctuations, fuel supply disruptions, and changes in transportation costs, could have a negative impact on the amounts DTE Electric charges utility customers for electricity and DTE Gas charges utility customers for gas and on the profitability of DTE Energy's non-utility businesses. The Registrants have hedging strategies and regulatory recovery mechanisms in place to mitigate some of the negative fluctuations in commodity supply prices in their utility and, for DTE Energy, non-utility businesses, but there can be no assurances that the Registrants' financial performance will not be negatively impacted by price fluctuations. The price of energy also impacts the market for DTE Energy's non-utility businesses that compete with utilities and alternative electric suppliers.

The supply and/or price of other industrial raw and finished inputs and/or related services may impact the Registrants' financial results. The Registrants are dependent on supplies of certain commodities, such as copper and limestone, among others, and industrial materials, and services in order to maintain day-to-day operations and maintenance of their facilities. Price fluctuations, or supply interruptions for these commodities and other items, could have a negative impact on the amounts charged to customers for the Registrants' utility products and, for DTE Energy, on the profitability of the non-utility businesses.

Emerging technologies may have a material adverse effect on the Registrants. Advances in technology that produce power or reduce power consumption include cost-effective renewable energy technologies, distributed generation, energy efficiency technologies, and energy storage devices. Such developments may impact the price of energy, may affect energy deliveries as customer-owned generation becomes more cost-effective, may require further improvements to our distribution systems to address changing load demands, and could make portions of our electric system power supply and/or distribution facilities obsolete prior to the end of their useful lives. Such technologies could also result in further declines in commodity prices or demand for delivered energy. Each of these factors could materially affect the Registrants’ results of operations, cash flows, or financial position.

Adverse changes in the Registrants' credit ratings may negatively affect them. Regional and national economic conditions, increased scrutiny of the energy industry and regulatory changes, as well as changes in the Registrants' economic performance, could result in credit agencies reexamining their credit ratings. While credit ratings reflect the opinions of the credit agencies issuing such ratings and may not necessarily reflect actual performance, a downgrade in the Registrants' credit ratings below investment grade could restrict or discontinue their ability to access capital markets and could result in an increase in their borrowing costs, a reduced level of capital expenditures, and could impact future earnings and cash flows. In addition, a reduction in the Registrants' credit ratings may require them to post collateral related to various physical or financially settled contracts for the purchase of energy-related commodities, products, and services, which could impact their liquidity.

Poor investment performance of pension and other postretirement benefit plan assets and other factors impacting benefit plan costs could unfavorably impact the Registrants' liquidity and results of operations. The Registrants' costs of providing non-contributory defined benefit pension plans and other postretirement benefit plans are dependent upon a number of factors, such as the rates of return on plan assets, the level of interest rates used to measure the required minimum funding levels of the plans, future government regulation, and the Registrants' required or voluntary contributions made to the plans. The performance of the debt and equity markets affects the value of assets that are held in trust to satisfy future obligations under the Registrants' plans. The Registrants have significant benefit obligations and hold significant assets in trust to satisfy these obligations. These assets are subject to market fluctuations and will yield uncertain returns, which may fall below the Registrants' projected return rates. A decline in the market value of the pension and other postretirement benefit plan assets will increase the funding requirements under the pension and other postretirement benefit plans if the actual asset returns do not recover these declines in the foreseeable future. Additionally, the pension and other postretirement benefit plan liabilities are sensitive to changes in interest rates. As interest rates decrease, the liabilities increase, resulting in increasing benefit expense and funding requirements. Also, if future increases in pension and other postretirement benefit costs as a result of reduced plan assets are not recoverable from the Registrants' utility customers, the results of operations and financial position of the Registrants could be negatively affected. Without sustained growth in the plan investments over time to increase the value of plan assets, the Registrants could be required to fund these plans with significant amounts of cash. Such cash funding obligations could have a material impact on the Registrants' cash flows, financial position, or results of operations.

The Registrants' ability to access capital markets is important. The Registrants' ability to access capital markets is important to operate their businesses and to fund capital investments. Turmoil in credit markets may constrain the Registrants' ability, as well as the ability of their subsidiaries, to issue new debt, including commercial paper, and refinance existing debt at reasonable interest rates. In addition, the level of borrowing by other energy companies, and the market as a whole, could limit the Registrants' access to capital markets. The Registrants' long-term revolving credit facilities do not expire until 2022, but the Registrants regularly access capital markets to refinance existing debt or fund new projects at the Registrants' utilities and DTE Energy's non-utility businesses, and the Registrants cannot predict the pricing or demand for those future transactions.

DTE Energy's participation in energy trading markets subjects it to risk. Events in the energy trading industry have increased the level of scrutiny on the energy trading business and the energy industry as a whole. In certain situations, DTE Energy may be required to post collateral to support trading operations, which could be substantial. If access to liquidity to support trading activities is curtailed, DTE Energy could experience decreased earnings potential and cash flows. Energy trading activities take place in volatile markets and expose DTE Energy to risks related to commodity price movements, deviations in weather, and other related risks. DTE Energy's trading business routinely has speculative trading positions in the market, within strict policy guidelines DTE Energy sets, resulting from the management of DTE Energy's business portfolio. To the extent speculative trading positions exist, fluctuating commodity prices can improve or diminish DTE Energy's financial results and financial position. DTE Energy manages its exposure by establishing and enforcing strict risk limits and risk management procedures. During periods of extreme volatility, these risk limits and risk management procedures may not work as planned and cannot eliminate all risks associated with these activities.

DTE Energy's ability to utilize production tax credits may be limited. To reduce U.S. dependence on imported oil, the Internal Revenue Code provides production tax credits as an incentive for taxpayers to produce fuels and electricity from alternative sources. DTE Energy generated production tax credits from coke production, landfill gas recovery, reduced emission fuel, renewable energy generation, and gas production operations. If DTE Energy's production tax credits were disallowed in whole or in part as a result of an IRS audit or changes in tax law there could be additional tax liabilities owed for previously recognized tax credits that could significantly impact DTE Energy's earnings and cash flows.

Weather significantly affects operations. At both utilities, deviations from normal hot and cold weather conditions affect the Registrants' earnings and cash flows. Mild temperatures can result in decreased utilization of the Registrants' assets, lowering income and cash flows. At DTE Electric, ice storms, tornadoes, or high winds can damage the electric distribution system infrastructure and power generation facilities and require it to perform emergency repairs and incur material unplanned expenses. The expenses of storm restoration efforts may not be fully recoverable through the regulatory process. DTE Gas can experience higher than anticipated expenses from emergency repairs on its gas distribution infrastructure required as a result of weather related issues.

Unplanned power plant outages may be costly. Unforeseen maintenance may be required to safely produce electricity or comply with environmental regulations. As a result of unforeseen maintenance, the Registrants may be required to make spot market purchases of electricity that exceed the costs of generation. The Registrants' financial performance may be negatively affected if unable to recover such increased costs.

Renewable portfolio standards and energy efficiency programs may affect the Registrants' business. The Registrants are subject to existing Michigan, and potential future, federal legislation and regulation requiring them to secure sources of renewable energy. The Registrants have complied with the existing federal and state legislation, but do not know what requirements may be added by federal or state legislation in the future. In addition, the Registrants expect to comply with new Michigan legislation increasing the percentage of power required to be provided by renewable energy sources. The Registrants cannot predict the financial impact or costs associated with complying with potential future legislation and regulations. Compliance with these requirements can significantly increase capital expenditures and operating expenses and can negatively affect the affordability of the rates charged to customers.

The Registrants are also required by Michigan legislation to implement energy efficiency measures and provide energy efficiency customer awareness and education programs. These requirements necessitate expenditures, and implementation of these programs creates the risk of reducing the Registrants' revenues as customers decrease their energy usage. The Registrants cannot predict how these programs will impact their business and future operating results.

Regional, national, and international economic conditions can have an unfavorable impact on the Registrants. The Registrants' utility and DTE Energy's non-utility businesses follow the economic cycles of the customers they serve and credit risk of counterparties they do business with. Should the financial conditions of some of DTE Energy's significant customers deteriorate as a result of regional, national or international economic conditions, reduced volumes of electricity and gas, and demand for energy services DTE Energy supplies, collections of accounts receivable, reductions in federal and state energy assistance funding, and potentially higher levels of lost gas or stolen gas and electricity could result in decreased earnings and cash flows.

Failure to attract and retain key executive officers and other skilled professional and technical employees could have an adverse effect on the Registrants’ operations. The Registrants' businesses are dependent on their ability to attract and retain skilled employees. Competition for skilled employees in some areas is high, and the inability to attract and retain these employees could adversely affect the Registrants' business and future operating results. In addition, the Registrants have an aging utility workforce, and the failure of a successful transfer of knowledge and expertise could negatively impact their operations.

A work interruption may adversely affect the Registrants. There are several bargaining units for DTE Energy's approximately 5,000 and DTE Electric's approximately 2,700 represented employees. The majority of represented employees are under contracts that expire in 2020 and 2021. A union choosing to strike would have an impact on the Registrants' businesses. The Registrants are unable to predict the effect a work stoppage would have on their costs of operations and financial performance.

If DTE Energy's goodwill becomes impaired, it may be required to record a charge to earnings. DTE Energy annually reviews the carrying value of goodwill associated with acquisitions it has made for impairment. Factors that may be considered for purposes of this analysis include any change in circumstances indicating that the carrying value of DTE Energy goodwill may not be recoverable, such as a decline in stock price and market capitalization, future cash flows, and slower growth rates in the industry. DTE Energy cannot predict the timing, strength, or duration of any economic slowdown or subsequent recovery, worldwide or in the economy or markets in which it operates; however, when events or changes in circumstances indicate that the carrying value of these assets may not be recoverable, DTE Energy may take a non-cash impairment charge, which could potentially materially impact DTE Energy's results of operations and financial position.

The Registrants' businesses have safety risks. The Registrants' electric distribution system, power plants, renewable energy equipment, and other facilities, and DTE Energy's gas distribution system, gas infrastructure, and other facilities, could be involved in incidents that result in injury, death, or property loss to employees, customers, or the public. Although the Registrants have insurance coverage for many potential incidents, depending upon the nature and severity of any incident, they could experience financial loss, damage to their reputation, and negative consequences from regulatory agencies or other public authorities.

The Registrants may not be fully covered by insurance. The Registrants have a comprehensive insurance program in place to provide coverage for various types of risks, including catastrophic damage as a result of severe weather or other natural disasters, war, terrorism, or a combination of other significant unforeseen events that could impact the Registrants' operations. Economic losses might not be covered in full by insurance, or the Registrants' insurers may be unable to meet contractual obligations.

Item 1B. Unresolved Staff Comments

None.

Item 3. Legal Proceedings

The Yolo-Solano Air Quality Management District issued nine notices of violation alleging that Woodland Biomass Power, LLC, which operates a renewable wood-fired power generation facility, failed a 2016 source test that was to demonstrate compliance with the facility’s PM-10 lb/hr daily emission permit limit, violated NO_x annual emission permit limits in 2013 and 2015 and related record keeping and reporting violations, failed a 2017 source test that was to demonstrate compliance with the facility’s NO_x lb/hr emission permit limit, and a fugitive dust violation that occurred in 2017. On January 5, 2018, Woodland Biomass Power, LLC paid a final settlement of $525,000 to resolve all the notice of violation issues.

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

For more information on legal proceedings and matters related to the Registrants, see Notes 9 and 18 to the Consolidated Financial Statements in Item 8 of this Report, "Regulatory Matters" and "Commitments and Contingencies," respectively.

Item 4. Mine Safety Disclosures

Not applicable.

Part II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters, and Issuer Purchases of Equity Securities

DTE Energy common stock is listed on the New York Stock Exchange, which is the principal market for such stock. The following table indicates the reported high and low sales prices of DTE Energy common stock on the Composite Tape of the New York Stock Exchange and dividends declared per share for each quarterly period during the past two years:



						Dividends Declared per Share
Year	Quarter	High		Low		Dividends Declared per Share
2017
	First	$	102.96	$	96.56	$	0.8250
	Second	$	111.35	$	100.97	$	0.8250
	Third	$	113.71	$	104.19	$	0.8250
	Fourth	$	116.74	$	106.21	$	0.8825
2016
	First	$	91.00	$	78.01	$	0.7300
	Second	$	99.13	$	84.77	$	0.7300
	Third	$	100.45	$	90.61	$	0.7700
	Fourth	$	99.92	$	89.66	$	0.8250

At December 31, 2017, there were 179,386,967 shares of DTE Energy common stock outstanding. These shares were held by a total of 53,437 shareholders of record.

DTE Energy paid cash dividends on common stock of $592 million in 2017, $531 million in 2016, and $501 million in 2015. The amount of future dividends will depend on DTE Energy's earnings, cash flows, financial condition, and other factors that are periodically reviewed by the DTE Energy Board of Directors. Although there can be no assurances, DTE Energy anticipates paying dividends for the foreseeable future.

All of the 138,632,234 issued and outstanding shares of DTE Electric common stock, par value $10 per share, are owned by DTE Energy, and constitute 100% of the voting securities of DTE Electric. Therefore, no market exists for DTE Electric's common stock.

DTE Electric paid cash dividends on common stock of $432 million in 2017, $420 million in 2016, and $395 million in 2015.

For information on DTE Energy dividend restrictions, see Note 16 to the Consolidated Financial Statements in Item 8 of this Report, "Short-Term Credit Arrangements and Borrowings."

All of DTE Energy's equity compensation plans that provide for the annual awarding of stock-based compensation have been approved by shareholders. For additional detail, see Note 21 to the Consolidated Financial Statements in Item 8 of this Report, "Stock-Based Compensation."

See the following table for information as of December 31, 2017:



	Number of Securities to be Issued Upon Exercise of Outstanding Options	Weighted-Average Exercise Price of Outstanding Options		Number of Securities Remaining Available for Future Issuance Under Equity Compensation Plans
Plans approved by shareholders	105,994	$	42.95	1,437,769

UNREGISTERED SALES OF DTE ENERGY 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's purchases of equity securities that are registered by DTE Energy pursuant to Section 12 of the Exchange Act of 1934 for the quarter ended December 31, 2017:



	Number of Shares Purchased^(a)	Average Price Paid per Share^(a)		Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Average Price Paid per Share	Maximum Dollar Value that May Yet Be Purchased Under the Plans or Programs
10/01/2017 — 10/31/2017	3,269	$	99.19	—	—	—
11/01/2017 — 11/30/2017	—	$	—	—	—	—
12/01/2017 — 12/31/2017	1,300	$	89.46	—	—	—
Total	4,569			—


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

COMPARISON OF CUMULATIVE FIVE YEAR TOTAL RETURN

Total Return to DTE Energy Shareholders

(Includes reinvestment of dividends)



	Annual Return Percentage Year Ended December 31,
Company/Index	2013	2014	2015		2016	2017
DTE Energy Company	14.89	34.61	(3.77	)	26.93	14.59
S&P 500 Index	32.39	13.69	1.38		11.95	21.82
S&P 500 Multi-Utilities Index	17.88	28.94	(1.73	)	18.56	12.09



	Indexed Returns Year Ended December 31,
	Base Period
Company/Index	2012	2013	2014	2015	2016	2017
DTE Energy Company	100	114.89	154.65	148.82	188.89	216.45
S&P 500 Index	100	132.39	150.51	152.59	170.83	208.11
S&P 500 Multi-Utilities Index	100	117.88	151.99	149.36	177.08	198.49

Item 6. Selected Financial Data

The following selected financial data of DTE Energy should be read in conjunction with the accompanying Management’s Discussion and Analysis in Item 7 of this Report and Combined Notes to Consolidated Financial Statements in Item 8 of this Report. This information has been omitted for DTE Electric per General Instruction I (2) (a) of Form 10-K for wholly-owned subsidiaries (reduced disclosure format).



	2017		2016		2015		2014		2013
	(In millions, except per share amounts)
Operating Revenues	$	12,607	$	10,630	$	10,337	$	12,301	$	9,661
Net Income Attributable to DTE Energy Company^(a)	$	1,134	$	868	$	727	$	905	$	661
Diluted Earnings Per Common Share	$	6.32	$	4.83	$	4.05	$	5.10	$	3.76
Financial Information
Dividends declared per share of common stock	$	3.36	$	3.06	$	2.84	$	2.69	$	2.59
Total Assets^(b)	$	33,767	$	32,041	$	28,662	$	27,827	$	25,864
Long-Term Debt^(b)(c)	$	12,185	$	11,269	$	8,760	$	8,271	$	7,143
Shareholders’ equity^(b)	$	9,512	$	9,011	$	8,772	$	8,327	$	7,921


(a)	The 2017 results include a $105 million net income tax benefit related to the enactment of the TCJA.


(b)	In October 2016, DTE Energy closed on an acquisition of midstream natural gas assets that are part of the Gas Storage and Pipelines segment. See Note 4 to the Consolidated Financial Statements, "Acquisitions and Exit Activities," for additional information.


(c)	Long-Term Debt includes Capital lease obligations and excludes debt due within one year.

Item 7. 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 with 2017 Operating Revenues of approximately $12.6 billion and Total Assets of approximately $33.8 billion. DTE Energy is the parent company of DTE Electric and DTE Gas, regulated electric and natural gas utilities engaged primarily in the business of providing electricity and natural gas sales, distribution, and storage services throughout Michigan. DTE Energy operates three energy-related non-utility segments with operations throughout the United States.

The following table summarizes DTE Energy's financial results:



	Years Ended December 31,
	2017		2016		2015
	(In millions, except per share amounts)
Net Income Attributable to DTE Energy Company	$	1,134	$	868	$	727
Diluted Earnings per Common Share	$	6.32	$	4.83	$	4.05

The increase in 2017 Net Income Attributable to DTE Energy Company is primarily due to higher earnings in the Gas Storage and Pipelines, Energy Trading, and Power and Industrial Projects segments, partially offset by lower earnings in the Corporate and Other segment. The 2017 increase is also due to $105 million of net income tax benefit related to the enactment of the TCJA. The increase in 2016 Net Income Attributable to DTE Energy Company is primarily due to higher earnings in the Electric and Power and Industrial Projects segments.

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

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

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

In 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 efficiency, 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. 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.

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. In September 2016, DTE Electric received an order from the MPSC in its amended Renewable Energy Plan approving two 150 megawatt wind projects expected to be constructed and in service between 2018 and 2020, and 25 megawatts of company-owned solar projects which will be constructed and in service between 2019 and 2020. DTE Electric constructed and placed in service 50 megawatts of solar generation in 2017. DTE Electric plans to build a natural gas fueled combined cycle generation facility to provide approximately 1,100 megawatts of energy beginning in 2022. In the third quarter of 2017, DTE Electric filed a CON with the MPSC seeking approval for the planned build of this natural gas plant. On January 31, 2018, DTE Electric filed its five-year distribution operations investment and maintenance plan to improve system reliability with the MPSC. DTE Electric plans to seek regulatory approval for capital expenditures consistent with prior ratemaking treatment.

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 NO_x, SO₂, mercury and other emissions. Additional rulemakings are expected 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, the EPA finalized performance standards for emissions of carbon dioxide from new and existing EGUs. The carbon standards for new sources are not expected to have a material impact on DTE Electric since DTE Electric has no plans to build new coal-fired generation, and any potential new gas generation will be able to comply with the applicable standards. In February 2016, the U.S. Supreme Court granted petitioners' requests for a stay of the carbon rules for existing EGUs (also known as the EPA Clean Power Plan) pending final review by the courts. The Clean Power Plan has no legal effect while the stay is in place. On March 28, 2017, a presidential executive order was issued on "Promoting Energy Independence and Economic Growth." The order instructs the EPA to review, and if appropriate, suspend, revise or rescind the Clean Power Plan rule. Additionally, federal agencies have been directed to conduct a review of all existing regulations that potentially burden the development and use of domestically produced energy resources. Following the issuance of this order, the federal government requested the U.S. Court of Appeals for the D.C. Circuit to hold all legal challenges in abeyance until the review of these regulations is completed. 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.

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.

See Items 1. and 2. Business and Properties and Note 18 to the Consolidated Financial Statements in Item 8 of this Report, "Commitments and Contingencies," for further discussion of Environmental Matters.

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.

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 our 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.



	2017			2016			2015
	(In millions)
Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	606		$	622		$	542
Gas	146			138			132
Gas Storage and Pipelines	275			119			107
Power and Industrial Projects	138			95			16
Energy Trading	72			(45		)	(22		)
Corporate and Other	(103		)	(61		)	(48		)
Net Income Attributable to DTE Energy Company	$	1,134		$	868		$	727

ELECTRIC

The Results of Operations discussion for DTE Electric is presented in a reduced disclosure format in accordance with General Instruction I (2) (a) of Form 10-K for wholly-owned subsidiaries.

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



	2017		2016		2015
	(In millions)
Operating Revenues — Utility operations	$	5,102	$	5,225	$	4,901
Fuel and purchased power — utility	1,454		1,532		1,573
Utility Margin	3,648		3,693		3,328
Operation and maintenance	1,428		1,455		1,344
Depreciation and amortization	753		750		637
Taxes other than income	302		284		277
Operating Income	1,165		1,204		1,070
Other (Income) and Deductions	238		229		238
Income Tax Expense	321		353		290
Net Income Attributable to DTE Energy Company	$	606	$	622	$	542

See DTE Electric's Consolidated Statements of Operations in Item 8 of this Report for a complete view of its results.

Utility Margin decreased $45 million in 2017 and increased $365 million in 2016. 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:



	2017			2016
	(In millions)
Implementation of new rates	$	124		$	198
PSCR disallowance in 2017 and 2015, respectively	(13		)	19
Base sales	(26		)	20
Weather	(109		)	96
Securitization bond and tax surcharge	—			40
Renewable energy program	—			12
Amortization of refundable revenue decoupling/deferred gain in 2015	—			(63		)
Regulatory mechanisms and other	(21		)	43
Increase (decrease) in Utility Margin	$	(45	)	$	365



	2017	2016	2015
	(In thousands of MWh)
DTE Electric Sales
Residential	14,885	15,875	15,001
Commercial	17,283	17,521	17,192
Industrial	9,897	10,004	9,690
Other	258	264	291
	42,323	43,664	42,174
Interconnection sales^(a)	2,623	2,334	4,108
Total DTE Electric Sales	44,946	45,998	46,282

DTE Electric Deliveries
Retail and wholesale	42,323	43,664	42,174
Electric retail access, including self generators^(b)	4,820	4,936	4,899
Total DTE Electric Sales and Deliveries	47,143	48,600	47,073


(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.

DTE Electric sales decreased for residential, commercial, and industrial primarily due to favorable weather in 2016.

Operation and maintenance expense decreased $27 million in 2017 and increased $111 million in 2016. The decrease in 2017 was primarily due to decreased power plant generation expenses of $66 million, partially offset by increased storm restoration expenses of $27 million, and increased line clearance expenses of $10 million. The decrease in power plant generation expenses includes an increase of $6 million of costs related to the 2016 fire at a generation facility, offset by $21 million of insurance proceeds received in 2017. The increase in 2016 was primarily due to increased power plant generation expenses of $55 million related to outages, increased distribution operations expenses of $13 million, and $47 million of expenses related to the deferral of negative other postretirement costs pursuant to the order in DTE Electric's base rate case, received in December 2015. The increase in the power plant generation expenses included $19 million of costs related to a fire at a generation facility which were partially reimbursed by insurance proceeds in 2017.

Depreciation and amortization expense increased $3 million in 2017 and increased $113 million in 2016. In 2017, the increase was due to $45 million of increased expense from an increased depreciable base, partially offset by a decrease of $29 million associated with the TRM, and a decrease of $13 million in amortization of regulatory assets. In 2016, $38 million of the increase was due to a higher depreciable base, $42 million was primarily due to the end of Securitization amortization in 2015, and an additional $42 million was associated with the TRM, offset by a $9 million decrease in nuclear decommissioning amortization.

Other (Income) and Deductions increased $9 million in 2017 and decreased $9 million in 2016. The increase in 2017 was primarily due to higher interest expense of $10 million, lower interest income of $8 million related to a sales and use tax settlement received in 2016, and a $7 million contribution to the DTE Energy Foundation, partially offset by $12 million of higher investment earnings and a $3 million decrease in Low Income Self-Sufficiency Plan (LSP) contributions to not-for-profit organizations in 2016. The decrease in 2016 was primarily due to $13 million of higher investment earnings, $8 million of interest income related to a sales and use tax settlement, offset by $3 million of LSP contributions to not-for-profit organizations, $2 million AFUDC equity, and $6 million higher interest expense.

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, impact of 2016 Michigan energy legislation, uncertainty of legislative or regulatory actions regarding climate change, and effects of energy efficiency programs.

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 our recommended method to flow the current and deferred tax benefits of those impacts to ratepayers.

GAS

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



	2017		2016		2015
	(In millions)
Operating Revenues — Utility operations	$	1,388	$	1,324	$	1,376
Cost of gas — utility	443		454		526
Utility Margin	945		870		850
Operation and maintenance	451		411		430
Depreciation and amortization	123		106		104
Taxes other than income	65		64		62
Asset (gains) losses and impairments, net	—		4		—
Operating Income	306		285		254
Other (Income) and Deductions	82		70		50
Income Tax Expense	78		77		72
Net Income Attributable to DTE Energy Company	$	146	$	138	$	132

Utility Margin increased $75 million in 2017 and increased $20 million in 2016. Revenues associated with certain surcharges are offset by related expenses elsewhere in DTE Energy's Consolidated Statements of Operations.

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



	2017			2016
	(In millions)
Implementation of new rates	$	80		$	23
Revenue decoupling mechanism	4			(7		)
Home protection program	3			4
Midstream storage and transportation revenues	(5		)	(2		)
Weather	(6		)	(22		)
Infrastructure recovery mechanism	—			12
Other	(1		)	12
Increase in Utility Margin	$	75		$	20



	2017	2016	2015
	(In Bcf)
Gas Markets
Gas sales	119	116	122
End-user transportation	165	182	169
	284	298	291
Intermediate transportation	260	214	289
Total Gas sales	544	512	580

Operation and maintenance expense increased $40 million in 2017 and decreased $19 million in 2016. The increase in 2017 was primarily due to increased employee benefits expenses of $30 million, increased corporate expenses of $3 million, and increased gas operations expenses of $3 million. The decrease in 2016 was primarily due to decreased uncollectible expenses of $14 million and decreased transmission expenses of $8 million. The decreased uncollectible expenses and transmission expenses in 2016 were primarily the result of weather-related impacts of warmer weather in 2016. Additionally, DTE Gas took actions to reduce costs to partially offset the negative impacts to revenue and utility margin resulting from the warmer weather in 2016.

Depreciation and amortization expense increased $17 million in 2017 and increased $2 million in 2016. The increase in 2017 was primarily due to increased expense from an increased depreciable base and higher depreciation rates.

Other (Income) and Deductions increased $12 million in 2017 and increased $20 million in 2016. The increase in 2017 was primarily due to increased contributions to the DTE Energy Foundation and other not-for-profit organizations of $7 million and higher interest expense of $5 million. The increase in 2016 was primarily due to contributions to the DTE Energy Foundation and other not-for-profit organizations.

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 includes projected changes in sales, operations, maintenance expenses, and working capital. The rate filing also requests an increase in return on equity from 10.1% to 10.5%. 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 our recommended method to flow the current and deferred tax benefits of those impacts to ratepayers.

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:



	2017			2016			2015
	(In millions)
Operating Revenues — Non-utility operations	$	453		$	302		$	243
Cost of gas — Non-utility	30			6			—
Operation and maintenance	83			81			58
Depreciation and amortization	76			45			30
Taxes other than income	8			4			5
Asset (gains) losses and impairments, net	2			—			—
Operating Income	254			166			150
Other (Income) and Deductions	(18		)	(31		)	(29		)
Income Tax Expense (Benefit)	(30		)	71			70
Net Income	302			126			109
Less: Net Income Attributable to Noncontrolling Interests	27			7			2
Net Income Attributable to DTE Energy Company	$	275		$	119		$	107

Operating Revenues — Non-utility operations increased $151 million in 2017 and increased $59 million in 2016. The increase in both periods was primarily due to the acquisition of AGS and SGG in October 2016 and increased volumes on the Bluestone Pipeline and Susquehanna gathering systems.

Cost of gas — Non-utility increased $24 million in 2017 and increased $6 million in 2016. The increase in both periods was primarily driven by the physical purchase of gas from AGS customers for resale to optimize available transportation capacity.

Operation and maintenance expense increased $2 million in 2017 and increased $23 million in 2016. The 2016 increase was primarily due to the transaction costs related to the acquisition of AGS and SGG in 2016 and increased activity on the Susquehanna gathering system.

Depreciation and amortization expense increased $31 million in 2017 and increased $15 million in 2016. The 2017 increase was primarily due to the acquisition of AGS and SGG in October 2016. The 2016 increase was due primarily to the acquisition of AGS and SGG and additional Bluestone and Susquehanna expansion projects placed in service.

Other (Income) and Deductions decreased $13 million in 2017 and increased $2 million in 2016. The 2017 decrease was primarily due to a $16 million net loss on extinguishment of debt within the storage business, and contributions to the DTE Energy Foundation and other not-for-profit organizations, partially offset by increased earnings from pipeline investments. The 2016 increase was primarily due to increased earnings from pipeline investments, partially offset by increased interest expense as a result of the acquisition of AGS and SGG in 2016.

Income Tax Expense (Benefit) decreased $101 million in 2017 from the expense of $71 million in 2016 and increased $1 million in 2016. The 2017 decrease was primarily due to the $115 million remeasurement of deferred tax assets and liabilities to reflect the reduction in the corporate tax rate from the enactment of the TCJA in December 2017. This was partially offset by increased tax expense on higher earnings in 2017.

Net Income Attributable to Noncontrolling Interests increased $20 million in 2017 and increased $5 million in 2016. The increase in both periods was primarily due to the acquisition of SGG in October 2016.

See Note 4 to the Consolidated Financial Statements in Item 8 of this Report, "Acquisitions and Exit Activities" for discussion of the acquisition of AGS and SGG in October 2016.

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. 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.

The October 2016 acquisition of AGS and SGG provides a platform for midstream growth and access to further investment opportunities in the Appalachian basin, an additional connection to the NEXUS Pipeline which should drive incremental volumes on the NEXUS Pipeline, and a new set of producer relationships that may lead to more partnering opportunities.

In May 2017, DTE Energy filed a FERC application for approval of the Birdsboro Pipeline, a 14-mile lateral to serve a new power plant in Pennsylvania. DTE Energy is targeting a 2018 in-service date.

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

POWER AND INDUSTRIAL PROJECTS

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



	2017			2016			2015
	(In millions)
Operating Revenues — Non-utility operations	$	2,089		$	1,906		$	2,224
Fuel, purchased power, and gas — non-utility	1,813			1,640			1,837
Non-utility Margin	276			266			387
Operation and maintenance	343			320			379
Depreciation and amortization	72			72			78
Taxes other than income	11			13			15
Asset (gains) losses and impairments, net	20			(1		)	106
Operating Loss	(170		)	(138		)	(191		)
Other (Income) and Deductions	(64		)	(52		)	(58		)
Income Taxes
Benefit	(42		)	(26		)	(49		)
Production Tax Credits	(153		)	(114		)	(91		)
	(195		)	(140		)	(140		)
Net Income	89			54			7
Less: Net Loss Attributable to Noncontrolling Interests	(49		)	(41		)	(9		)
Net Income Attributable to DTE Energy Company	$	138		$	95		$	16

Operating Revenues — Non-utility operations increased $183 million in 2017 and decreased $318 million in 2016. The changes are due to the following:



	2017
	(In millions)
Higher demand due to improved conditions in the steel business	$	107
Higher production driven by new projects, offset by lower coal prices in the REF business	102
Lower production and one-time recovery in 2016, offset by an acquisition in the renewables business	(9		)
Lower sales primarily associated with expired contracts in the on-site business	(17		)
	$	183

	2016
	(In millions)
Closure of the Shenango coke battery and lower demand in the steel business	$	(264	)
Termination of a lease agreement in the REF business	(40		)
Contract termination at a renewable power project facility, offset by a one-time revenue recovery	(9		)
Other	(5		)
	$	(318	)

Non-utility Margin increased $10 million in 2017 and decreased $121 million in 2016. The changes are due to the following:



	2017
	(In millions)
Higher demand due to improved conditions in the steel business	$	42
Lower production and one-time recovery in 2016 in the renewables business	(11		)
Lower sales primarily associated with expired contracts in the on-site business	(15		)
Other	(6		)
	$	10

	2016
	(In millions)
Closure of the Shenango coke battery and lower demand in the steel business	$	(114	)
Termination of a lease agreement in the REF business	(12		)
Lower fuel costs in a renewable power project business	5
	$	(121	)

Operation and maintenance expense increased $23 million in 2017 and decreased $59 million in 2016. The 2017 increase was primarily due to an increase in maintenance spending driven by improved conditions in the steel business of $16 million, higher maintenance and a new acquisition in the renewables business of $7 million, and an increase associated with new projects in the REF business of $5 million, offset by lower spending as a result of the closure of the Shenango coke battery in 2015 of $6 million. The 2016 decrease was primarily due to lower spending as a result of the closure of the Shenango coke battery in 2015 of $68 million, cost control due to lower demand in the steel business, and lower spending primarily due to the closure of a renewable power project of $4 million, partially offset by an increase associated with new projects in the REF business of $14 million.

Asset (gains) losses and impairments, net decreased by $21 million in 2017 from the net gain of $1 million in 2016 and decreased by $107 million in 2016 from the net loss of $106 million in 2015. The 2017 decrease was primarily due to an impairment in the REF business of $14 million and an impairment of a petroleum coke project of $6 million. The 2016 decrease was primarily due to a loss associated with the closure of the Shenango coke battery in 2015.

Other (Income) and Deductions increased $12 million in 2017 and decreased $6 million in 2016. The 2017 increase was primarily due to increased equity earnings in the renewable business of $9 million and insurance settlements in the renewable and REF businesses of $6 million, offset by increased contributions to the DTE Energy Foundation of $6 million. The 2016 decrease was primarily due to the reduction of refined coal produced at REF sites with investors of $9 million and lower equity earnings primarily from a renewable power project of $8 million, offset by higher contributions to the DTE Energy Foundation and other not-for-profit organizations in 2015 of $11 million.

Income Taxes — Benefit increased by $16 million in 2017 and decreased by $23 million in 2016. The 2017 increase was primarily due to the remeasurement of deferred tax assets and liabilities to reflect the reduction in the corporate tax rate from the enactment of the TCJA in December 2017 of $21 million, an increase due to higher pretax loss of $7 million, and a decrease due to a worthless stock deduction associated with the Shenango closure in 2016 of $10 million. The decrease in 2016 was primarily driven by a lower pretax loss of $33 million, offset by a $10 million worthless stock deduction due to the Shenango closure.

Income Taxes — Production Tax Credits increased by $39 million in 2017 and increased $23 million in 2016. The increase in both periods was primarily due to new projects in the REF business.

Net Loss Attributable to Noncontrolling Interests increased by $8 million in 2017 and increased by $32 million in 2016. The 2017 increase is primarily due to a change in the ownership percentage in one of the REF projects of $8 million. The 2016 increase consists of $27 million due to new lease arrangements and $5 million due to existing lease arrangements with investors at various REF facilities.

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

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:



	2017		2016			2015
	(In millions)
Operating Revenues — Non-utility operations	$	4,277	$	2,575		$	2,459
Purchased power and gas — non-utility	4,077		2,552			2,417
Non-utility Margin	200		23			42
Operation and maintenance	68		63			67
Depreciation and amortization	5		3			2
Taxes other than income	4		2			4
Operating Income (Loss)	123		(45		)	(31		)
Other (Income) and Deductions	2		29			6
Income Tax Expense (Benefit)	49		(29		)	(15		)
Net Income (Loss) Attributable to DTE Energy Company	$	72	$	(45	)	$	(22	)

Operating Revenues — Non-utility operations and Purchased power and gas — non-utility were impacted by an increase in both volumes and gas prices for the year ended December 31, 2017, primarily in the gas structured strategy. For 2016, these line items were impacted by an increase in volumes, partially offset by a decrease in gas prices, primarily in the gas structured strategy.

Non-utility Margin increased $177 million in 2017 and decreased $19 million in 2016. The change in both periods was primarily due to timing from the unrealized and realized margins presented in the following tables:



	2017
	(In millions)
Unrealized Margins^(a)
Favorable results, primarily in gas structured and gas full requirements strategies^(b)	$	113
Unfavorable results, primarily in power and gas trading and power full requirements strategies	(26		)
	$	87
Realized Margins^(a)
Favorable results, primarily in gas structured, environmental trading and gas storage strategies^(c)	$	103
Unfavorable results, primarily in the power full requirements strategy	(13		)
	$	90
Increase in Non-utility Margin	$	177

(a)


(b)	Amount includes $113 million of timing related gains related to gas strategies which will reverse in future periods as the underlying contracts settle.


(c)	Amount includes $95 million of timing related losses related to gas strategies recognized in previous periods that reversed as the underlying contracts settled.



	2016
	(In millions)
Unrealized Margins^(a)
Unfavorable results, primarily in gas structured, gas full requirements, gas transportation, and power trading strategies^(b)	$	(74	)
Favorable results, primarily in gas trading and power full requirements strategies	28
	$	(46	)
Realized Margins^(a)
Favorable results, primarily in power full requirements, gas full requirements, power trading, and gas structured strategies	$	48
Unfavorable results, primarily in the gas transportation strategy^(c)	(21		)
	$	27
Decrease in Non-utility Margin	$	(19	)

(a)


(b)	Amount includes $46 million of timing related losses related to gas strategies which will reverse in future periods as the underlying contracts settle.


(c)	Amount includes $4 million of timing related gains related to gas strategies recognized in previous periods that reversed as the underlying contracts settled.

Other (Income) and Deductions decreased$27 million in 2017 and increased $23 million in 2016. The change in both periods was primarily due to 2016 contributions to the DTE Energy Foundation.

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

See also the "Fair Value" section herein and Notes 12 and 13 to the Consolidated Financial Statements in Item 8 of this Report, "Fair Value" and "Financial and Other Derivative Instruments," respectively.

~~CORPORATE~~EMPLOYEES

Item 1A. Risk Factors

Item 1B. Unresolved Staff Comments

None.

Item 3. Legal Proceedings

Item 4. Mine Safety Disclosures

Not applicable.

Part II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters, and Issuer Purchases of Equity Securities



						Dividends Declared per Share
Year	Quarter	High		Low		Dividends Declared per Share
2017
	First	$	102.96	$	96.56	$	0.8250
	Second	$	111.35	$	100.97	$	0.8250
	Third	$	113.71	$	104.19	$	0.8250
	Fourth	$	116.74	$	106.21	$	0.8825
2016
	First	$	91.00	$	78.01	$	0.7300
	Second	$	99.13	$	84.77	$	0.7300
	Third	$	100.45	$	90.61	$	0.7700
	Fourth	$	99.92	$	89.66	$	0.8250

At December 31, 2017, there were 179,386,967 shares of DTE Energy common stock outstanding. These shares were held by a total of 53,437 shareholders of record.

DTE Electric paid cash dividends on common stock of $432 million in 2017, $420 million in 2016, and $395 million in 2015.

For information on DTE Energy dividend restrictions, see Note 16 to the Consolidated Financial Statements in Item 8 of this Report, "Short-Term Credit Arrangements and Borrowings."

See the following table for information as of December 31, 2017:



	Number of Securities to be Issued Upon Exercise of Outstanding Options	Weighted-Average Exercise Price of Outstanding Options		Number of Securities Remaining Available for Future Issuance Under Equity Compensation Plans
Plans approved by shareholders	105,994	$	42.95	1,437,769

UNREGISTERED SALES OF DTE ENERGY EQUITY SECURITIES AND ~~OTHER~~USE OF PROCEEDS

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



	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
10/01/2017 — 10/31/2017	3,269	$	99.19	—	—	—
11/01/2017 — 11/30/2017	—	$	—	—	—	—
12/01/2017 — 12/31/2017	1,300	$	89.46	—	—	—
Total	4,569			—


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

COMPARISON OF CUMULATIVE FIVE YEAR TOTAL RETURN

Total Return to DTE Energy Shareholders

(Includes reinvestment of dividends)



	Annual Return Percentage Year Ended December 31,
Company/Index	2013	2014	2015		2016	2017
DTE Energy Company	14.89	34.61	(3.77	)	26.93	14.59
S&P 500 Index	32.39	13.69	1.38		11.95	21.82
S&P 500 Multi-Utilities Index	17.88	28.94	(1.73	)	18.56	12.09



	Indexed Returns Year Ended December 31,
	Base Period
Company/Index	2012	2013	2014	2015	2016	2017
DTE Energy Company	100	114.89	154.65	148.82	188.89	216.45
S&P 500 Index	100	132.39	150.51	152.59	170.83	208.11
S&P 500 Multi-Utilities Index	100	117.88	151.99	149.36	177.08	198.49

Item 6. Selected Financial Data



	2017		2016		2015		2014		2013
	(In millions, except per share amounts)
Operating Revenues	$	12,607	$	10,630	$	10,337	$	12,301	$	9,661
Net Income Attributable to DTE Energy Company^(a)	$	1,134	$	868	$	727	$	905	$	661
Diluted Earnings Per Common Share	$	6.32	$	4.83	$	4.05	$	5.10	$	3.76
Financial Information
Dividends declared per share of common stock	$	3.36	$	3.06	$	2.84	$	2.69	$	2.59
Total Assets^(b)	$	33,767	$	32,041	$	28,662	$	27,827	$	25,864
Long-Term Debt^(b)(c)	$	12,185	$	11,269	$	8,760	$	8,271	$	7,143
Shareholders’ equity^(b)	$	9,512	$	9,011	$	8,772	$	8,327	$	7,921


(a)	The 2017 results include a $105 million net income tax benefit related to the enactment of the TCJA.


(b)	In October 2016, DTE Energy closed on an acquisition of midstream natural gas assets that are part of the Gas Storage and Pipelines segment. See Note 4 to the Consolidated Financial Statements, "Acquisitions and Exit Activities," for additional information.


(c)	Long-Term Debt includes Capital lease obligations and excludes debt due within one year.

Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

EXECUTIVE OVERVIEW

The following table summarizes DTE Energy's financial results:



	Years Ended December 31,
	2017		2016		2015
	(In millions, except per share amounts)
Net Income Attributable to DTE Energy Company	$	1,134	$	868	$	727
Diluted Earnings per Common Share	$	6.32	$	4.83	$	4.05

The increase in 2017 Net Income Attributable to DTE Energy Company is primarily due to higher earnings in the Gas Storage and Pipelines, Energy Trading, and Power and Industrial Projects segments, partially offset by lower earnings in the Corporate and Other ~~includes various holding company activities, holds certain~~segment. The 2017 increase is also due to $105 million of net income tax benefit related to the enactment of the TCJA. The increase in 2016 Net Income Attributable to DTE Energy Company is primarily due to higher earnings in the Electric and Power and Industrial Projects segments.

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

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

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 ~~energy-related investments.~~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

ENVIRONMENTAL MATTERS

The Registrants are subject to extensive environmental regulation and expect to continue recovering environmental costs related to utility operations through rates charged to customers. The following table summarizes DTE Energy's, including DTE Electric's, estimated significant future environmental expenditures based upon current regulations. The amounts reported in the following table do not include any expenditures related to the EPA Clean Power Plan as discussed below. Actual costs to comply could vary substantially.regulation. Additional costs may result as the effects of various substances on the environment are studied and governmental regulations are developed and implemented.

DTE Electric DTE Gas Non-utility Total
(In millions)
Air $ 40
$ —
$ —
$ 40
Water 90
—
—
90
Contaminated and other sites 10
20
—
30
Coal Combustion Residuals and Effluent Limitations Guidelines 290
—
—
290
Estimated total future expenditures through 2022 $ 430
$ 20
$ —
$ 450
Estimated 2016 expenditures $ 70
$ 7
$ —
$ 77
Estimated 2017 expenditures $ 40
$ 4
$ —
$ 44
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.

~~Air~~ — DTE Electric is subject to the EPA ozone and fine particulate transport and acid rain regulations that limit power plant emissions of ~~sulfur dioxide~~SO₂ and ~~nitrogen oxides.~~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 ~~additional emission~~ controls on fossil-fueled power plants to reduce ~~nitrogen oxide and sulfur dioxide, with further emission controls planned for reductions of~~NO_x, SO₂, mercury and other emissions. ~~These~~Additional rulemakings are expected over the next few years which could require additional controls for ~~sulfur dioxide, nitrogen oxides,~~SO₂, NO_x, and other hazardous air ~~pollutants over the next few years.~~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 ~~is implementing~~has implemented regulatory actions under the Clean Air Act to address emissions of GHGs from the utility sector and other sectors of the economy. Among these actions, the EPA ~~has~~ finalized performance standards for emissions of carbon dioxide from new and existing ~~electric generating units (EGUs).~~EGUs. The carbon standards for new sources are not expected to have a material impact on DTE Electric since DTE Electric has no plans to build new coal-fired generation, and any potential new gas generation will be able to comply with the applicable standards. In February 2016, the U.S. Supreme Court granted petitioners' requests for a stay of the carbon rules for existing EGUs (also known as the EPA Clean Power Plan) pending final review by the courts. The Clean Power Plan has no legal effect while the stay is in place. On March 28, 2017, a presidential executive order was issued on "Promoting Energy Independence and Economic Growth." The order instructs the EPA to review, and if appropriate, suspend, revise or rescind the Clean Power Plan rule. Additionally, federal agencies have been directed to conduct a review of all existing regulations that potentially burden the development and use of domestically produced energy resources. Following the issuance of this order, the federal government requested the U.S. Court of Appeals for the D.C. Circuit to hold all legal challenges in abeyance until the review of these regulations is completed. 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 ~~final carbon standards (also known as~~EPA's repeal and possible replacement of the ~~EPA~~ Clean Power ~~Plan)~~Plan on existing sources at this time.

~~Water~~ ~~— The EPA finalized regulations on cooling water intake in August 2014.~~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 ~~Electric~~Energy's utility and non-utility segments. At the present time, it is ~~conducting studies~~not possible to ~~determine~~quantify the ~~best technology for reducing the environmental~~financial impacts of these climate related regulatory initiatives on the ~~cooling water intake structures at each of its facilities. DTE Electric may be required to install technologies to reduce the impacts of the cooling water intakes.~~

~~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,~~Registrants or oil. The facilities, which produced gas, have been designated as MGP sites. DTE Gas owns, or previously owned, fourteen such former MGP sites. DTE Electric owns, or previously owned, three former MGP sites. DTE Energy anticipates the cost amortization methodology approved by the MPSC for DTE Gas, which allows DTE Gas to amortize 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 effect on DTE Energy's operations. DTE Electric believes the likelihood of a material change to the accrued amount is remote based on current knowledge of the conditions at each of its sites.

~~Coal Combustion Residuals~~See Items 1. and ~~Effluent Limitations Guidelines~~— In April 2015, the EPA published a final rule for the disposal of coal combustion residuals, commonly known as coal ash. The rule became effective in October 2015. The rule is based on the continued listing of coal ash as a non-hazardous waste2. Business and ~~relies on various self-implementation design~~Properties and performance standards. DTE Electric owns and operates 3 permitted engineered coal ash storage facilities to dispose of coal ash from coal-fired power plants and operates a number of smaller impoundments at its power plants. At certain facilities, the rule requires the installation of monitoring wells, compliance with groundwater standards, and the closure of basins at the end of the useful life of the associated power plant. At other facilities, the rule requires ash laden waters be moved from earthen basins to steel and concrete tanks.

In November 2015, the EPA finalized effluent limitations guidelines for the steam electric power generating industry which may require additional controls to be installed between 2018 and 2023. The initial costs to comply with this rule have been developed and included in the Coal Combustion Residual and Effluent Limitations Guidelines amount in the above table.

~~See Management’s Discussion and Analysis in Item 7 of this Report and Notes 7, 8, and 17~~Note 18 to the Consolidated Financial Statements in Item 8 of this Report, ~~"Regulatory Matters", "Asset Retirement Obligations", and~~ "Commitments and ~~Contingencies"~~Contingencies," for further discussion of Environmental Matters.

OUTLOOK

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

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



	2017			2016			2015
	(In millions)
Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	606		$	622		$	542
Gas	146			138			132
Gas Storage and Pipelines	275			119			107
Power and Industrial Projects	138			95			16
Energy Trading	72			(45		)	(22		)
Corporate and Other	(103		)	(61		)	(48		)
Net Income Attributable to DTE Energy Company	$	1,134		$	868		$	727

ELECTRIC

The Results of Operations discussion for DTE Electric is presented in a reduced disclosure format in accordance with General Instruction I (2) (a) of Form 10-K for wholly-owned subsidiaries.

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



	2017		2016		2015
	(In millions)
Operating Revenues — Utility operations	$	5,102	$	5,225	$	4,901
Fuel and purchased power — utility	1,454		1,532		1,573
Utility Margin	3,648		3,693		3,328
Operation and maintenance	1,428		1,455		1,344
Depreciation and amortization	753		750		637
Taxes other than income	302		284		277
Operating Income	1,165		1,204		1,070
Other (Income) and Deductions	238		229		238
Income Tax Expense	321		353		290
Net Income Attributable to DTE Energy Company	$	606	$	622	$	542

See DTE Electric's Consolidated Statements of Operations in Item 8 of this Report for a complete view of its results.

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



	2017			2016
	(In millions)
Implementation of new rates	$	124		$	198
PSCR disallowance in 2017 and 2015, respectively	(13		)	19
Base sales	(26		)	20
Weather	(109		)	96
Securitization bond and tax surcharge	—			40
Renewable energy program	—			12
Amortization of refundable revenue decoupling/deferred gain in 2015	—			(63		)
Regulatory mechanisms and other	(21		)	43
Increase (decrease) in Utility Margin	$	(45	)	$	365



	2017	2016	2015
	(In thousands of MWh)
DTE Electric Sales
Residential	14,885	15,875	15,001
Commercial	17,283	17,521	17,192
Industrial	9,897	10,004	9,690
Other	258	264	291
	42,323	43,664	42,174
Interconnection sales^(a)	2,623	2,334	4,108
Total DTE Electric Sales	44,946	45,998	46,282

DTE Electric Deliveries
Retail and wholesale	42,323	43,664	42,174
Electric retail access, including self generators^(b)	4,820	4,936	4,899
Total DTE Electric Sales and Deliveries	47,143	48,600	47,073


(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.

DTE Electric sales decreased for residential, commercial, and industrial primarily due to favorable weather in 2016.

GAS

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



	2017		2016		2015
	(In millions)
Operating Revenues — Utility operations	$	1,388	$	1,324	$	1,376
Cost of gas — utility	443		454		526
Utility Margin	945		870		850
Operation and maintenance	451		411		430
Depreciation and amortization	123		106		104
Taxes other than income	65		64		62
Asset (gains) losses and impairments, net	—		4		—
Operating Income	306		285		254
Other (Income) and Deductions	82		70		50
Income Tax Expense	78		77		72
Net Income Attributable to DTE Energy Company	$	146	$	138	$	132

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



	2017			2016
	(In millions)
Implementation of new rates	$	80		$	23
Revenue decoupling mechanism	4			(7		)
Home protection program	3			4
Midstream storage and transportation revenues	(5		)	(2		)
Weather	(6		)	(22		)
Infrastructure recovery mechanism	—			12
Other	(1		)	12
Increase in Utility Margin	$	75		$	20



	2017	2016	2015
	(In Bcf)
Gas Markets
Gas sales	119	116	122
End-user transportation	165	182	169
	284	298	291
Intermediate transportation	260	214	289
Total Gas sales	544	512	580

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:



	2017			2016			2015
	(In millions)
Operating Revenues — Non-utility operations	$	453		$	302		$	243
Cost of gas — Non-utility	30			6			—
Operation and maintenance	83			81			58
Depreciation and amortization	76			45			30
Taxes other than income	8			4			5
Asset (gains) losses and impairments, net	2			—			—
Operating Income	254			166			150
Other (Income) and Deductions	(18		)	(31		)	(29		)
Income Tax Expense (Benefit)	(30		)	71			70
Net Income	302			126			109
Less: Net Income Attributable to Noncontrolling Interests	27			7			2
Net Income Attributable to DTE Energy Company	$	275		$	119		$	107

See Note 4 to the Consolidated Financial Statements in Item 8 of this Report, "Acquisitions and Exit Activities" for discussion of the acquisition of AGS and SGG in October 2016.

In May 2017, DTE Energy filed a FERC application for approval of the Birdsboro Pipeline, a 14-mile lateral to serve a new power plant in Pennsylvania. DTE Energy is targeting a 2018 in-service date.

POWER AND INDUSTRIAL PROJECTS



	2017			2016			2015
	(In millions)
Operating Revenues — Non-utility operations	$	2,089		$	1,906		$	2,224
Fuel, purchased power, and gas — non-utility	1,813			1,640			1,837
Non-utility Margin	276			266			387
Operation and maintenance	343			320			379
Depreciation and amortization	72			72			78
Taxes other than income	11			13			15
Asset (gains) losses and impairments, net	20			(1		)	106
Operating Loss	(170		)	(138		)	(191		)
Other (Income) and Deductions	(64		)	(52		)	(58		)
Income Taxes
Benefit	(42		)	(26		)	(49		)
Production Tax Credits	(153		)	(114		)	(91		)
	(195		)	(140		)	(140		)
Net Income	89			54			7
Less: Net Loss Attributable to Noncontrolling Interests	(49		)	(41		)	(9		)
Net Income Attributable to DTE Energy Company	$	138		$	95		$	16

Operating Revenues — Non-utility operations increased $183 million in 2017 and decreased $318 million in 2016. The changes are due to the following:



	2017
	(In millions)
Higher demand due to improved conditions in the steel business	$	107
Higher production driven by new projects, offset by lower coal prices in the REF business	102
Lower production and one-time recovery in 2016, offset by an acquisition in the renewables business	(9		)
Lower sales primarily associated with expired contracts in the on-site business	(17		)
	$	183

	2016
	(In millions)
Closure of the Shenango coke battery and lower demand in the steel business	$	(264	)
Termination of a lease agreement in the REF business	(40		)
Contract termination at a renewable power project facility, offset by a one-time revenue recovery	(9		)
Other	(5		)
	$	(318	)

Non-utility Margin increased $10 million in 2017 and decreased $121 million in 2016. The changes are due to the following:



	2017
	(In millions)
Higher demand due to improved conditions in the steel business	$	42
Lower production and one-time recovery in 2016 in the renewables business	(11		)
Lower sales primarily associated with expired contracts in the on-site business	(15		)
Other	(6		)
	$	10

	2016
	(In millions)
Closure of the Shenango coke battery and lower demand in the steel business	$	(114	)
Termination of a lease agreement in the REF business	(12		)
Lower fuel costs in a renewable power project business	5
	$	(121	)

Income Taxes — Production Tax Credits increased by $39 million in 2017 and increased $23 million in 2016. The increase in both periods was primarily due to new projects in the REF business.

ENERGY TRADING



	2017		2016			2015
	(In millions)
Operating Revenues — Non-utility operations	$	4,277	$	2,575		$	2,459
Purchased power and gas — non-utility	4,077		2,552			2,417
Non-utility Margin	200		23			42
Operation and maintenance	68		63			67
Depreciation and amortization	5		3			2
Taxes other than income	4		2			4
Operating Income (Loss)	123		(45		)	(31		)
Other (Income) and Deductions	2		29			6
Income Tax Expense (Benefit)	49		(29		)	(15		)
Net Income (Loss) Attributable to DTE Energy Company	$	72	$	(45	)	$	(22	)



	2017
	(In millions)
Unrealized Margins^(a)
Favorable results, primarily in gas structured and gas full requirements strategies^(b)	$	113
Unfavorable results, primarily in power and gas trading and power full requirements strategies	(26		)
	$	87
Realized Margins^(a)
Favorable results, primarily in gas structured, environmental trading and gas storage strategies^(c)	$	103
Unfavorable results, primarily in the power full requirements strategy	(13		)
	$	90
Increase in Non-utility Margin	$	177

(a)


(b)	Amount includes $113 million of timing related gains related to gas strategies which will reverse in future periods as the underlying contracts settle.


(c)	Amount includes $95 million of timing related losses related to gas strategies recognized in previous periods that reversed as the underlying contracts settled.



	2016
	(In millions)
Unrealized Margins^(a)
Unfavorable results, primarily in gas structured, gas full requirements, gas transportation, and power trading strategies^(b)	$	(74	)
Favorable results, primarily in gas trading and power full requirements strategies	28
	$	(46	)
Realized Margins^(a)
Favorable results, primarily in power full requirements, gas full requirements, power trading, and gas structured strategies	$	48
Unfavorable results, primarily in the gas transportation strategy^(c)	(21		)
	$	27
Decrease in Non-utility Margin	$	(19	)

(a)


(b)	Amount includes $46 million of timing related losses related to gas strategies which will reverse in future periods as the underlying contracts settle.


(c)	Amount includes $4 million of timing related gains related to gas strategies recognized in previous periods that reversed as the underlying contracts settled.

Other (Income) and Deductions decreased$27 million in 2017 and increased $23 million in 2016. The change in both periods was primarily due to 2016 contributions to the DTE Energy Foundation.

EMPLOYEES

DTE Energy and its subsidiaries had approximately ~~10,000~~10,200 employees as of December 31, ~~2015,~~2017, of which approximately ~~4,900~~5,000 were represented by unions. DTE Electric had approximately ~~4,500~~4,700 employees as of December 31, ~~2015,~~2017, of which approximately ~~2,600~~2,700 were represented by unions. There are several bargaining units for DTE ~~Energy’s~~Energy subsidiaries' represented employees. The majority of represented employees for both DTE Energy and DTE Electric are under contracts that expire in ~~2016~~2020 and ~~2017.~~2021.

Item 1A.Risk Factors

The Registrants are subject to rate regulation.Electric and gas rates for the utilities are set by the MPSC and the FERC and cannot be changed without regulatory authorization. The Registrants may be negatively impacted by new regulations or interpretations by the MPSC, the FERC, or other regulatory bodies. The Registrants' ability to recover costs may be impacted by the time lag between the incurrence of costs and the recovery of the costs in customers' rates. Regulators also may decide to disallow recovery of certain costs in customers' rates if they determine that those costs do not meet the standards for recovery under current governing laws and regulations. The Registrants' utilities typically self-implement base rate changes six months after rate case filings, in accordance with Michigan law. However, if the final rates authorized by regulators in the final rate order are lower than the amounts the Registrants collected during the self-implementation period, the Registrants must refund the difference with interest. Regulators may also disagree with the Registrants' rate calculations under the various mechanisms that are intended to mitigate the risk to their utilities related to certain aspects of the business. If the Registrants cannot agree with regulators on an appropriate reconciliation of those mechanisms, it may impact the Registrants' ability to recover certain costs through customer rates. Regulators may also decide to eliminate these mechanisms in future rate cases, which may make it more difficult for the Registrants to recover their costs in the rates charged to customers. The Registrants cannot predict what rates the MPSC will authorize in future rate cases. New legislation, regulations, or interpretations could change how the business operates, impact the Registrants' ability to recover costs through rates or the timing of such recovery, or require the Registrants to incur additional expenses. ~~The outcome of the current Michigan energy policy reform legislative process could impact the Registrants' recovery of costs through rates.~~

Changes to Michigan's electric retail access program could negatively impact the Registrants' financial performance. The State of Michigan currently experiences a hybrid market, where the MPSC continues to regulate electric rates for DTE Electric customers, while alternative electric suppliers charge market-based rates. MPSC rate orders, and energy legislation enacted by the State of Michigan, ~~in 2008,~~ have placed a 10% cap on the total potential retail access migration. However, even with the legislated 10% cap on participation, there continues to be legislative and financial risk associated with the electric retail access program. Electric retail access migration is sensitive to market price and full service electric price changes. The Registrants are required under current regulation to provide full service to retail access customers that choose to return, potentially resulting in the need for additional generating capacity. ~~The outcome of the current Michigan energy policy reform legislative process could impact the Registrants' recovery of costs through rates.~~

The MISO regional energy market, including the State of Michigan, is expected to face capacity constraints beginning in 2016, due primarily to the retirement of coal-fired generation caused by increasingly stringent environmental requirements. Significant investment in new natural gas-fired generation and renewables will be required. Under the current regulatory structure, retail access customers do not fund capacity costs, potentially impacting electric supply reliability and utility customer affordability.

Uncertainty around future environmental regulations creates difficulty planning long-term capital projects in the Registrants' generation fleet and, for DTE ~~Energy,~~Energy's gas distribution businesses. These laws and regulations require the Registrants to seek a variety of environmental licenses, permits, inspections, and other regulatory approvals. The Registrants could be required to install expensive pollution control measures or limit or cease activities, including the retirement of certain generating plants, based on these regulations. Additionally, the Registrants may become a responsible party for environmental cleanup at sites identified by a regulatory body. The Registrants cannot predict with certainty the amount and timing of future expenditures related to environmental matters because of the difficulty of estimating cleanup costs. There is also uncertainty in quantifying liabilities under environmental laws that impose joint and several liability on potentially responsible parties.

Operation of a nuclear facility subjects the Registrants to risk. Ownership of an operating nuclear generating plant subjects the Registrants to significant additional risks. These risks include, among others, plant security, environmental regulation and remediation, changes in federal nuclear regulation, increased capital expenditures to meet industry requirements, and operational factors that can significantly impact the performance and cost of operating a nuclear ~~facility.~~facility compared to other generation options. While the Registrants maintain insurance for various nuclear-related risks, there can be no assurances that such insurance will be sufficient to cover the Registrants' costs in the event of an accident or business interruption at the nuclear generating plant, which may affect the Registrants' financial performance. In addition, while the Registrants have a nuclear decommissioning trust fund to finance the decommissioning of the nuclear generating plant, there can be no assurances that such fund will be sufficient to fund the cost of decommissioning. A decline in market value of assets held in decommissioning trust funds due to poor investment performance or other factors may increase the funding requirements for these obligations. Any increase in funding requirements may have a material impact on the Registrants’ liquidity, financial position, or results of operations.

The supply and/or price of energy commodities and/or related services may impact the Registrants' financial results.The Registrants are dependent on coal for much of their electrical generating capacity. DTE Energy's access to natural gas supplies is critical to ensure reliability of service for utility gas customers. DTE Energy's non-utility businesses are also dependent upon supplies and prices of energy commodities and services. Price fluctuations, fuel supply disruptions, and changes in transportation costs, could have a negative impact on the amounts DTE Electric charges utility customers for electricity and DTE Gas charges utility customers for gas and on the profitability of DTE Energy's non-utility businesses. The Registrants have hedging strategies and regulatory recovery mechanisms in place to mitigate some of the negative fluctuations in commodity supply prices in their utility and, for DTE Energy, non-utility businesses, but there can be no assurances that the Registrants' financial performance will not be negatively impacted by price fluctuations. The price of energy also impacts the market for DTE Energy's non-utility businesses that compete with utilities and alternative electric suppliers.

Poor investment performance of pension and other postretirement benefit plan assets and other factors impacting benefit plan costs could unfavorably impact the Registrants' liquidity and results of operations.The Registrants' costs of providing non-contributory defined benefit pension plans and other postretirement benefit plans are dependent upon a number of factors, such as the rates of return on plan assets, the level of interest rates used to measure the required minimum funding levels of the plans, future government regulation, and the Registrants' required or voluntary contributions made to the plans. The performance of the debt and equity markets affects the value of assets that are held in trust to satisfy future obligations under the Registrants' plans. The Registrants have significant benefit obligations and hold significant assets in trust to satisfy these obligations. These assets are subject to market fluctuations and will yield uncertain returns, which may fall below the Registrants' projected return rates. A decline in the market value of the pension and other postretirement benefit plan assets will increase the funding requirements under the pension and other postretirement benefit plans if the actual asset returns do not recover these declines in the foreseeable future. Additionally, the pension and other postretirement benefit plan liabilities are sensitive to changes in interest rates. As interest rates decrease, the liabilities increase, resulting in increasing benefit expense and funding requirements. Also, if future increases in pension and other postretirement benefit costs as a result of reduced plan assets are not recoverable from the Registrants' utility customers, the results of operations and financial position of the Registrants could be negatively affected. Without sustained growth in the plan investments over time to increase the value of plan assets, the Registrants could be required to fund these plans with significant amounts of cash. Such cash funding obligations could have a material impact on the Registrants' cash flows, financial position, or results of operations.

The Registrants' ability to access capital markets is important.The Registrants' ability to access capital markets is important to operate their businesses and to fund capital investments. Turmoil in credit markets may constrain the Registrants' ability, as well as the ability of their subsidiaries, to issue new debt, including commercial paper, and refinance existing debt at reasonable interest rates. In addition, the level of borrowing by other energy companies, and the market as a whole, could limit the Registrants' access to capital markets. The Registrants' long-term revolving credit facilities do not expire until ~~2020,~~2022, but the Registrants regularly access capital markets to refinance existing debt or fund new projects at the Registrants' utilities and DTE Energy's non-utility businesses, and the Registrants cannot predict the pricing or demand for those future transactions.

~~Construction and capital improvements to the Registrants' power facilities and DTE Energy's distribution systems subject them to risk.~~ The Registrants are managing ongoing, and planning future, significant construction and capital improvement projects at multiple power generation and distribution facilities and DTE Energy's gas distribution system. Many factors that could cause delays or increased prices for these complex projects are beyond the Registrants' control, including the cost of materials and labor, subcontractor performance, timing and issuance of necessary permits, construction disputes, and weather conditions. Failure to complete these projects on schedule and on budget for any reason could adversely affect the Registrants' financial performance and operations at the affected facilities and businesses.

~~DTE Energy's non-utility businesses may not perform to its expectations.~~ DTE Energy relies on non-utility operations for an increasing portion of earnings. If DTE Energy's current and contemplated non-utility investments do not perform at expected levels, DTE Energy could experience diminished earnings and a corresponding decline in shareholder value.

DTE Energy's participation in energy trading markets subjects it to risk.Events in the energy trading industry have increased the level of scrutiny on the energy trading business and the energy industry as a whole. In certain situations, DTE Energy may be required to post collateral to support trading operations, which could be substantial. If access to liquidity to support trading activities is curtailed, DTE Energy could experience decreased earnings potential and cash flows. Energy trading activities take place in volatile markets and expose DTE Energy to risks related to commodity price movements, deviations in weather, and other related risks. DTE Energy's trading business routinely has speculative trading positions in the market, within strict policy guidelines DTE Energy sets, resulting from the management of DTE Energy's business portfolio. To the extent speculative trading positions exist, fluctuating commodity prices can improve or diminish DTE Energy's financial results and financial position. DTE Energy manages its exposure by establishing and enforcing strict risk limits and risk management procedures. During periods of extreme volatility, these risk limits and risk management procedures may not work as planned and cannot eliminate all risks associated with these activities.

DTE Energy's ability to utilize production tax credits may be limited. To reduce U.S. dependence on imported oil, the Internal Revenue Code provides production tax credits as an incentive for taxpayers to produce fuels and electricity from alternative sources. DTE Energy generated production tax credits from coke production, landfill gas recovery, reduced emission fuel, renewable energy generation, and gas production operations. ~~All production tax credits taken after 2013 are subject to audit by the IRS.~~ If DTE Energy's production tax credits were disallowed in whole or in part as a result of an IRS audit or changes in tax law there could be additional tax liabilities owed for previously recognized tax credits that could significantly impact DTE Energy's earnings and cash flows.

Weather significantly affects operations.At both utilities, deviations from normal hot and cold weather conditions affect the Registrants' earnings and cash flows. Mild temperatures can result in decreased utilization of the Registrants' assets, lowering income and cash flows. At DTE Electric, ice storms, tornadoes, or high winds can damage the electric distribution system infrastructure and power generation facilities and require it to perform emergency repairs and incur material unplanned expenses. The expenses of storm restoration efforts may not be fully recoverable through the regulatory process. DTE Gas can experience higher than anticipated expenses from emergency repairs on its gas distribution infrastructure required as a result of weather related issues.

~~DTE Energy relies on cash flows from subsidiaries.~~ DTE Energy is a holding company. Cash flows from the utility and non-utility subsidiaries are required to pay interest expenses and dividends on DTE Energy debt and securities. Should a major subsidiary not be able to pay dividends or transfer cash flows to DTE Energy, its ability to pay interest and dividends would be restricted.

Renewable portfolio standards and energy efficiency programs may affect the Registrants' business.The Registrants are subject to existing Michigan, and potential future, federal legislation and regulation requiring them to secure sources of renewable energy. The Registrants have complied with the existing federal and state legislation, but do not know what requirements may be added by federal ~~legislation.~~or state legislation in the future. In addition, ~~there could be additional state requirements~~the Registrants expect to comply with new Michigan legislation increasing the percentage of power required to be provided by renewable energy sources. The Registrants cannot predict the financial impact or costs associated with complying with potential future legislation and regulations. Compliance with these requirements can significantly increase capital expenditures and operating expenses and can negatively affect the affordability of the rates charged to customers.

~~Threats of terrorism or cyber-attacks could affect the Registrants' business.~~ The Registrants may be threatened by problems such as computer viruses or terrorism that may disrupt the Registrants' operations and could harm the Registrants' operating results. The Registrants' industry requires the continued operation of sophisticated information technology systems and network infrastructure. Despite implementation of security measures, all of the Registrants' technology systems are vulnerable to disability or failures due to hacking, viruses, acts of war or terrorism, and other causes. If the Registrants' information technology systems were to fail and they were unable to recover in a timely way, the Registrants might be unable to fulfill critical business functions, which could have a material adverse effect on the Registrants' business, operating results, and financial condition.

In addition, the Registrants' generation plants and electrical distribution facilities and, for DTE Energy, gas pipeline and storage facilities, in particular may be targets of terrorist activities that could disrupt the Registrants' ability to produce or distribute some portion of their products. The Registrants have increased security as a result of past events and may be required by regulators or by the future terrorist threat environment to make investments in security that the Registrants cannot currently predict.

~~Failure to maintain the security of personally identifiable information could adversely affect the Registrants.~~ In connection with the Registrant's businesses, they collect and retain personally identifiable information of their customers, shareholders, and employees. Customers, shareholders, and employees expect that the Registrants will adequately protect their personal information, and the regulatory environment surrounding information security and privacy is increasingly demanding. A significant theft, loss, or fraudulent use of customer, shareholder, employee, or Registrant data by cybercrime or otherwise could adversely impact the Registrants' reputation and could result in significant costs, fines, and litigation.

Failure to attract and retain key executive officers and other skilled professional and technical employees could have an adverse effect on the ~~Registrants' operations.~~Registrants’ operations. The Registrants' businesses are dependent on their ability to attract and retain skilled employees. Competition for skilled employees in some areas is high, and the inability to attract and retain these employees could adversely affect the Registrants' business and future operating results. In addition, the Registrants have an aging utility workforce, and the failure of a successful transfer of knowledge and expertise could negatively impact their operations.

A work interruption may adversely affect the Registrants. There are several bargaining units for DTE Energy's approximately ~~4,900~~5,000 and DTE Electric's approximately ~~2,600~~2,700 represented employees. The majority of represented employees are under contracts that expire in ~~2016~~2020 and ~~2017.~~2021. A union choosing to strike would have an impact on the Registrants' businesses. The Registrants are unable to predict the effect a work stoppage would have on their costs of operations and financial performance.

The Registrants' businesses have safety risks. The Registrants' electric distribution system, power plants, ~~wind~~renewable energy equipment, and other facilities, and DTE Energy's gas distribution system, gas infrastructure, and other facilities, could be involved in incidents that result in injury, death, or property loss to employees, customers, or the public. Although the Registrants have insurance coverage for many potential incidents, depending upon the nature and severity of any incident, they could experience financial loss, damage to their reputation, and negative consequences from regulatory agencies or other public authorities.

The Registrants may not be fully covered by insurance. The Registrants have a comprehensive insurance program in place to provide coverage for various types of risks, including catastrophic damage as a result of ~~acts of God,~~severe weather or other natural disasters, war, terrorism, or a combination of other significant unforeseen events that could impact the Registrants' operations. Economic losses might not be covered in full by insurance, or the Registrants' insurers may be unable to meet contractual ~~obligations~~.obligations.

Item 1B. Unresolved Staff Comments

None.

Item 3. Legal Proceedings

For more information on ~~material~~ legal proceedings and matters related to the Registrants, see Notes 89 and 1718 to the Consolidated Financial Statements in Item 8 of this Report, "Regulatory Matters" and "Commitments and ~~Contingencies".~~Contingencies," respectively.

Item 4. Mine Safety Disclosures

Not applicable.

Part II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters, and Issuer Purchases of Equity Securities

DTE Energy common stock is listed on the New York Stock Exchange, which is the principal market for such stock. The following table indicates the reported high and low sales prices of DTE Energy common stock on the Composite Tape of the New York Stock Exchange and dividends ~~paid~~declared per share for each quarterly period during the past two years:

Dividends
Paid per Share
Year Quarter High Low
2015

First $ 92.27
$ 76.84
$ 0.6900
Second $ 84.27
$ 73.23
$ 0.6900
Third $ 85.12
$ 74.53
$ 0.7300
Fourth $ 85.36
$ 77.35
$ 0.7300
2014

First $ 74.61
$ 64.84
$ 0.6550
Second $ 79.45
$ 72.76
$ 0.6550
Third $ 78.89
$ 71.60
$ 0.6900
Fourth $ 90.77
$ 75.76
$ 0.6900



						Dividends Declared per Share
Year	Quarter	High		Low		Dividends Declared per Share
2017
	First	$	102.96	$	96.56	$	0.8250
	Second	$	111.35	$	100.97	$	0.8250
	Third	$	113.71	$	104.19	$	0.8250
	Fourth	$	116.74	$	106.21	$	0.8825
2016
	First	$	91.00	$	78.01	$	0.7300
	Second	$	99.13	$	84.77	$	0.7300
	Third	$	100.45	$	90.61	$	0.7700
	Fourth	$	99.92	$	89.66	$	0.8250

At December 31, ~~2015,~~2017, there were ~~179,470,213~~179,386,967 shares of DTE Energy common stock outstanding. These shares were held by a total of ~~58,999~~53,437 shareholders of record.

DTE Energy paid cash dividends on common stock of $592 million in 2017, $531 million in 2016, and $501 million in ~~2015, $470 million in 2014, and $445 million in 2013.~~2015. The amount of future dividends will depend on DTE Energy's earnings, cash flows, financial condition, and other factors that are periodically reviewed by the DTE Energy Board of Directors. Although there can be no assurances, DTE Energy anticipates paying dividends for the foreseeable future.

All of the ~~138,632,324~~138,632,234 issued and outstanding shares of DTE Electric common stock, par value $10 per share, are owned by DTE Energy, and constitute 100% of the voting securities of DTE Electric. Therefore, no market exists for DTE Electric's common stock.

DTE Electric paid cash dividends on common stock of $432 million in 2017, $420 million in 2016, and $395 million in ~~2015, $370 million in 2014, and $342 million in 2013.~~2015.

For information on DTE Energy dividend restrictions, see Note 1516 to the Consolidated Financial Statements in Item 8 of this Report, "Short-Term Credit Arrangements and ~~Borrowings".~~Borrowings."

All of DTE Energy's equity compensation plans that provide for the annual awarding of stock-based compensation have been approved by shareholders. For additional detail, see Note 1921 to the Consolidated Financial Statements in Item 8 of this Report, "Stock-Based ~~Compensation".~~Compensation."

See the following table for information as of December 31, ~~2015:~~2017:

Number of Securities to be Issued Upon Exercise of Outstanding Options Weighted-Average Exercise Price of Outstanding Options Number of Securities Remaining Available for Future Issuance Under Equity Compensation Plans
Plans approved by shareholders 262,282
$ 42.52
2,892,454



	Number of Securities to be Issued Upon Exercise of Outstanding Options	Weighted-Average Exercise Price of Outstanding Options		Number of Securities Remaining Available for Future Issuance Under Equity Compensation Plans
Plans approved by shareholders	105,994	$	42.95	1,437,769

UNREGISTERED SALES OF DTE ENERGY EQUITY SECURITIES AND USE OF PROCEEDS

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

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
10/01/2015 — 10/31/2015 1,576
$ 79.43
—
—
—
11/01/2015 — 11/30/2015 2,436
$ 78.53
—
—
—
12/01/2015 — 12/31/2015 1,900
$ 78.42
—
—
—
Total 5,912

—



	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
10/01/2017 — 10/31/2017	3,269	$	99.19	—	—	—
11/01/2017 — 11/30/2017	—	$	—	—	—	—
12/01/2017 — 12/31/2017	1,300	$	89.46	—	—	—
Total	4,569			—


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

COMPARISON OF CUMULATIVE FIVE YEAR TOTAL RETURN

Total Return to DTE Energy Shareholders

(Includes reinvestment of dividends)


	Annual Return Percentage Year Ended December 31,						Annual Return Percentage Year Ended December 31,
Company/Index	2011	2012	2013	2014	2015		2013	2014	2015		2016	2017
DTE Energy Company	25.76	14.90	14.89	34.61	(3.77	)	14.89	34.61	(3.77	)	26.93	14.59
S&P 500 Index	2.11	16.00	32.39	13.69	1.38		32.39	13.69	1.38		11.95	21.82
S&P 500 Multi-Utilities Index	18.41	4.24	17.88	28.94	(1.73	)	17.88	28.94	(1.73	)	18.56	12.09

Indexed Returns
Year Ended December 31,
Base Period
Company/Index 2010 2011 2012 2013 2014 2015
DTE Energy Company 100
125.76
144.51
166.03
223.49
215.07
S&P 500 Index 100
102.11
118.45
156.82
178.29
180.75
S&P 500 Multi-Utilities Index 100
118.41
123.42
145.50
187.59
184.35



	Indexed Returns Year Ended December 31,
	Base Period
Company/Index	2012	2013	2014	2015	2016	2017
DTE Energy Company	100	114.89	154.65	148.82	188.89	216.45
S&P 500 Index	100	132.39	150.51	152.59	170.83	208.11
S&P 500 Multi-Utilities Index	100	117.88	151.99	149.36	177.08	198.49

Item 6. Selected Financial Data

2015 2014 2013 2012 2011
(In millions, except per share amounts)
Operating Revenues $ 10,337
$ 12,301
$ 9,661
$ 8,791
$ 8,858
Net Income Attributable to DTE Energy Company
Income from continuing operations attributable to DTE Energy Company (a) $ 727
$ 905
$ 661
$ 666
$ 714
Discontinued operations (b) —
—
—
(56 ) (3 )
Net Income Attributable to DTE Energy Company $ 727
$ 905
$ 661
$ 610
$ 711
Diluted Earnings Per Common Share
Income from continuing operations $ 4.05
$ 5.10
$ 3.76
$ 3.88
$ 4.20
Discontinued operations —
—
—
(0.33 ) (0.02 )
Diluted Earnings Per Common Share $ 4.05
$ 5.10
$ 3.76
$ 3.55
$ 4.18
Financial Information
Dividends declared per share of common stock $ 2.84
$ 2.69
$ 2.59
$ 2.42
$ 2.32
Total assets $ 28,737
$ 27,899
$ 25,935
$ 26,318
$ 25,958
Long-term debt, including capital leases $ 8,835
$ 8,343
$ 7,214
$ 7,014
$ 7,187
Shareholders’ equity $ 8,772
$ 8,327
$ 7,921
$ 7,373
$ 7,009



	2017		2016		2015		2014		2013
	(In millions, except per share amounts)
Operating Revenues	$	12,607	$	10,630	$	10,337	$	12,301	$	9,661
Net Income Attributable to DTE Energy Company^(a)	$	1,134	$	868	$	727	$	905	$	661
Diluted Earnings Per Common Share	$	6.32	$	4.83	$	4.05	$	5.10	$	3.76
Financial Information
Dividends declared per share of common stock	$	3.36	$	3.06	$	2.84	$	2.69	$	2.59
Total Assets^(b)	$	33,767	$	32,041	$	28,662	$	27,827	$	25,864
Long-Term Debt^(b)(c)	$	12,185	$	11,269	$	8,760	$	8,271	$	7,143
Shareholders’ equity^(b)	$	9,512	$	9,011	$	8,772	$	8,327	$	7,921


(a)	~~2011~~The 2017 results include ~~an $87~~a $105 million net income tax benefit related to the enactment of the ~~MCIT.~~TCJA.

(b)

~~Discontinued operations represents~~In October 2016, DTE ~~Energy's Unconventional~~Energy closed on an acquisition of midstream natural gas assets that are part of the Gas ~~Production business that was sold in 2012 resulting in a $55 million after-tax loss on sale.~~Storage and Pipelines segment. See Note 4 to the Consolidated Financial Statements, "Acquisitions and Exit Activities," for additional information.


(c)	Long-Term Debt includes Capital lease obligations and excludes debt due within one year.

Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

EXECUTIVE OVERVIEW

DTE Energy is a diversified energy company with ~~2015 operating revenues~~2017 Operating Revenues of approximately ~~$10.3~~$12.6 billion and ~~assets~~Total Assets of approximately ~~$28.7~~$33.8 billion. DTE Energy is the parent company of DTE Electric and DTE Gas, regulated electric and natural gas utilities engaged primarily in the business of providing electricity and natural gas sales, distribution, and storage services throughout Michigan. DTE Energy operates three energy-related non-utility segments with operations throughout the United States.

The following table summarizes DTE Energy's financial results:


	Years Ended December 31,						Years Ended December 31,
	2015		2014		2013		2017		2016		2015
	(In millions, except per share amounts)						(In millions, except per share amounts)
Net Income Attributable to DTE Energy Company	$	727	$	905	$	661	$	1,134	$	868	$	727
Diluted Earnings per Common Share	$	4.05	$	5.10	$	3.76	$	6.32	$	4.83	$	4.05

~~The decrease in 2015 Net Income Attributable to DTE Energy Company is primarily due to lower earnings in the Energy Trading and Power and Industrial Projects segments.~~ The increase in ~~2014~~2017 Net Income Attributable to DTE Energy Company is primarily due to higher earnings in the Gas Storage and Pipelines, Energy Trading, ~~Electric,~~and Power and Industrial Projects segments, partially offset by lower earnings in the Corporate and ~~Gas Storage~~Other segment. The 2017 increase is also due to $105 million of net income tax benefit related to the enactment of the TCJA. The increase in 2016 Net Income Attributable to DTE Energy Company is primarily due to higher earnings in the Electric and ~~Pipelines~~Power and Industrial Projects segments.

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

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

CAPITAL INVESTMENTS

DTE Electric's capital investments over the ~~2016-2020~~2018-2022 period are estimated at ~~$8.2~~$10.4 billion comprised of ~~$3.8~~$4.1 billion for ~~maintenance~~capital replacements and other projects, ~~$3.2~~$4.3 billion for distribution infrastructure, and ~~$1.2~~$2.0 billion for new generation. ~~Over~~DTE Electric has retired four coal-fired generation units at the ~~next fifteen years,~~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. In September 2016, DTE Electric received an order from the MPSC in its amended Renewable Energy Plan approving two 150 megawatt wind projects expected to be constructed and in service between 2018 and 2020, and 25 megawatts of company-owned solar projects which will be constructed and in service between 2019 and 2020. DTE Electric constructed and placed in service 50 megawatts of solar generation in 2017. DTE Electric plans to ~~retire~~build a ~~portion~~natural gas fueled combined cycle generation facility to provide approximately 1,100 megawatts of ~~its coal-fired generation and to increase~~energy beginning in 2022. In the ~~proportion~~third quarter of ~~its generation mix attributable to natural gas-fired generation and renewables.~~2017, DTE Electric ~~acquired two~~filed a CON with the MPSC seeking approval for the planned build of this natural gas ~~facilities in 2015, as described in Note 4~~plant. On January 31, 2018, DTE Electric filed its five-year distribution operations investment and maintenance plan to improve system reliability with the ~~Consolidated Financial Statements in Item 8 of this Report, "Acquisitions and Exit Activities".~~MPSC. DTE Electric plans to seek regulatory approval ~~in general rate case filings and renewable energy plan filings~~ for capital expenditures consistent with prior ratemaking treatment.

DTE Gas' capital investments over the ~~2016-2020~~2018-2022 period are estimated at ~~$1.6~~$2.1 billion comprised of ~~$750~~$950 million for base infrastructure, ~~$650 million~~$1.1 billion for gas main renewal, meter move out, and pipeline integrity programs, and ~~$200~~$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. ~~See Note 8 to the Consolidated Financial Statements in Item 8 of this Report, "Regulatory Matters" for a description of DTE Gas' IRM.~~

DTE Energy's non-utility businesses' capital investments are primarily for expansion, growth, and ongoing maintenance. Gas Storage and Pipelines' capital investments over the ~~2016-2020~~2018-2022 period are estimated at ~~$2.0~~$2.8 billion to ~~$2.6~~$3.4 billion for gathering and pipeline investments and expansions, including the NEXUS Pipeline. Power and Industrial Projects' capital investments over the ~~2016-2020~~2018-2022 period are estimated at ~~$600~~$800 million to ~~$950 million~~$1.2 billion for investments in cogeneration and on-site energy projects.

ENVIRONMENTAL MATTERS

DTE Electric is subject to the EPA ozone and fine particulate transport and acid rain regulations that limit power plant emissions of ~~sulfur dioxide~~SO₂ and ~~nitrogen oxides.~~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 ~~additional emission~~ controls on fossil-fueled power plants to reduce ~~nitrogen oxide and sulfur dioxide, with further emission controls planned for reductions of~~NO_x, SO₂, mercury and other emissions. ~~These~~Additional rulemakings are expected over the next few years which could require additional controls for ~~sulfur dioxide, nitrogen oxides,~~SO₂, NO_x, and other hazardous air ~~pollutants over the next few years.~~pollutants. To comply with ~~these~~existing requirements, DTE Electric spent approximately ~~$2.3~~$2.4 billion through ~~2015. It is estimated that~~2017. DTE Electric ~~will make~~does not anticipate additional capital expenditures ~~of approximately $40 million in 2016.~~through 2024.

~~As directed by a June 2013 Presidential Memorandum, the~~The EPA ~~is implementing~~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 August 2015,~~ the EPA finalized performance standards for emissions of carbon dioxide from new and existing ~~electric generating units (EGUs).~~EGUs. The carbon performance standards, known as the Clean Power Plan (CPP), require states to meet emission reduction targets from existing fossil-fueled EGUs beginning in 2022. The EPA has finalized interim standards applicable from 2022 to 2029 leading to emission standards to be achieved in 2030. States must submit initial compliance plans in September 2016, but may request an extension to submit a final compliance plan by September 2018. States that fail to submit a plan or do not meet EPA criteria for a complete plan will be subject to a federal plan that was proposed by the EPA with the final CPP.

~~The Registrants are working with the State of Michigan and other stakeholders to shape the CPP compliance plan for Michigan. The final~~ carbon standards for new sources are not expected to have a material impact on ~~the Registrants,~~DTE Electric since ~~the Registrants have~~DTE Electric has no plans to build new coal-fired generation, and any potential new gas generation will be able to comply with the applicable standards. AtIn February 2016, the ~~present time,~~U.S. Supreme Court granted petitioners' requests for a stay of the carbon rules for existing EGUs (also known as the EPA Clean Power Plan) pending final review by the courts. The Clean Power Plan has no legal effect while the stay is in place. On March 28, 2017, a presidential executive order was issued on "Promoting Energy Independence and Economic Growth." The order instructs the EPA to review, and if appropriate, suspend, revise or rescind the Clean Power Plan rule. Additionally, federal agencies have been directed to conduct a review of all existing regulations that potentially burden the development and use of domestically produced energy resources. Following the issuance of this order, the federal government requested the U.S. Court of Appeals for the D.C. Circuit to hold all legal challenges in abeyance until the review of these regulations is completed. 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 ~~final performance standards for~~EPA's repeal and possible replacement of the Clean Power Plan on existing ~~power plants due to the multitude of options available to states for compliance that require careful analysis and input from numerous stakeholders.~~ sources at this time.

Pending or future legislation or other regulatory actions could have a material impact on ~~the Registrants'~~DTE Electric's operations and financial position and the rates ~~the Registrants charge~~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. ~~The Registrants~~DTE Electric would seek to recover these incremental costs through increased rates charged to ~~their~~its utility customers, as authorized by the MPSC.

Increased costs for energy produced from traditional coal-based sources due to recent, pending, and future regulatory initiatives, could also increase the economic viability of energy produced from renewable, natural ~~gas-fired~~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.

See Items 1. and 2. Business and Properties and Note 1718 to the Consolidated Financial Statements in Item 8 of this Report, "Commitments and ~~Contingencies",~~Contingencies," for further discussion of Environmental Matters.

~~EXIT ACTIVITIES~~

During the fourth quarter of 2015, DTE Energy announced the closure of the Shenango Incorporated coke battery plant in response to a sharp downturn in the North American steel industry. The plant, which is part of the Power and Industrial Projects segment, is located in Pittsburgh, PA. As a result of the closure, DTE Energy recorded a one-time pre-tax non-cash impairment charge of $111 million. The charge included $96 million to fully impair the long-lived assets, employee severance expenses related to the workforce reduction of approximately 170 employees for $3 million, and other expenses, including write downs of inventory, of $12 million. The closure optimizes DTE Energy's coke production at its larger, more efficient facility. Production of coke from the Shenango battery ceased in January 2016. The plant closure will not significantly impact DTE Energy's earnings in future periods. As of December 31, 2015, no amounts have been paid to date under these exit activities. For amounts accrued at December 31, 2015 related to these exit activities, DTE Energy expects future cash payments of approximately $7 million to be made in 2016. DTE Energy anticipates incurring additional costs, including environmental remediation costs, in connection with the closure. An estimate of the amount of the additional costs and timing of the activities cannot be determined at December 31, 2015 as alternatives are currently being evaluated, however, the likelihood of these costs being material to DTE Energy's Consolidated Financial Statements is remote.

~~OUTLOOK~~GAS STORAGE AND PIPELINES

Description

Gas Storage and Pipelines owns natural gas storage fields, lateral and gathering pipeline systems, compression and surface facilities, and has ownership interests in interstate pipelines serving the Midwest, Ontario, and Northeast markets. The pipeline and storage assets are primarily supported by long-term, fixed-price revenue contracts.

Properties

Gas Storage and Pipelines holds the following properties:



Property Classification	% Owned	Description	Location
Pipelines
Appalachia Gathering System^(a)	100%	114-mile pipeline delivering Marcellus Shale gas to Texas Eastern Pipeline and Stonewall Gas Gathering system	PA and WV
Stonewall Gas Gathering^(a)	55%	68-mile pipeline connecting Appalachia Gathering System to Columbia Pipeline	WV
Bluestone Pipeline	100%	59-mile pipeline delivering Marcellus Shale gas to Millennium Pipeline and Tennessee Pipeline	PA and NY
Susquehanna gathering system	100%	Gathering system delivering Southwestern Energy's Marcellus Shale gas production to Bluestone Pipeline	PA
Vector Pipeline	40%	348-mile pipeline connecting Chicago, Michigan, and Ontario market centers	IL, IN, MI, and Ontario
Millennium Pipeline	26%	251-mile pipeline serving markets in the Northeast	NY
Michigan gathering systems	100%	Gathers production gas in northern Michigan	MI
Storage
Washington 10	100%	75 Bcf of storage capacity	MI
Washington 28	50%	16 Bcf of storage capacity	MI


(a)	In October 2016, DTE Energy closed on an acquisition of midstream natural gas assets that are part of the Gas Storage and Pipelines segment. See Note 4 to the Consolidated Financial Statements, "Acquisitions and Exit Activities," for additional information.

The ~~next few years will be a period~~assets of ~~rapid change~~these businesses are well integrated with other DTE Energy operations. Pursuant to an operating agreement, DTE Gas provides physical operations, maintenance, and technical support for ~~DTE Energy~~the Washington 10 and 28 storage facilities 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.~~Michigan gathering systems.

~~Looking forward,~~In addition, DTE Energy owns a 50% interest in the NEXUS Pipeline, a 255-mile pipeline to transport Utica and Marcellus shale gas to Ohio, Michigan, and Ontario market centers. A FERC application was filed in the fourth quarter of 2015 and was approved in August 2017. Construction has commenced with an anticipated third quarter 2018 in-service date.

In May 2017, DTE Energy filed a FERC application for approval of the Birdsboro Pipeline, a 14-mile lateral to serve a new power plant in Pennsylvania. DTE Energy is targeting a 2018 in-service date.

Regulation

Gas Storage and Pipelines operates natural gas storage facilities in Michigan as intrastate facilities regulated by the MPSC, and provides intrastate storage and related services pursuant to an MPSC-approved tariff. Gas Storage and Pipelines also provides interstate services in accordance with an Operating Statement on file with the FERC. Vector and Millennium Pipelines provide interstate transportation services in accordance with their FERC-approved tariffs. In addition, Vector is subject to applicable laws, rules and regulations in Canada. NEXUS Pipeline, when operational, will ~~focus on several areas~~also provide interstate transportation services in accordance with their FERC-approved tariffs. Gas Storage and Pipelines' gathering and pipeline assets are subject to the rules and regulations of the MPSC, Pennsylvania Public Utility Commission, the West Virginia Public Service Commission, and the New York Public Service Commission.

Strategy and Competition

Gas Storage and Pipelines expects to continue its steady growth plan by expanding existing assets, acquiring and/or developing new assets that are typically supported with long-term customer commitments. The focus will be on opportunities in the Midwest to Northeast region to supply natural gas to meet growing demand and displace less attractive supply from certain regions in North America. Much of the growth in demand for natural gas is expected to ~~improve future performance:~~occur in the eastern Canada and the northeast U.S. regions. Gas Storage and Pipelines believes that the Vector, Millennium, and NEXUS Pipelines are well positioned to provide access routes and low-cost expansion options to these markets due to growth in production from the Marcellus/Utica Shales in Pennsylvania and West Virginia. Gas Storage and Pipelines has agreements with key Marcellus shale producers that support its Bluestone Pipeline, Susquehanna gathering, AGS, and SGG businesses. Gas Storage and Pipelines is evaluating new pipeline and storage investment opportunities that could include additional pipeline and gathering expansions, laterals, compression, and other Marcellus/Utica shale midstream development or partnering opportunities.

Gas Storage and Pipelines has competition from other pipelines and storage providers. Operations are dependent upon a limited number of customers, and the loss of any one or a few customers could have a material adverse effect on the results of Gas Storage and Pipelines.

POWER AND INDUSTRIAL PROJECTS

Description

Industrial Energy Services

Steel and Petroleum Coke — Power and Industrial Projects produces metallurgical coke from a coke battery with a capacity of 1.0 million tons per year and has an investment in a second coke battery with a capacity of 1.2 million tons per year. Power and Industrial Projects also provides pulverized coal and petroleum coke to the steel, pulp and paper, and other industries.

Renewable Energy

Wholesale Power and Renewables — Power and Industrial Projects holds ownership interests in, and operates, five renewable generating plants with a capacity of 217 MWs. The electric output is sold under long-term power purchase agreements.

Landfill Gas Recovery — Power and Industrial Projects has ownership interests in, and operates, twenty-two landfill gas ~~customer satisfaction;~~recovery sites in eight different states. The sites recover methane from landfills and converts the gas to generate electricity, replace fossil fuels in industrial and manufacturing operations, or refine to pipeline-quality gas, which can then be used as vehicle fuel.

~~electric reliability;~~Reduced Emissions Fuel

~~rate competitiveness~~

Reduced Emissions Fuel — Power and ~~affordability;~~

~~regulatory stability~~Industrial Projects has constructed and ~~investment recovery for~~placed in service REF facilities at eleven sites including facilities located at eight third-party owned coal-fired power plants. DTE Energy has sold membership interests in four of the ~~electric~~facilities and ~~gas utilities;~~

~~growth~~entered into lease arrangements in three of ~~utility asset base;~~

~~employee engagement;~~

~~cost structure optimization across all business segments;~~

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

~~investments that integrate assets and leverage skills and expertise.~~

the facilities. DTE Energy will continue to optimize these facilities by seeking investors or entering into lease arrangements for facilities operating at DTE Electric and other utility sites. In addition, DTE Energy has entered into an agreement to operate an REF facility owned by an outside party located at a third-party owned coal-fired power plant. The facilities blend a proprietary additive with coal used in coal-fired power plants, resulting in reduced emissions of nitrogen oxide and mercury. Qualifying facilities are eligible to generate tax credits for ten years upon achieving certain criteria. The value of a tax credit is adjusted annually by an inflation factor published by the IRS. The value of the tax credit is reduced if the reference price of coal exceeds certain thresholds. The economic benefit of the REF facilities is dependent upon the generation of production tax credits.

Properties and Other

The following are significant properties operated by Power and Industrial Projects:



Business Areas	Location	Service Type
Industrial Energy Services
Steel and Petroleum Coke
Pulverized Coal Operations	MI	Pulverized Coal
Coke Production	MI	Metallurgical Coke Supply
Other Investment in Coke Production and Petroleum Coke	IN and MS	Metallurgical Coke Supply and Pulverized Petroleum Coke
On-Site Energy
Automotive	IN, MI, NY, and OH	Electric Distribution, Chilled Water, Waste Water, Steam, Cooling Tower Water, Reverse Osmosis Water, Compressed Air, Mist, and Dust Collectors
Airports	MI and PA	Electricity and Hot and Chilled Water
Chemical Manufacturing	KY and OH	Electricity, Steam, Natural Gas, Compressed Air, and Wastewater
Consumer Manufacturing	OH	Electricity, Steam, Wastewater, and Sewer
Business Park	PA	Electricity
Hospital and University	CA and IL	Electricity, Steam, and Chilled Water
Renewable Energy
Pulp and Paper	AL	Electric Generation and Steam
Renewables	CA and MN	Electric Generation
Landfill Gas Recovery	AZ, CA, MI, NC, NY, OH, TX, and UT	Electric Generation and Renewable Natural Gas
Reduced Emissions Fuel	MI, OH, OK, IL, PA, TX, and WI	REF Supply



	2017		2016		2015
	(In millions)
Production Tax Credits Generated (Allocated to DTE Energy)
REF	$	144	$	103	$	77
Renewables	6		8		11
Landfill Gas Recovery	3		3		3
	$	153	$	114	$	91

Regulation

Strategy and Competition

Power and Industrial Projects will continue leveraging its energy-related operating experience and project management capability to develop and grow its steel, on-site energy, and renewable energy businesses, and optimize the REF businesses. Power and Industrial Projects will also continue to pursue opportunities to ~~grow~~provide asset management and operations services to third parties. There are limited competitors for Power and Industrial Projects' existing disparate businesses who provide similar products and services. Power and Industrial Projects' operations are dependent upon a limited number of customers, and the loss of any one or a few customers could have a material adverse effect on the results of Power and Industrial Projects.

Power and Industrial Projects intends to focus on the following areas for growth:

Providing operating services to owners of on-site industrial power plants;

Acquiring and developing landfill gas recovery facilities, renewable energy projects, and other energy projects which may qualify for tax credits;

Obtaining investors in the REF projects.

ENERGY TRADING

Description

Energy Trading focuses on physical and financial power and 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's customer base is predominantly utilities, local distribution companies, pipelines, producers and generators, and other marketing and trading companies. Energy Trading enters into derivative financial instruments as part of its marketing and hedging activities. These financial instruments are generally accounted for under the MTM method, which results in the recognition in earnings of unrealized gains and losses from changes in the fair value of the derivatives. Energy Trading utilizes forwards, futures, swaps, and option contracts to mitigate risk associated with marketing and trading activity, as well as for proprietary trading within defined risk guidelines. Energy Trading also provides commodity risk management services to the other businesses within DTE Energy.

Regulation

Strategy and Competition

DTE Energy's strategy for the Energy Trading business is to deliver value-added services to DTE Energy customers. DTE Energy seeks to manage this business in a ~~disciplined~~ manner complementary to the growth of DTE Energy's other business segments. Energy Trading focuses on physical marketing and the optimization of its portfolio of energy assets. The segment competes with electric and gas marketers, financial institutions, traders, utilities, and other energy providers. The Energy Trading business is dependent upon the availability of capital and an investment grade credit rating. DTE Energy believes it has ample available capital capacity to support Energy Trading activities. DTE Energy monitors its use of capital closely to ensure that its commitments do not exceed capacity. A material credit restriction would negatively impact Energy Trading's financial performance. Competitors with greater access to capital, or at a lower cost, may have a competitive advantage. DTE Energy has risk management and credit processes to monitor and mitigate risk.

CORPORATE AND OTHER

Description

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

ENVIRONMENTAL MATTERS



	DTE Electric		DTE Gas		Non-utility		Total
	(In millions)
Water	$	35	$	—	$	—	$	35
Contaminated and other sites	5		35		—		40
Coal combustion residuals and effluent limitations guidelines	295		—		—		295
Estimated total future expenditures through 2024	$	335	$	35	$	—	$	370
Estimated 2018 expenditures	$	10	$	30	$	—	$	40
Estimated 2019 expenditures	$	65	$	—	$	—	$	65

EMPLOYEES

Item 1A. Risk Factors

Environmental laws and liability may be costly. The Registrants are subject to, and affected by, numerous environmental regulations. These regulations govern air emissions, water quality, wastewater discharge, and disposal of solid and hazardous waste. Compliance with these regulations can ~~secure opportunities~~significantly increase capital spending, operating expenses, and plant down times, and can negatively affect the affordability of the rates charged to customers.

Construction and capital improvements to the Registrants' power facilities, DTE Energy's distribution systems and its ~~strategic,~~Gas Storage and Pipelines business subject them to risk. The Registrants are managing ongoing, and planning future, significant construction and capital improvement projects at DTE Electric's multiple power generation and distribution facilities, at DTE Energy's gas distribution system, and at DTE Energy's Gas Storage and Pipelines business. Many factors that could cause delays or increased prices for these complex projects are beyond the Registrants' control, including the cost of materials and labor, subcontractor performance, timing and issuance of necessary permits or approvals (including required certificates from regulatory agencies), construction disputes, impediments to acquiring rights-of-way or land rights on a timely basis and on acceptable terms, cost overruns, and weather conditions. Failure to complete these projects on schedule and on budget for any reason could adversely affect the Registrants' financial performance, operations, or expected investment returns at the affected facilities, businesses and development projects.

DTE Energy's participation in energy trading markets subjects it to risk. Events in the energy trading industry have increased the level of scrutiny on the energy trading business and the energy industry as a whole. In certain situations, DTE Energy may be required to post collateral to support trading operations, which could be substantial. If access to liquidity to support trading activities is curtailed, DTE Energy could experience decreased earnings potential and cash flows. Energy trading activities take place in volatile markets and expose DTE Energy to risks related to commodity price movements, deviations in weather, and other related risks. DTE Energy's trading business routinely has speculative trading positions in the market, within strict policy guidelines DTE Energy sets, resulting from the management of DTE Energy's business portfolio. To the extent speculative trading positions exist, fluctuating commodity prices can improve or diminish DTE Energy's financial results and financial position. DTE Energy manages its exposure by establishing and enforcing strict risk limits and risk ~~criteria.~~management procedures. During periods of extreme volatility, these risk limits and risk management procedures may not work as planned and cannot eliminate all risks associated with these activities.

Item 1B. Unresolved Staff Comments

None.

Item 3. Legal Proceedings

Item 4. Mine Safety Disclosures

Not applicable.

~~RESULTS~~

Part II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters, and Issuer Purchases of Equity Securities



						Dividends Declared per Share
Year	Quarter	High		Low		Dividends Declared per Share
2017
	First	$	102.96	$	96.56	$	0.8250
	Second	$	111.35	$	100.97	$	0.8250
	Third	$	113.71	$	104.19	$	0.8250
	Fourth	$	116.74	$	106.21	$	0.8825
2016
	First	$	91.00	$	78.01	$	0.7300
	Second	$	99.13	$	84.77	$	0.7300
	Third	$	100.45	$	90.61	$	0.7700
	Fourth	$	99.92	$	89.66	$	0.8250

At December 31, 2017, there were 179,386,967 shares of DTE Energy common stock outstanding. These shares were held by a total of 53,437 shareholders of record.

DTE Electric paid cash dividends on common stock of $432 million in 2017, $420 million in 2016, and $395 million in 2015.

For information on DTE Energy dividend restrictions, see Note 16 to the Consolidated Financial Statements in Item 8 of this Report, "Short-Term Credit Arrangements and Borrowings."

See the following table for information as of December 31, 2017:



	Number of Securities to be Issued Upon Exercise of Outstanding Options	Weighted-Average Exercise Price of Outstanding Options		Number of Securities Remaining Available for Future Issuance Under Equity Compensation Plans
Plans approved by shareholders	105,994	$	42.95	1,437,769

UNREGISTERED SALES OF ~~OPERATIONS~~DTE ENERGY EQUITY SECURITIES AND USE OF PROCEEDS

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

The following ~~sections provide a detailed discussion~~table provides information about DTE Energy's purchases of equity securities that are registered by DTE Energy pursuant to Section 12 of the ~~operating performance and future outlook~~Exchange Act of ~~DTE Energy's segments. Segment information, described below, includes intercompany revenues and expenses, and other income and deductions that are eliminated in~~1934 for the ~~Consolidated Financial Statements.~~quarter ended December 31, 2017:

2015 2014 2013
(In millions)
Net Income (Loss) Attributable to DTE Energy by Segment:
Electric $ 542
$ 528
$ 484
Gas 132
140
143
Gas Storage and Pipelines 107
82
70
Power and Industrial Projects 16
90
66
Energy Trading (22 ) 122
(58 )
Corporate and Other (48 ) (57 ) (44 )
Net Income Attributable to DTE Energy Company $ 727
$ 905
$ 661



	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
10/01/2017 — 10/31/2017	3,269	$	99.19	—	—	—
11/01/2017 — 11/30/2017	—	$	—	—	—	—
12/01/2017 — 12/31/2017	1,300	$	89.46	—	—	—
Total	4,569			—


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

COMPARISON OF CUMULATIVE FIVE YEAR TOTAL RETURN

~~ELECTRIC~~Total Return to DTE Energy Shareholders

(Includes reinvestment of dividends)



	Annual Return Percentage Year Ended December 31,
Company/Index	2013	2014	2015		2016	2017
DTE Energy Company	14.89	34.61	(3.77	)	26.93	14.59
S&P 500 Index	32.39	13.69	1.38		11.95	21.82
S&P 500 Multi-Utilities Index	17.88	28.94	(1.73	)	18.56	12.09



	Indexed Returns Year Ended December 31,
	Base Period
Company/Index	2012	2013	2014	2015	2016	2017
DTE Energy Company	100	114.89	154.65	148.82	188.89	216.45
S&P 500 Index	100	132.39	150.51	152.59	170.83	208.11
S&P 500 Multi-Utilities Index	100	117.88	151.99	149.36	177.08	198.49

Item 6. Selected Financial Data

The following selected financial data of DTE Energy should be read in conjunction with the accompanying Management’s ~~Narrative~~Discussion and Analysis in Item 7 of ~~Results~~this Report and Combined Notes to Consolidated Financial Statements in Item 8 of ~~Operations discussion~~this Report. This information has been omitted for DTE Electric ~~is presented in a reduced disclosure format in accordance with~~per General Instruction I (2) (a) of Form 10-K for wholly-owned ~~subsidiaries.~~

~~The Electric segment consists principally of DTE Electric. Results for Electric segment with a reconciliation to DTE Electric are discussed below:~~subsidiaries (reduced disclosure format).

2015 2014 2013
(In millions)
Operating Revenues — Utility operations $ 4,901
$ 5,283
$ 5,199
Fuel and purchased power — utility 1,573
1,705
1,668
Gross Margin 3,328
3,578
3,531
Operation and maintenance 1,344
1,332
1,377
Depreciation and amortization 637
933
902
Taxes other than income 277
268
261
Asset (gains) losses and impairments, net —
(1 ) (3 )
Operating Income 1,070
1,046
994
Other (Income) and Deductions 238
222
258
Income Tax Expense 290
296
252
Segment Net Income Attributable to DTE Energy Company $ 542
$ 528
$ 484
Reconciliation of Segment Net Income Attributable to DTE Energy Company to DTE Electric Net Income 2
4
3
DTE Electric Net Income Attributable to DTE Energy Company $ 544
$ 532
$ 487

~~See DTE Electric's Consolidated Statements of Operations in Item 8 of this report for a complete view of its results.~~

~~Gross Margin~~ decreased $250 million in 2015 and increased $47 million in 2014. Revenues associated with certain mechanisms and surcharges are offset by related expenses elsewhere in the Registrants' Consolidated Statements of Operations.

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

2015 2014
(In millions)
Implementation of new rates $ 117
$ —
Base sales, inclusive of weather effect 24
(48 )
Renewable energy program 3
20
PSCR disallowance (19 ) —
Securitization bond and tax surcharge (376 ) (10 )
Amortization of refundable revenue decoupling/deferred gain —
63
Low-income energy assistance surcharge —
17
Regulatory mechanisms and other 1
5
Increase (decrease) in Electric segment Gross Margin $ (250 ) $ 47
Reconciliation of Electric segment Gross Margin to DTE Electric Gross Margin (1 ) —
Increase (decrease) in DTE Electric Gross Margin $ (251 ) $ 47

2015 2014 2013
(In thousands of MWh)
DTE Electric Sales
Residential 15,001
14,940
15,273
Commercial 17,192
16,792
16,661
Industrial 9,690
10,199
10,303
Other 291
517
942
42,174
42,448
43,179
Interconnection sales (a) 4,108
3,630
3,883
Total DTE Electric Sales 46,282
46,078
47,062

DTE Electric Deliveries

Retail and Wholesale 42,174
42,448
43,179
Electric retail access, including self generators (b) 4,899
5,033
5,200
Total DTE Electric Sales and Deliveries 47,073
47,481
48,379



	2017		2016		2015		2014		2013
	(In millions, except per share amounts)
Operating Revenues	$	12,607	$	10,630	$	10,337	$	12,301	$	9,661
Net Income Attributable to DTE Energy Company^(a)	$	1,134	$	868	$	727	$	905	$	661
Diluted Earnings Per Common Share	$	6.32	$	4.83	$	4.05	$	5.10	$	3.76
Financial Information
Dividends declared per share of common stock	$	3.36	$	3.06	$	2.84	$	2.69	$	2.59
Total Assets^(b)	$	33,767	$	32,041	$	28,662	$	27,827	$	25,864
Long-Term Debt^(b)(c)	$	12,185	$	11,269	$	8,760	$	8,271	$	7,143
Shareholders’ equity^(b)	$	9,512	$	9,011	$	8,772	$	8,327	$	7,921


(a)	~~Represents power that is not distributed by DTE Electric.~~The 2017 results include a $105 million net income tax benefit related to the enactment of the TCJA.

(b)

~~Represents deliveries~~In October 2016, DTE Energy closed on an acquisition of midstream natural gas assets that are part of the Gas Storage and Pipelines segment. See Note 4 to the Consolidated Financial Statements, "Acquisitions and Exit Activities," for ~~self generators that have purchased power from alternative energy suppliers to supplement their power requirements.~~additional information.


(c)	Long-Term Debt includes Capital lease obligations and excludes debt due within one year.

Item 7. 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 ~~residential~~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 with 2017 Operating Revenues of approximately $12.6 billion and ~~commercial~~Total Assets of approximately $33.8 billion. DTE Energy 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, ~~increased due primarily to favorable weather, while industrial sales decreased due primarily to lower steel customer load.~~distribution, and storage services throughout Michigan. DTE Energy operates three energy-related non-utility segments with operations throughout the United States.

~~Operation and maintenance expense~~ ~~increased $12 million in 2015 and decreased $45 million in 2014.~~ The following table summarizes DTE Energy's financial results:



	Years Ended December 31,
	2017		2016		2015
	(In millions, except per share amounts)
Net Income Attributable to DTE Energy Company	$	1,134	$	868	$	727
Diluted Earnings per Common Share	$	6.32	$	4.83	$	4.05

The increase in ~~2015~~2017 Net Income Attributable to DTE Energy Company is primarily due to ~~increased power plant generation expenses of $28 million, increased line clearance expenses of $25 million, increased distribution operations expenses of $13 million,~~higher earnings in the Gas Storage and ~~$18~~Pipelines, Energy Trading, and Power and Industrial Projects segments, partially offset by lower earnings in the Corporate and Other segment. The 2017 increase is also due to $105 million of ~~expenses~~net income tax benefit related to the ~~transition~~enactment of ~~PLD customers~~the TCJA. The increase in 2016 Net Income Attributable to DTE ~~Electric's distribution system effective July 1, 2014, partially offset by decreased storm restoration expenses of $63 million and decreased employee benefits of $7 million. The decrease in 2014~~Energy Company is primarily due to ~~decreased employee benefit expenses of $68 million, decreased distribution operations expenses of $36 million, and decreased power plant generation expenses of $7 million, partially offset by~~ higher storm restoration expenses of $19 million, increased low-income energy assistance of $17 million, $17 million of expenses related to the transition of PLD customers to DTE Electric's distribution system, and increased energy optimization and renewable energy expenses of $13 million. The MPSC approved a TRM that provides for recovery of the deferred net incremental revenue requirement associated with the transition of former PLD customers that is reflectedearnings in the ~~Depreciation~~Electric and ~~amortization line~~Power and Industrial Projects segments.

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

DTE ~~Electric's Consolidated Statements of Operations.~~

~~Depreciation and amortizationexpense~~ decreased $296 million in 2015 and increased $31 million in 2014. The 2015 decrease was due to $342 million of decreased amortization of regulatory assets related to Securitization and $15 million associated with the TRM, partially offset by $61 million of increased expenses due to an increased depreciable base. The 2014 increase was due to $42 million of increased expense due to an increased depreciable base and increased amortization of regulatory assets of $3 million, primarily related to Securitization, partially offset by $14 million associated with the TRM.

~~Other (Income) and Deductions~~ increased $16 million in 2015 and decreased $36 million in 2014. The increase in 2015 was primarily due to lower investment earnings of $11 million and higher interest expense of $8 million. The decrease in 2014 was primarily due to decreased interest expenses of $18 million and the 2013 contribution to the DTE Energy Foundation of $18 million.

~~Outlook~~— ~~DTE Electric will continue to move forward in its efforts~~Energy's strategy is to achieve ~~operational excellence, sustained~~long-term earnings growth, a strong ~~cash flows,~~balance sheet, and ~~earn its authorized return on equity.~~ an attractive dividend yield.

DTE ~~Electric~~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. ~~Looking forward, additional factors may impact earnings such as weather, the outcome of regulatory proceedings, benefit plan design changes, investment returns~~DTE Energy is focused on executing plans to achieve operational excellence and changes in discount rate assumptions in benefit plans and health care costs, uncertainty of legislative or regulatory actions regarding climate change and electric retail access, and effects of energy efficiency programs. DTE Electric residential and commercial sales have increased due primarily to improved economic activity and have been substantially offset by energy efficiency measures taken by customers. DTE Electric expects to continue its efforts to improve productivity and decrease costs while improving customer satisfaction with ~~consideration~~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 efficiency, 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 ~~customer rate affordability.~~its aging coal-fired plants. Refer to the "Capital Investments" section below for further discussion.

31A 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 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. In September 2016, DTE Electric received an order from the MPSC in its amended Renewable Energy Plan approving two 150 megawatt wind projects expected to be constructed and in service between 2018 and 2020, and 25 megawatts of company-owned solar projects which will be constructed and in service between 2019 and 2020. DTE Electric constructed and placed in service 50 megawatts of solar generation in 2017. DTE Electric plans to build a natural gas fueled combined cycle generation facility to provide approximately 1,100 megawatts of energy beginning in 2022. In the third quarter of 2017, DTE Electric filed a ~~rate case~~CON with the MPSC ~~on February 1, 2016 requesting an increase in base rates~~seeking approval for the planned build of ~~$344 million based on a projected twelve-month period ending July~~this natural gas plant. On January 31, 2017. The requested increase in base rates is due primarily to an increase in net plant resulting from infrastructure investments, environmental compliance, and reliability improvement projects. The rate filing also includes projected changes in sales, operation2018, DTE Electric filed its five-year distribution operations investment and maintenance ~~expenses, and working capital. The rate filing also requests an increase in return on equity from 10.3%~~plan to ~~10.5% on a capital structure of 50% equity and 50% debt.~~improve system reliability with the MPSC. DTE Electric ~~anticipates self-implementing a~~plans to seek regulatory approval for capital expenditures consistent with prior ratemaking treatment.

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 ~~increase~~case filings for base infrastructure capital expenditures consistent with prior ratemaking treatment.

ENVIRONMENTAL MATTERS

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 NO_x, SO₂, mercury and other emissions. Additional rulemakings are expected over the next few years which could require additional controls for SO₂, NO_x, and other hazardous air pollutants. To comply with ~~an MPSC order expected by February~~existing requirements, DTE Electric spent approximately $2.4 billion through 2017.

~~GAS~~ DTE Electric does not anticipate additional capital expenditures through 2024.

The ~~Gas segment consists principally~~EPA has implemented regulatory actions under the Clean Air Act to address emissions of GHGs from the utility sector and other sectors of the economy. Among these actions, the EPA finalized performance standards for emissions of carbon dioxide from new and existing EGUs. The carbon standards for new sources are not expected to have a material impact on DTE ~~Gas. Gas results are discussed below:~~Electric since DTE Electric has no plans to build new coal-fired generation, and any potential new gas generation will be able to comply with the applicable standards. In February 2016, the U.S. Supreme Court granted petitioners' requests for a stay of the carbon rules for existing EGUs (also known as the EPA Clean Power Plan) pending final review by the courts. The Clean Power Plan has no legal effect while the stay is in place. On March 28, 2017, a presidential executive order was issued on "Promoting Energy Independence and Economic Growth." The order instructs the EPA to review, and if appropriate, suspend, revise or rescind the Clean Power Plan rule. Additionally, federal agencies have been directed to conduct a review of all existing regulations that potentially burden the development and use of domestically produced energy resources. Following the issuance of this order, the federal government requested the U.S. Court of Appeals for the D.C. Circuit to hold all legal challenges in abeyance until the review of these regulations is completed. 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.

2015 2014 2013
(In millions)
Operating Revenues — Utility operations $ 1,376
$ 1,636
$ 1,474
Cost of gas — utility 526
725
624
Gross Margin 850
911
850
Operation and maintenance 430
456
429
Depreciation and amortization 104
99
95
Taxes other than income 62
61
56
Operating Income 254
295
270
Other (Income) and Deductions 50
77
50
Income Tax Expense 72
78
77
Net Income Attributable to DTE Energy Company $ 132
$ 140
$ 143

~~Gross Margin~~ ~~decreased $61 million in 2015~~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 ~~$61 million in 2014. Revenues associated with certain mechanisms~~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 ~~surcharges are offset by related expenses elsewhere in~~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 ~~Consolidated Statements~~utility and non-utility segments. At the present time, it is not possible to quantify the financial impacts of ~~Operations.~~these climate related regulatory initiatives on the Registrants or their customers.

~~The following table details changes in various gross margin components relative~~See Items 1. and 2. Business and Properties and Note 18 to the ~~comparable prior period:~~

2015 2014
(In millions)
Weather $ (64 ) $ 31
Infrastructure recovery mechanism 12
7
Home protection program 4
7
Revenue decoupling mechanism 7
(3 )
Midstream storage and transportation revenues (10 ) 6
Other (10 ) 13
Increase (decrease) in Gross Margin $ (61 ) $ 61

2015 2014 2013
Gas Markets (in Bcf)
Gas sales 122
138
128
End-user transportation 169
167
157
291
305
285
Intermediate transportation 289
305
300
Total Gas sales 580
610
585

~~Operation~~Consolidated Financial Statements in Item 8 of this Report, "Commitments and ~~maintenanceexpense~~ ~~decreased $26 million in 2015 and increased $27 million in 2014. The decrease in 2015 is primarily due to decreased gas operations expenses~~Contingencies," for further discussion of $12 million, decreased employee benefits expenses of $10 million, decreased transmission expenses of $3 million, and decreased uncollectible expenses of $3 million. The increase in 2014 is primarily due to increased gas operations expenses of $32 million, increased uncollectible expenses of $4 million, and increased corporate administrative expenses of $3 million, partially offset by decreased employee benefit expenses of $10 million and reduced energy optimization expenses of $2 million.Environmental Matters.

~~Other (Income) and Deductions~~ decreased $27 million in 2015 and increased $27 million in 2014. The decrease in 2015 is primarily due to the 2014 contribution to the DTE Energy Foundation and other charitable organizations. The increase in 2014 is primarily due to contributions to the DTE Energy Foundation and other charitable organizations in 2014.

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

DTE Gas filed a rate case with the MPSC on December 18, 2015 requesting an increase in base rates of $183 million based on a projected twelve-month period ending October 31, 2017. The requested increase in base rates is due primarily to an increase in net plant of $800 million, inclusive of IRM capital investments being recovered through approved IRM surcharge filings. The rate filing also includes projected changes in sales, operation and maintenance expenses, and working capital. The rate filing also requests an increase in return on equity from 10.5% to 10.75% on a capital structure of 52% equity and 48% debt. DTE Gas anticipates self-implementing a rate increase in November 2016 with an MPSC order expected by December 2016. Concurrent with the MPSC order in this rate case, the existing IRM surcharge will be terminated. However, in this rate case filing, DTE Gas requested to implement a new IRM surcharge to become effective in January 2017.

GAS STORAGE AND PIPELINES

~~The~~ Description

Gas Storage and Pipelines ~~segment consists of~~owns natural gas storage fields, lateral and gathering pipeline systems, compression and surface facilities, and has ownership interests in interstate pipelines serving the ~~non-utility gas pipelines~~Midwest, Ontario, and Northeast markets. The pipeline and storage ~~businesses.~~ assets are primarily supported by long-term, fixed-price revenue contracts.

Properties

Gas Storage and Pipelines ~~results are discussed below:~~holds the following properties:

2015 2014 2013
(In millions)
Operating Revenues — Non-utility operations $ 243
$ 203
$ 132
Operation and maintenance 58
46
25
Depreciation and amortization 30
34
23
Taxes other than income 5
4
3
Asset (gains) losses and impairments, net —
1
—
Operating Income 150
118
81
Other (Income) and Deductions (29 ) (19 ) (36 )
Income Tax Expense 70
53
45
Net Income 109
84
72
Net Income Attributable to Noncontrolling Interests 2
2
2
Net Income Attributable to DTE Energy Company $ 107
$ 82
$ 70



Property Classification	% Owned	Description	Location
Pipelines
Appalachia Gathering System^(a)	100%	114-mile pipeline delivering Marcellus Shale gas to Texas Eastern Pipeline and Stonewall Gas Gathering system	PA and WV
Stonewall Gas Gathering^(a)	55%	68-mile pipeline connecting Appalachia Gathering System to Columbia Pipeline	WV
Bluestone Pipeline	100%	59-mile pipeline delivering Marcellus Shale gas to Millennium Pipeline and Tennessee Pipeline	PA and NY
Susquehanna gathering system	100%	Gathering system delivering Southwestern Energy's Marcellus Shale gas production to Bluestone Pipeline	PA
Vector Pipeline	40%	348-mile pipeline connecting Chicago, Michigan, and Ontario market centers	IL, IN, MI, and Ontario
Millennium Pipeline	26%	251-mile pipeline serving markets in the Northeast	NY
Michigan gathering systems	100%	Gathers production gas in northern Michigan	MI
Storage
Washington 10	100%	75 Bcf of storage capacity	MI
Washington 28	50%	16 Bcf of storage capacity	MI


(a)	In October 2016, DTE Energy closed on an acquisition of midstream natural gas assets that are part of the Gas Storage and Pipelines segment. See Note 4 to the Consolidated Financial Statements, "Acquisitions and Exit Activities," for additional information.

~~Operating Revenues — Non-utility operations~~ ~~increased $40 million in 2015 and increased $71 million in 2014.~~ The 2015 increase is due primarily to increased volumes on the Bluestone Pipeline and Susquehanna gathering systems, partially offset by decreased gas storage revenues due to expiring contracts being replacedassets of these businesses are well integrated with contracts at lower rates. The 2014 increase is due primarily to increased volumes on the Bluestone Pipeline and additional segments placed in service in the Susquehanna gathering system. Storage revenue also increased due to weather favorability in early 2014, partially offset by lower market rates.

~~Operation and maintenance expense~~ increased $12 million in 2015 and increased $21 million in 2014. The 2015 increase is due primarily to increased activity on the Bluestone and Susquehanna projects and increased gas storage operations expense. The 2014 increase is due primarily to increased activity on the Bluestone and Susquehanna projects and increased corporate overheads due to growth of this segment.

~~Depreciation and amortizationexpense~~ decreased $4 million in 2015 and increased $11 million in 2014. The 2015 decrease is due primarily to a change in the estimated useful life of Susquehanna gathering assets related to a contract extension in the fourth quarter of 2014, partially offset by additional Bluestone and Susquehanna projects placed in service. The 2014 increase is due primarily to the growth of the Bluestone and Susquehanna projects.

~~Other (Income) and Deductions~~ increased $10 million in 2015 and decreased $17 million in 2014. The 2015 increase is due primarily to increased earnings from pipeline investments. The 2014 decrease is due primarily to decreased earnings from a pipeline investment and increased intercompany interest expense. The earnings from the pipeline investment were negatively impacted in 2014 by a revenue deferral for depreciation collected in FERC-approved tariff rates in excess of depreciation expense.

~~Outlook —~~ Gas Storage and Pipelines expects to maintain its steady growth by developing an asset portfolio with multiple growth platforms through investment in new projects and expansions. Gas Storage and Pipelines will continue to look for additional investment opportunities and other storage and pipeline projects at favorable prices. The 2015 capacity expansion of Bluestone Pipeline in Susquehanna County, Pennsylvania and Broome County, New York, is complete and included a second compressor facility and approximately six miles of additional pipeline loop to accommodate increased shipper demand. Planning and design activities are underway for Bluestone Pipeline's 2016 expansion. Additionally, the Susquehanna gathering system is being expanded to accommodate increased production. Despite recent pressure on producers from low commodity prices, DTE Energy ~~believes its long-term~~operations. Pursuant to an operating agreement, ~~with Southwestern~~DTE Gas provides physical operations, maintenance, and technical support for the Washington 10 and 28 storage facilities and for the Michigan gathering systems.

In addition, DTE Energy ~~Production Company and the quality of the natural gas reserves~~owns a 50% interest 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~~255-mile pipeline 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.~~Ontario market centers. A FERC application was filed in the fourth quarter of 2015 and was approved in August 2017. Construction has commenced with an ~~estimated~~anticipated third quarter 2018 in-service date.

In May 2017, DTE Energy filed a FERC application for approval of the Birdsboro Pipeline, a 14-mile lateral to serve a new power plant in ~~service date~~Pennsylvania. DTE Energy is targeting a 2018 in-service date.

Regulation

Gas Storage and Pipelines operates natural gas storage facilities in Michigan as intrastate facilities regulated by the MPSC, and provides intrastate storage and related services pursuant to an MPSC-approved tariff. Gas Storage and Pipelines also provides interstate services in accordance with an Operating Statement on file with the FERC. Vector and Millennium Pipelines provide interstate transportation services in accordance with their FERC-approved tariffs. In addition, Vector is subject to applicable laws, rules and regulations in Canada. NEXUS Pipeline, when operational, will also provide interstate transportation services in accordance with their FERC-approved tariffs. Gas Storage and Pipelines' gathering and pipeline assets are subject to the rules and regulations of the MPSC, Pennsylvania Public Utility Commission, the West Virginia Public Service Commission, and the New York Public Service Commission.

Strategy and Competition

Gas Storage and Pipelines expects to continue its steady growth plan by expanding existing assets, acquiring and/or developing new assets that are typically supported with long-term customer commitments. The focus will be on opportunities in the ~~fourth quarter~~Midwest to Northeast region to supply natural gas to meet growing demand and displace less attractive supply from certain regions in North America. Much of ~~2017.~~the growth in demand for natural gas is expected to occur in the eastern Canada and the northeast U.S. regions. Gas Storage and Pipelines believes that the Vector, Millennium, and NEXUS Pipelines are well positioned to provide access routes and low-cost expansion options to these markets due to growth in production from the Marcellus/Utica Shales in Pennsylvania and West Virginia. Gas Storage and Pipelines has agreements with key Marcellus shale producers that support its Bluestone Pipeline, Susquehanna gathering, AGS, and SGG businesses. Gas Storage and Pipelines is evaluating new pipeline and storage investment opportunities that could include additional pipeline and gathering expansions, laterals, compression, and other Marcellus/Utica shale midstream development or partnering opportunities.

POWER AND INDUSTRIAL PROJECTS

~~The~~ Description

Power and Industrial Projects ~~segment~~ is comprised primarily of projects that deliver energy and utility-type products and services to industrial, commercial, and institutional customers, produce reduced emissions fuel, and sell electricity from renewable energy projects. This business segment provides services using project assets usually located on or near the customers' premises in the steel, automotive, pulp and paper, airport, chemical, and other industries as follows:

Industrial Energy Services

Steel and Petroleum Coke — Power and Industrial Projects ~~results are discussed below:~~

2015 2014 2013
(In millions)
Operating Revenues — Non-utility operations $ 2,224
$ 2,289
$ 1,950
Fuel, purchased power, and gas — non-utility 1,837
1,913
1,571
Gross Margin 387
376
379
Operation and maintenance 379
368
343
Depreciation and amortization 78
77
72
Taxes other than income 15
15
15
Asset (gains) losses and impairments, net 106
(12 ) (4 )
Operating Loss (191 ) (72 ) (47 )
Other (Income) and Deductions (58 ) (66 ) (73 )
Income Taxes
Expense (Benefits) (49 ) (3 ) 8
Production Tax Credits (91 ) (97 ) (53 )
(140 ) (100 ) (45 )
Net Income 7
94
71
Net Income (Loss) Attributable to Noncontrolling Interests (9 ) 4
5
Net Income Attributable to DTE Energy Company $ 16
$ 90
$ 66

~~Gross Margin~~ ~~increased $11 million in 2015 and decreased $3 million in 2014. The 2015 increase is primarily due to an $8 million increase in production at~~produces metallurgical coke from a ~~renewable power project, a $6 million increase in pricing at two landfill gas projects, a $6 million increase associated~~coke battery with a ~~newly constructed~~capacity of 1.0 million tons per year and has an investment in a second coke battery with a capacity of 1.2 million tons per year. Power and Industrial Projects also provides pulverized coal and petroleum coke to the steel, pulp and paper, and other industries.

On-Site Energy — Power and Industrial Projects provides power generation, steam production, chilled water production, wastewater treatment, and compressed air supply to industrial customers. Power and Industrial Projects also provides utility-type services using project assets usually located on or near the customers' premises in the ~~on-site business,~~automotive, airport, chemical, and a $5 million increase in production in the REF business, partially offset by a $13 million decrease in product sales at the steel projects. The 2014 decrease is primarily due to a $13 million decrease in sales associated with project terminations in the on-site energy business, $12 million of higher start-up costs associated with new projects in the REF business, a $3 million decrease in lower pricing in the steel business, partially offset by a $19 million increase associated with new renewable powerother industries.

Renewable Energy

Wholesale Power and ~~landfill gas projects,~~Renewables — Power and ~~a $6 million increase due to the closing of the coal transportation business.~~

~~Operation and maintenanceexpense~~ increased $11 million in 2015 and increased $25 million in 2014. The 2015 increase is primarily due to costs associated with closure of the Shenango coke battery. The 2014 increase is primarily due to $16 million of higher maintenance and general administrative expenses in the steel business and $9 million of higher spending associated with the start-up of a renewable power project.

~~Depreciation and amortization expense~~ ~~increased by $1 million in 2015 and increased by $5 million in 2014. The 2014 increase is primarily due to $4 million associated with the start-up of a renewable power project.~~

~~Asset (gains) losses and impairments, net~~ decreased by $118 million in 2015 and increased by $8 million in 2014. The 2015 decrease is due primarily to the closure of the Shenango coke battery and a renewable power project. The 2014 increase is due primarily to a gain associated with a sale of an on-site project in 2014 and an asset impairment recorded in 2013.

~~Other (Income) and Deductions~~ decreased by $8 million in 2015 and decreased $7 million in 2014. The 2015 decrease is due primarily to charitable contributions, and the 2014 decrease is due primarily to lower equity earnings at various projects.

~~Income Taxes - Expense (Benefits)~~ ~~decreased by $46 million in 2015. The decrease is primarily due to the impact of the closure of the Shenango coke battery and a renewable power project.~~

~~Income Taxes - Production Tax Credits~~ ~~decreased by $6 million in 2015 and increased $44 million in 2014. The 2015 decrease is primarily due to the reduction of~~Industrial Projects holds ownership interests in, and operates, five renewable generating plants with a capacity of 217 MWs. The electric output is sold under long-term power purchase agreements.

Landfill Gas Recovery — Power and Industrial Projects has ownership interests in, and operates, twenty-two landfill gas recovery sites in eight different states. The sites recover methane from landfills and converts the ~~REF projects. The 2014 increase is due primarily~~gas to ~~higher production volumes of refined coal that resulted~~generate electricity, replace fossil fuels in ~~higher tax credits at REF projects.~~industrial and manufacturing operations, or refine to pipeline-quality gas, which can then be used as vehicle fuel.

Reduced Emissions Fuel

~~Net Income (Loss) Attributable to Noncontrolling Interests~~ decreased by $13 million in 2015 and decreased by $1 million in 2014. The 2015 loss allocated to noncontrolling interests is primarily due to lease arrangements with investors at various REF facilities.

~~Outlook~~Reduced Emissions Fuel — Power and Industrial Projects has constructed and placed in service REF facilities at ~~nine~~eleven sites including facilities located at ~~six~~eight third-party owned coal-fired power plants. DTE Energy has sold membership interests in four of the facilities and entered into lease arrangements in ~~two~~three of the facilities. DTE Energy will continue to optimize these facilities by seeking investors or entering into lease arrangements for facilities operating at DTE Electric and other utility sites. ~~DTE Energy is in the process of relocating underutilized facility equipment at an existing site to a new third-party owned coal-fired power plant.~~ In addition, DTE Energy has entered into an agreement to operate an REF facility owned by an outside party located at a third-party owned coal-fired power plant. The facilities blend a proprietary additive with coal used in coal-fired power plants, resulting in reduced emissions of nitrogen oxide and mercury. Qualifying facilities are eligible to generate tax credits for ten years upon achieving certain criteria. The value of a tax credit is adjusted annually by an inflation factor published by the IRS. The value of the tax credit is reduced if the reference price of coal exceeds certain thresholds. The economic benefit of the REF facilities is dependent upon the generation of production tax credits.

~~DTE Energy expects decreased production levels~~

Properties and Other

The following are significant properties operated by Power and Industrial Projects:



Business Areas	Location	Service Type
Industrial Energy Services
Steel and Petroleum Coke
Pulverized Coal Operations	MI	Pulverized Coal
Coke Production	MI	Metallurgical Coke Supply
Other Investment in Coke Production and Petroleum Coke	IN and MS	Metallurgical Coke Supply and Pulverized Petroleum Coke
On-Site Energy
Automotive	IN, MI, NY, and OH	Electric Distribution, Chilled Water, Waste Water, Steam, Cooling Tower Water, Reverse Osmosis Water, Compressed Air, Mist, and Dust Collectors
Airports	MI and PA	Electricity and Hot and Chilled Water
Chemical Manufacturing	KY and OH	Electricity, Steam, Natural Gas, Compressed Air, and Wastewater
Consumer Manufacturing	OH	Electricity, Steam, Wastewater, and Sewer
Business Park	PA	Electricity
Hospital and University	CA and IL	Electricity, Steam, and Chilled Water
Renewable Energy
Pulp and Paper	AL	Electric Generation and Steam
Renewables	CA and MN	Electric Generation
Landfill Gas Recovery	AZ, CA, MI, NC, NY, OH, TX, and UT	Electric Generation and Renewable Natural Gas
Reduced Emissions Fuel	MI, OH, OK, IL, PA, TX, and WI	REF Supply



	2017		2016		2015
	(In millions)
Production Tax Credits Generated (Allocated to DTE Energy)
REF	$	144	$	103	$	77
Renewables	6		8		11
Landfill Gas Recovery	3		3		3
	$	153	$	114	$	91

Regulation

Certain electric generating facilities within Power and Industrial Projects have market-based rate authority from the FERC to sell power. The facilities are subject to FERC reporting requirements and market behavior rules. Certain projects of ~~metallurgical coke~~Power and ~~pulverized coal supplied~~Industrial Projects are also subject to ~~steel industry customers for 2016. A recent downturn in~~ the ~~steel industry in the United States will likely negatively impact the volume~~applicable laws, rules, and ~~pricing of metallurgical coke sales for the upcoming year. See discussion of potential impairment risk~~regulations related to ~~long-lived steel related assets in~~ the ~~Critical Accounting Estimates section. The segment has four renewable power generation facilities in operation. On-site energy services will continue to be delivered in accordance with the terms~~EPA, U.S. Department of ~~long-term contracts. DTE Energy will continue to look for additional investment opportunities~~Homeland Security, DOE, and ~~other energy projects at favorable prices.~~various state utility commissions.

Strategy and Competition

Power and Industrial Projects will continue ~~to leverage~~leveraging its ~~extensive~~ energy-related operating experience and project management capability to develop ~~additional~~and grow its steel, on-site energy, and renewable energy businesses, and optimize the REF businesses. Power and Industrial Projects will also continue to pursue opportunities to provide asset management and operations services to third parties. There are limited competitors for Power and Industrial Projects' existing disparate businesses who provide similar products and services. Power and Industrial Projects' operations are dependent upon a limited number of customers, and the loss of any one or a few customers could have a material adverse effect on the results of Power and Industrial Projects.

Power and Industrial Projects intends to focus on the following areas for growth:

Providing operating services to owners of on-site industrial power plants;

Acquiring and developing landfill gas recovery facilities, renewable energy projects, ~~to serve~~and other energy ~~intensive industrial customers.~~projects which may qualify for tax credits;

35Obtaining investors in the REF projects.

ENERGY TRADING

Description

Energy Trading focuses on physical and financial power and 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's customer base is predominantly utilities, local distribution companies, pipelines, producers and generators, and other marketing and trading companies. Energy Trading enters into derivative financial instruments as part of its marketing and hedging activities. These financial instruments are generally accounted for under the MTM method, which results in the recognition in earnings of unrealized gains and losses from changes in the fair value of the derivatives. Energy Trading utilizes forwards, futures, swaps, and option contracts to mitigate risk associated with marketing and trading activity, as well as for proprietary trading within defined risk guidelines. Energy Trading also provides commodity risk management services to the other businesses within DTE Energy.

Regulation

Strategy and Competition

CORPORATE AND OTHER

Description

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

ENVIRONMENTAL MATTERS



	DTE Electric		DTE Gas		Non-utility		Total
	(In millions)
Water	$	35	$	—	$	—	$	35
Contaminated and other sites	5		35		—		40
Coal combustion residuals and effluent limitations guidelines	295		—		—		295
Estimated total future expenditures through 2024	$	335	$	35	$	—	$	370
Estimated 2018 expenditures	$	10	$	30	$	—	$	40
Estimated 2019 expenditures	$	65	$	—	$	—	$	65

EMPLOYEES

Item 1A. Risk Factors

Item 1B. Unresolved Staff Comments

None.

Item 3. Legal Proceedings

Item 4. Mine Safety Disclosures

Not applicable.

Part II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters, and Issuer Purchases of Equity Securities



						Dividends Declared per Share
Year	Quarter	High		Low		Dividends Declared per Share
2017
	First	$	102.96	$	96.56	$	0.8250
	Second	$	111.35	$	100.97	$	0.8250
	Third	$	113.71	$	104.19	$	0.8250
	Fourth	$	116.74	$	106.21	$	0.8825
2016
	First	$	91.00	$	78.01	$	0.7300
	Second	$	99.13	$	84.77	$	0.7300
	Third	$	100.45	$	90.61	$	0.7700
	Fourth	$	99.92	$	89.66	$	0.8250

At December 31, 2017, there were 179,386,967 shares of DTE Energy common stock outstanding. These shares were held by a total of 53,437 shareholders of record.

DTE Electric paid cash dividends on common stock of $432 million in 2017, $420 million in 2016, and $395 million in 2015.

For information on DTE Energy dividend restrictions, see Note 16 to the Consolidated Financial Statements in Item 8 of this Report, "Short-Term Credit Arrangements and Borrowings."

See the following table for information as of December 31, 2017:



	Number of Securities to be Issued Upon Exercise of Outstanding Options	Weighted-Average Exercise Price of Outstanding Options		Number of Securities Remaining Available for Future Issuance Under Equity Compensation Plans
Plans approved by shareholders	105,994	$	42.95	1,437,769

UNREGISTERED SALES OF DTE ENERGY EQUITY SECURITIES AND USE OF PROCEEDS

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



	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
10/01/2017 — 10/31/2017	3,269	$	99.19	—	—	—
11/01/2017 — 11/30/2017	—	$	—	—	—	—
12/01/2017 — 12/31/2017	1,300	$	89.46	—	—	—
Total	4,569			—


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

COMPARISON OF CUMULATIVE FIVE YEAR TOTAL RETURN

Total Return to DTE Energy Shareholders

(Includes reinvestment of dividends)



	Annual Return Percentage Year Ended December 31,
Company/Index	2013	2014	2015		2016	2017
DTE Energy Company	14.89	34.61	(3.77	)	26.93	14.59
S&P 500 Index	32.39	13.69	1.38		11.95	21.82
S&P 500 Multi-Utilities Index	17.88	28.94	(1.73	)	18.56	12.09



	Indexed Returns Year Ended December 31,
	Base Period
Company/Index	2012	2013	2014	2015	2016	2017
DTE Energy Company	100	114.89	154.65	148.82	188.89	216.45
S&P 500 Index	100	132.39	150.51	152.59	170.83	208.11
S&P 500 Multi-Utilities Index	100	117.88	151.99	149.36	177.08	198.49

Item 6. Selected Financial Data



	2017		2016		2015		2014		2013
	(In millions, except per share amounts)
Operating Revenues	$	12,607	$	10,630	$	10,337	$	12,301	$	9,661
Net Income Attributable to DTE Energy Company^(a)	$	1,134	$	868	$	727	$	905	$	661
Diluted Earnings Per Common Share	$	6.32	$	4.83	$	4.05	$	5.10	$	3.76
Financial Information
Dividends declared per share of common stock	$	3.36	$	3.06	$	2.84	$	2.69	$	2.59
Total Assets^(b)	$	33,767	$	32,041	$	28,662	$	27,827	$	25,864
Long-Term Debt^(b)(c)	$	12,185	$	11,269	$	8,760	$	8,271	$	7,143
Shareholders’ equity^(b)	$	9,512	$	9,011	$	8,772	$	8,327	$	7,921


(a)	The 2017 results include a $105 million net income tax benefit related to the enactment of the TCJA.


(b)	In October 2016, DTE Energy closed on an acquisition of midstream natural gas assets that are part of the Gas Storage and Pipelines segment. See Note 4 to the Consolidated Financial Statements, "Acquisitions and Exit Activities," for additional information.


(c)	Long-Term Debt includes Capital lease obligations and excludes debt due within one year.

Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

EXECUTIVE OVERVIEW

The following table summarizes DTE Energy's financial results:



	Years Ended December 31,
	2017		2016		2015
	(In millions, except per share amounts)
Net Income Attributable to DTE Energy Company	$	1,134	$	868	$	727
Diluted Earnings per Common Share	$	6.32	$	4.83	$	4.05

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.

CAPITAL INVESTMENTS

ENVIRONMENTAL MATTERS

OUTLOOK

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

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



	2017			2016			2015
	(In millions)
Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	606		$	622		$	542
Gas	146			138			132
Gas Storage and Pipelines	275			119			107
Power and Industrial Projects	138			95			16
Energy Trading	72			(45		)	(22		)
Corporate and Other	(103		)	(61		)	(48		)
Net Income Attributable to DTE Energy Company	$	1,134		$	868		$	727

ELECTRIC

The Results of Operations discussion for DTE Electric is presented in a reduced disclosure format in accordance with General Instruction I (2) (a) of Form 10-K for wholly-owned subsidiaries.

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



	2017		2016		2015
	(In millions)
Operating Revenues — Utility operations	$	5,102	$	5,225	$	4,901
Fuel and purchased power — utility	1,454		1,532		1,573
Utility Margin	3,648		3,693		3,328
Operation and maintenance	1,428		1,455		1,344
Depreciation and amortization	753		750		637
Taxes other than income	302		284		277
Operating Income	1,165		1,204		1,070
Other (Income) and Deductions	238		229		238
Income Tax Expense	321		353		290
Net Income Attributable to DTE Energy Company	$	606	$	622	$	542

See DTE Electric's Consolidated Statements of Operations in Item 8 of this Report for a complete view of its results.

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



	2017			2016
	(In millions)
Implementation of new rates	$	124		$	198
PSCR disallowance in 2017 and 2015, respectively	(13		)	19
Base sales	(26		)	20
Weather	(109		)	96
Securitization bond and tax surcharge	—			40
Renewable energy program	—			12
Amortization of refundable revenue decoupling/deferred gain in 2015	—			(63		)
Regulatory mechanisms and other	(21		)	43
Increase (decrease) in Utility Margin	$	(45	)	$	365



	2017	2016	2015
	(In thousands of MWh)
DTE Electric Sales
Residential	14,885	15,875	15,001
Commercial	17,283	17,521	17,192
Industrial	9,897	10,004	9,690
Other	258	264	291
	42,323	43,664	42,174
Interconnection sales^(a)	2,623	2,334	4,108
Total DTE Electric Sales	44,946	45,998	46,282

DTE Electric Deliveries
Retail and wholesale	42,323	43,664	42,174
Electric retail access, including self generators^(b)	4,820	4,936	4,899
Total DTE Electric Sales and Deliveries	47,143	48,600	47,073


(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.

DTE Electric sales decreased for residential, commercial, and industrial primarily due to favorable weather in 2016.

GAS

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



	2017		2016		2015
	(In millions)
Operating Revenues — Utility operations	$	1,388	$	1,324	$	1,376
Cost of gas — utility	443		454		526
Utility Margin	945		870		850
Operation and maintenance	451		411		430
Depreciation and amortization	123		106		104
Taxes other than income	65		64		62
Asset (gains) losses and impairments, net	—		4		—
Operating Income	306		285		254
Other (Income) and Deductions	82		70		50
Income Tax Expense	78		77		72
Net Income Attributable to DTE Energy Company	$	146	$	138	$	132

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



	2017			2016
	(In millions)
Implementation of new rates	$	80		$	23
Revenue decoupling mechanism	4			(7		)
Home protection program	3			4
Midstream storage and transportation revenues	(5		)	(2		)
Weather	(6		)	(22		)
Infrastructure recovery mechanism	—			12
Other	(1		)	12
Increase in Utility Margin	$	75		$	20



	2017	2016	2015
	(In Bcf)
Gas Markets
Gas sales	119	116	122
End-user transportation	165	182	169
	284	298	291
Intermediate transportation	260	214	289
Total Gas sales	544	512	580

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:



	2017			2016			2015
	(In millions)
Operating Revenues — Non-utility operations	$	453		$	302		$	243
Cost of gas — Non-utility	30			6			—
Operation and maintenance	83			81			58
Depreciation and amortization	76			45			30
Taxes other than income	8			4			5
Asset (gains) losses and impairments, net	2			—			—
Operating Income	254			166			150
Other (Income) and Deductions	(18		)	(31		)	(29		)
Income Tax Expense (Benefit)	(30		)	71			70
Net Income	302			126			109
Less: Net Income Attributable to Noncontrolling Interests	27			7			2
Net Income Attributable to DTE Energy Company	$	275		$	119		$	107

See Note 4 to the Consolidated Financial Statements in Item 8 of this Report, "Acquisitions and Exit Activities" for discussion of the acquisition of AGS and SGG in October 2016.

In May 2017, DTE Energy filed a FERC application for approval of the Birdsboro Pipeline, a 14-mile lateral to serve a new power plant in Pennsylvania. DTE Energy is targeting a 2018 in-service date.

POWER AND INDUSTRIAL PROJECTS



	2017			2016			2015
	(In millions)
Operating Revenues — Non-utility operations	$	2,089		$	1,906		$	2,224
Fuel, purchased power, and gas — non-utility	1,813			1,640			1,837
Non-utility Margin	276			266			387
Operation and maintenance	343			320			379
Depreciation and amortization	72			72			78
Taxes other than income	11			13			15
Asset (gains) losses and impairments, net	20			(1		)	106
Operating Loss	(170		)	(138		)	(191		)
Other (Income) and Deductions	(64		)	(52		)	(58		)
Income Taxes
Benefit	(42		)	(26		)	(49		)
Production Tax Credits	(153		)	(114		)	(91		)
	(195		)	(140		)	(140		)
Net Income	89			54			7
Less: Net Loss Attributable to Noncontrolling Interests	(49		)	(41		)	(9		)
Net Income Attributable to DTE Energy Company	$	138		$	95		$	16

Operating Revenues — Non-utility operations increased $183 million in 2017 and decreased $318 million in 2016. The changes are due to the following:



	2017
	(In millions)
Higher demand due to improved conditions in the steel business	$	107
Higher production driven by new projects, offset by lower coal prices in the REF business	102
Lower production and one-time recovery in 2016, offset by an acquisition in the renewables business	(9		)
Lower sales primarily associated with expired contracts in the on-site business	(17		)
	$	183

	2016
	(In millions)
Closure of the Shenango coke battery and lower demand in the steel business	$	(264	)
Termination of a lease agreement in the REF business	(40		)
Contract termination at a renewable power project facility, offset by a one-time revenue recovery	(9		)
Other	(5		)
	$	(318	)

Non-utility Margin increased $10 million in 2017 and decreased $121 million in 2016. The changes are due to the following:



	2017
	(In millions)
Higher demand due to improved conditions in the steel business	$	42
Lower production and one-time recovery in 2016 in the renewables business	(11		)
Lower sales primarily associated with expired contracts in the on-site business	(15		)
Other	(6		)
	$	10

	2016
	(In millions)
Closure of the Shenango coke battery and lower demand in the steel business	$	(114	)
Termination of a lease agreement in the REF business	(12		)
Lower fuel costs in a renewable power project business	5
	$	(121	)

Income Taxes — Production Tax Credits increased by $39 million in 2017 and increased $23 million in 2016. The increase in both periods was primarily due to new projects in the REF business.

ENERGY TRADING


	2015			2014		2013			2017		2016			2015
	(In millions)								(In millions)
Operating Revenues — Non-utility operations	$	2,459		$	3,762	$	1,771		$	4,277	$	2,575		$	2,459
Purchased power and gas — non-utility	2,417			3,478		1,782			4,077		2,552			2,417
Gross Margin	42			284		(11		)
Non-utility Margin									200		23			42
Operation and maintenance	67			70		72			68		63			67
Depreciation and amortization	2			1		1			5		3			2
Taxes other than income	4			4		4			4		2			4
Operating Income (Loss)	(31		)	209		(88		)	123		(45		)	(31		)
Other (Income) and Deductions	6			10		8			2		29			6
Income Tax Expense (Benefit)	(15		)	77		(38		)	49		(29		)	(15		)
Net Income (Loss) Attributable to DTE Energy Company	$	(22	)	$	122	$	(58	)	$	72	$	(45	)	$	(22	)

Operating Revenues — Non-utility operations and Purchased power and gas — non-utility were impacted by ~~a decrease in gas prices, partially offset by~~ an increase in both volumes ~~primarily in the~~and gas ~~structured strategy~~prices for the year ended December 31, ~~2015.~~2017, primarily in the gas structured strategy. For ~~2014,~~2016, these line items were impacted by an increase in ~~gas~~ volumes, ~~and~~partially offset by a decrease in gas prices, primarily in the gas structured strategy.

~~Gross~~Non-utility Margin ~~decreased $242~~increased $177 million in ~~2015~~2017 and ~~increased $295~~decreased $19 million in ~~2014.~~2016. The ~~decrease~~change in ~~2015 and the increase in 2014 are~~both periods was primarily due to timing from ~~MTM adjustments on certain transactions~~the unrealized and realized margins presented in the ~~gas structured strategy.~~following tables:



	2017
	(In millions)
Unrealized Margins^(a)
Favorable results, primarily in gas structured and gas full requirements strategies^(b)	$	113
Unfavorable results, primarily in power and gas trading and power full requirements strategies	(26		)
	$	87
Realized Margins^(a)
Favorable results, primarily in gas structured, environmental trading and gas storage strategies^(c)	$	103
Unfavorable results, primarily in the power full requirements strategy	(13		)
	$	90
Increase in Non-utility Margin	$	177

(a)


(b)	Amount includes $113 million of timing related gains related to gas strategies which will reverse in future periods as the underlying contracts settle.


(c)	Amount includes $95 million of timing related losses related to gas strategies recognized in previous periods that reversed as the underlying contracts settled.



	2016
	(In millions)
Unrealized Margins^(a)
Unfavorable results, primarily in gas structured, gas full requirements, gas transportation, and power trading strategies^(b)	$	(74	)
Favorable results, primarily in gas trading and power full requirements strategies	28
	$	(46	)
Realized Margins^(a)
Favorable results, primarily in power full requirements, gas full requirements, power trading, and gas structured strategies	$	48
Unfavorable results, primarily in the gas transportation strategy^(c)	(21		)
	$	27
Decrease in Non-utility Margin	$	(19	)

(a)


(b)	Amount includes $46 million of timing related losses related to gas strategies which will reverse in future periods as the underlying contracts settle.


(c)	Amount includes $4 million of timing related gains related to gas strategies recognized in previous periods that reversed as the underlying contracts settled.

Other (Income) and Deductions decreased$27 million in 2017 and increased $23 million in 2016. The ~~decrease~~change in ~~Gross Margin in 2015 represents a $155 million decrease in realized margins and an $87 million decrease in unrealized margins. The $155 million decrease in realized margins is~~both periods was primarily due to $201 million of unfavorable results, primarily in gas structured, and power trading strategies, offset by $46 million of favorable results, primarily in power full requirements and gas transportation strategies. The $87 million decrease in unrealized margins is due2016 contributions to ~~$120 million of unfavorable results, primarily in~~ the ~~gas structured strategy, offset by $33 million of favorable results, primarily in power full requirements and gas transportation strategies.~~

The increase in Gross Margin in 2014 represents a $92 million increase in realized margins and a $203 million increase in unrealized margins. The $92 million increase in realized margins is due to $149 million of favorable results, primarily in gas structured and gas transportation strategies, offset by $57 million of unfavorable results, primarily in power full requirements, gas full requirements, and gas trading strategies. The $203 million increase in unrealized margins is due to $211 million of favorable results, primarily in gas structured and gas full requirements strategies, offset by $8 million of unfavorable results, primarily in the power full requirements strategy.

~~During the first quarter of 2015,~~DTE Energy Trading experienced slightly colder than normal weather conditions, on average, in the gas and power markets served, unlike the extreme weather conditions in the midwest and northeast that Energy Trading experienced in the first quarter of 2014. Consequently, this led to less favorable results in gas asset optimization strategies due to lower gas prices as compared to 2014, partially offset by lower realized losses from Energy Trading's power full requirements strategy as compared to 2014.

Natural gas structured transactions typically involve a physical purchase or sale of natural gas in the future and/or natural gas basis financial instruments which are derivatives and a related non-derivative pipeline transportation contract. These gas structured transactions can result in significant earnings volatility as the derivative components are marked-to-market without revaluing the related non-derivative contracts. Included in the $201 million of unfavorable realized results for the year ended December 31, 2015 related to gas strategies is $113 million of timing related gains and losses recognized in previous years that reversed as the underlying contracts settled. The $113 million of timing related items is comprised of a reversal of timing related losses of $65 million in 2014 and a reversal of timing gains of $48 million in 2015. Included in the $120 million of unfavorable unrealized results for the year ended December 31, 2015, related to gas strategies is $126 million of timing related gains and losses. The $126 million of timing related items is the variance of timing gains of $102 million in 2014 and timing losses of $24 million in 2015, which will reverse in future periods as the underlying contracts settle.

Included in the $149 million of favorable realized results for the year ended December 31, 2014 in Energy Trading's gas strategies, is $65 million of timing related losses recognized in 2013 that reversed as the underlying contracts were settled. Included in the $211 million of favorable unrealized results for the year ended December 31, 2014 in Energy Trading's gas strategies, is $102 million of timing related gains which will reverse in future periods, and the absence of $89 million of timing related losses in 2013.Foundation.

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.~~RTOs. Significant portions of the Energy Trading portfolio are economically hedged. Most financial instruments and physical power and natural gas contracts are deemed derivatives, whereas natural gas inventory, pipeline transportation, renewable energy credits, and storage assets are not derivatives. As a result, ~~DTE~~ 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" ~~in the "Capital Resources and Liquidity"~~ section ~~that follows~~herein and Notes 1112 and 1213 to the Consolidated Financial Statements in Item 8 of this Report, ~~“Fair Value”~~"Fair Value" and "Financial and Other Derivative ~~Instruments",~~Instruments," respectively.

CORPORATE AND OTHER

Corporate and Other includes various holding company activities, ~~and~~ holds certain non-utility debt, and holds energy-related investments. The ~~2015~~2017 net loss of ~~$48~~$103 million represents an ~~improvement~~increase of $9$42 million from the ~~2014~~2016 net loss of ~~$57~~$61 million due primarily to ~~2014 investment impairments and lower~~the remeasurement of deferred tax assets and liabilities to reflect the reduction in the corporate tax rate from the enactment of the TCJA in December 2017 resulting in income tax expense ~~related~~of $34 million, and the contribution of land and improvements to the ~~impact of New York state income tax reform enacted in March 2014, partially offset by higher interest expense.~~DTE Energy Beacon Park Foundation. The ~~2014~~2016 net loss of ~~$57~~$61 million represents an increase of $13 million from the ~~2013~~2015 net loss of ~~$44~~$48 million due primarily to ~~increased impairments of investments and increased deferred~~state tax ~~expense~~adjustments related to ~~New York state income tax reform enacted in March 2014.~~the Gas Storage and Pipelines acquisition and the write-off of unamortized debt issuance costs associated with the redemption of Junior Subordinated Debentures.

See Note 910 to the Consolidated Financial Statements in Item 8 of this Report, "Income ~~Taxes".~~Taxes."

CAPITAL RESOURCES AND LIQUIDITY

Cash Requirements

DTE Energy uses cash to maintain and invest in the electric and natural gas utilities, to grow the non-utility businesses, to retire, and pay interest on long-term debt, and to pay dividends. DTE Energy believes it will have sufficient internal and external capital resources to fund anticipated capital and operating requirements. DTE Energy expects that cash from operations in ~~2016~~2018 will be approximately ~~$1.8 billion, or approximately $100 million lower than 2015, due primarily to higher working capital requirements.~~$2.0 billion. DTE Energy anticipates base level utility capital ~~investments;~~investments, including environmental, renewable, and energy ~~optimization~~waste reduction expenditures; expenditures for non-utility businesses; and contributions to equity method investees in ~~2016~~2018 of approximately ~~$2.7~~$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.


	2015			2014			2013			2017			2016			2015
Cash and Cash Equivalents	(In millions)									(In millions)
Cash Flows From (Used For)
Operating Activities:
Cash Flow From (Used For)
Operating Activities
Net Income	$	720		$	911		$	668		$	1,112		$	834		$	720
Adjustments to reconcile Net Income to Net cash from operating activities:
Depreciation and amortization	852			1,145			1,094			1,030			976			852
Nuclear fuel amortization	46			48			38			53			58			46
Allowance for equity funds used during construction	(21		)	(21		)	(15		)	(23		)	(21		)	(21		)
Deferred income taxes	237			356			164			196			265			237
Asset (gains) losses and impairments, net	107			(4		)	(8		)	38			8			107
Working capital and other	(30		)	(596		)	213			(289		)	(36		)	(25		)
Net cash from operating activities	1,911			1,839			2,154			2,117			2,084			1,916
Investing Activities:
Investing Activities
Plant and equipment expenditures — utility	(1,817		)	(1,784		)	(1,534		)	(2,037		)	(1,898		)	(1,817		)
Plant and equipment expenditures — non-utility	(203		)	(265		)	(342		)	(213		)	(147		)	(203		)
Acquisition	(241		)	—			—
Proceeds from sale of assets	16			45			36
Acquisition, net of cash acquired										—			(1,147		)	(241		)
Restricted cash for debt redemption, principally Securitization, net	97			3			(1		)	(2		)	1			97
Contributions to equity method investees										(299		)	(239		)	(98		)
Other	(56		)	(59		)	(65		)	(13		)	42			58
Net cash used for investing activities	(2,204		)	(2,060		)	(1,906		)	(2,564		)	(3,388		)	(2,204		)
Financing Activities:
Financing Activities
Issuance of long-term debt, net of issuance costs	956			1,736			1,234			1,398			2,035			956
Redemption of long-term debt	(286		)	(1,237		)	(961		)	(385		)	(807		)	(286		)
Repurchase of long-term debt										—			(59		)	—
Issuance of equity units, net of issuance costs										—			654			—
Short-term borrowings, net	101			267			(109		)	122			—			101
Issuance of common stock	9			—			39
Repurchase of common stock	—			(52		)	—			(51		)	(33		)	—
Dividends on common stock	(501		)	(470		)	(445		)
Dividends on common stock and other										(592		)	(531		)	(501		)
Contributions from noncontrolling interests										50			114			23
Distributions to noncontrolling interests										(40		)	(5		)	(8		)
Other	3			(27		)	(19		)	(81		)	(9		)	(8		)
Net cash from (used for) financing activities	282			217			(261		)
Net Decrease in Cash and Cash Equivalents	$	(11	)	$	(4	)	$	(13	)
Net cash from financing activities										421			1,359			277
Net Increase (Decrease) in Cash and Cash Equivalents										$	(26	)	$	55		$	(11	)

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 ~~$72~~$33 million in ~~2015.~~2017. The increase in operating cash flows reflects a decrease in cash expenditures for working capital items, partially offset by lower Net Income after adjusting for non-cash and non-operating items. The decreases in depreciation and amortization and deferred income taxes are partially offset by the increase in asset (gains) losses and impairments, which is primarily due to DTE Energy's closure of the Shenango coke battery plant in 2015. See Note 4 to the Consolidated Financial Statements in Item 8 of this Report, "Acquisitions and Exit Activities".

~~Cash from operations decreased $315 million in 2014. The reduction~~ in operating cash flows reflects an increase in ~~cash expenditures for working capital items, partially offset by higher~~ Net Income ~~after adjusting~~and adjustments for non-cash and non-operating items, ~~(primarily depreciation~~primarily Depreciation and amortization, and ~~deferred~~Assets (gains) losses and impairments, partially offset by a decrease to Deferred income ~~taxes).~~taxes and working capital adjustments.

Cash from operations increased $168 million in 2016. The increase in operating cash flows reflects an increase in Net Income and adjustments for non-cash and non-operating items, primarily Depreciation and amortization, partially offset by decreases from Asset (gains) losses and impairments, net and working capital items.

The change in working capital items in ~~2015~~2017 primarily related to increases ~~in regulatory~~of cash used for Accounts Receivable, Inventories, Accrued pension liability, Derivative assets and liabilities, ~~derivative~~Equity earnings of equity method investees, and Other current and noncurrent assets and liabilities, ~~accounts receivable, net, and inventories,~~ partially offset by ~~decreases~~increases in ~~accrued pension liability, accrued~~cash from the Accrued postretirement liability, and ~~accounts payable.~~Regulatory assets and liabilities. The change in working capital items in ~~2014~~2016 primarily related to ~~fuel inventories, derivative assets~~increases in cash used for Accounts receivable, and ~~liabilities, and regulatory~~Regulatory assets and liabilities, partially offset by ~~the change~~increases in ~~accounts receivable, net, accounts~~cash from Accounts payable, Accrued pension liability, and ~~pension and other~~Accrued postretirement ~~liabilities.~~liability.

Cash used for Investing Activities

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

Capital spending within the utility businesses is primarily to maintain and improve ~~the~~ 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 $144~~decreased $824 million in ~~2015~~2017 due primarily to DTE Energy's ~~$241 million~~2016 acquisition ~~in January. This is~~of midstream natural gas assets, partially offset by increased capital expenditures, Contributions to equity method investees, primarily the ~~increase~~NEXUS Pipeline as it continues to develop, and two acquisitions of landfill gas facilities, which are presented in ~~restricted cash for debt redemption as this activity primarily relates to Securitization bonds that were fully redeemed in March 2015.~~Investing Activities - Other.

Net cash used for investing activities increased ~~$154 million~~$1.2 billion in ~~2014~~2016 due primarily to DTE Energy's acquisition of midstream natural gas assets, net of cash acquired of $83 million, of $1.1 billion, as described in Note 4 to the Consolidated Financial Statements in Item 8 of this Report, "Acquisitions and Exit Activities," as well as increased ~~capital expenditures by~~Contributions to equity method investees, primarily the ~~utility businesses, partially offset by decreased capital expenditures by the non-utility business and increased proceeds from sale of assets.~~NEXUS Pipeline as it continues to develop.

Cash from ~~(used for)~~ Financing Activities

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

DTE Energy's strategy is to have a targeted debt portfolio blend of fixed and variable interest rates and maturity. DTE Energy continually evaluates its leverage target, which is currently 50% to ~~53%~~54%, to ensure it is consistent with the objective of a strong investment grade debt rating.

Net cash from financing activities ~~increased $65~~decreased $938 million in ~~2015.~~2017. The ~~increase~~decrease is primarily attributable to ~~decreased redemptions~~a decrease in Issuances of long-term debt ~~which is~~and equity units, Contributions from noncontrolling interests, an increase in Dividends on common stock, and Distributions to noncontrolling interests, partially offset by ~~decreases in issuances~~an increase to Short-term borrowings, and a decrease to Redemptions and Repurchases of long-term ~~debt, short-term borrowings, and repurchase of common stock.~~debt.

Net cash from financing activities increased ~~$478 million~~$1.1 billion in ~~2014.~~2016. The increase is primarily attributable to increases in ~~short-term borrowings and issuances~~Issuances of long-term debt and equity units, which are partially offset by increased ~~redemptions~~Redemptions of long-term debt ~~repurchases~~and a decrease in Short-term borrowings. The increased issuances in 2016 were primarily related to the acquisition of ~~common stock, and increased dividends on common stock.~~midstream natural gas assets. See details in the "Acquisition Financing" section of Note 14 to the Consolidated Financial Statements in Item 8 of this Report, "Long-Term Debt."

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 ~~$500~~$110 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 ~~$1.5~~$1.4 billion of available liquidity at December 31, ~~2015,~~2017, consisting of cash and amounts available under unsecured revolving credit agreements.

DTE Energy expects to issue ~~approximately $100~~equity up to $300 million ~~of common stock~~ in ~~2016~~2018 through ~~its~~the dividend reinvestment plan and pension and other employee benefit plans.

At the discretion of management, and depending upon financial market conditions, DTE Energy ~~anticipates making 2016~~may make contributions up to ~~the~~$200 million, including contributions from DTE Electric of $175 million, to its pension plans ~~of up to $180 million and up to $20 million~~in 2018. DTE Energy does not anticipate making any contributions to the other postretirement benefit ~~plans. The planned contributions will be made~~plans in ~~cash or a combination of cash and DTE Energy common stock.~~2018.

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”~~"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”~~"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 December 31, ~~2015,~~2017, DTE Energy's contractual obligation to post collateral in the form of cash or ~~letter~~letters of credit in the event of a downgrade to below investment grade, under both hard trigger and soft trigger provisions, was approximately ~~$412~~$456 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 8, 9, ~~13, 15,~~10, 14, 16, 18, and 1820 to the Consolidated Financial Statements in Item 8 of this Report, "Regulatory ~~Matters",~~Matters," "Income ~~Taxes",~~Taxes," "Long-Term ~~Debt",~~Debt," "Short-Term Credit Arrangements and ~~Borrowings",~~Borrowings," "Commitments and Contingencies," and "Retirement Benefits and Trusteed ~~Assets".~~Assets."

Contractual Obligations

The following table details DTE Energy's, including DTE Electric's, contractual obligations for debt redemptions, leases, purchase obligations, and other long-term obligations as of December 31, ~~2015:~~2017:


	Total		2016		2017-2018		2019-2020		2021 and Beyond		Total		2018		2019-2020		2021-2022		2023 and Thereafter
	(In millions)										(In millions)
Long-term debt:
Mortgage bonds, notes, and other (a)	$	8,820	$	465	$	416	$	1,115	$	6,824	$	11,227	$	104	$	2,180	$	1,078	$	7,865
Junior subordinated debentures(b)	480		—		—		—		480		1,180		—		—		—		1,180
Capital lease obligations	24		9		12		3		—		6		5		1		—		—
Interest	7,022		475		756		754		5,037		9,877		504		970		849		7,554
Stock purchase contract^(c)											68		34		34		—		—
Operating leases	197		37		55		34		71		166		40		56		22		48
Electric, gas, fuel, transportation, and storage purchase obligations (b)	6,097		1,918		1,542		575		2,062
Long-term DTE Electric renewable energy power purchase agreements (c)(d)	1,379		82		165		165		967
Other long-term obligations (e)(f)(g)	126		38		64		10		14
Electric, gas, fuel, transportation, and storage purchase obligations^(d)											5,713		2,162		1,421		663		1,467
Long-term DTE Electric renewable energy power purchase agreements^(e)(f)											1,219		85		166		166		802
Other long-term obligations^(g)(h)(i)											614		484		106		16		8
Total obligations	$	24,145	$	3,024	$	3,010	$	2,656	$	15,455	$	30,070	$	3,418	$	4,934	$	2,794	$	18,924


(a)	Excludes $15 million of unamortized debt discount ~~on debt.~~and $69 million of unamortized debt issuance costs.


(b)	Excludes $35 million of unamortized debt issuance costs.


(c)	Includes $2 million of interest.


(d)	Excludes amounts associated with full requirements contracts where no stated minimum purchase volume is required.


~~(c)~~(e)	The agreements represent the minimum settlements with suppliers for renewable energy and renewable energy credits under existing contract terms which expire from 2030 through 2035. DTE Electric's share of plant output ranges from 44% to 100%.


~~(d)~~(f)	Excludes a power purchase agreement with a non-utility affiliate of DTE Energy.


~~(e)~~(g)	Includes liabilities for unrecognized tax benefits of $3$10 million.


~~(f)~~(h)	Excludes other long-term liabilities of ~~$138~~$178 million not directly derived from contracts or other agreements.

~~(g)~~(i)

At December 31, ~~2015,~~2017, DTE Energy met the minimum pension funding levels required under the Employee Retirement Income Security Act of 1974 (ERISA) and the Pension Protection Act of 2006 for the defined benefit pension plans. DTE Energy may contribute more than the minimum funding requirements for the pension plans and may also make contributions to the other postretirement benefit plans; however, these amounts are not included in the table above as such amounts are discretionary. Planned funding levels are disclosed in the ~~Capital~~"Capital Resources and ~~Liquidity~~Liquidity" and ~~Critical~~"Critical Accounting ~~Estimates~~Estimates" sections herein and in Note 1820 to the Consolidated Financial Statements in Item 8 of this Report, "Retirement Benefits and Trusteed ~~Assets".~~Assets."

Credit Ratings

Credit ratings are intended to provide banks and capital market participants with a framework for comparing the credit quality of securities and are not a recommendation to buy, sell, or hold securities. DTE Energy, DTE Electric, and DTE Gas' credit ratings affect their costs of capital and other terms of financing, as well as their ability to access the credit and commercial paper markets. DTE Energy, DTE Electric, and DTE Gas' management believes that the current credit ratings provide sufficient access to capital markets. However, disruptions in the banking and capital markets not specifically related to DTE Energy, DTE Electric, and DTE Gas may affect their ability to access these funding sources or cause an increase in the return required by investors.

As part of the normal course of business, DTE Electric, DTE Gas, and various non-utility subsidiaries of DTE Energy routinely enter into physical or financially settled contracts for the purchase and sale of electricity, natural gas, coal, capacity, storage, and other energy-related products and services. Certain of these contracts contain provisions which allow the counterparties to request that DTE Energy posts cash or letters of credit in the event that the senior unsecured debt rating of DTE Energy is downgraded below investment grade. The amount of such collateral which could be requested fluctuates based upon commodity prices and the provisions and maturities of the underlying transactions and could be substantial. Also, upon a downgrade below investment grade, DTE Energy, DTE Electric, and DTE Gas could have restricted access to the commercial paper market, and if DTE Energy is downgraded below investment grade, the non-utility businesses, especially the Energy Trading and Power and Industrial Projects segments, could be required to restrict operations due to a lack of available liquidity. A downgrade below investment grade could potentially increase the borrowing costs of DTE Energy, DTE Electric, and DTE Gas and their subsidiaries and may limit access to the capital markets. The impact of a downgrade will not affect DTE Energy, DTE Electric, and DTE Gas' ability to comply with existing debt covenants. While DTE Energy, DTE Electric, and DTE Gas currently do not anticipate such a downgrade, they cannot predict the outcome of current or future credit rating agency reviews.

In February 2016, based on DTE Energy's strong and predictable earnings and cash flow, Fitch upgraded DTE Energy's unsecured debt rating from 'BBB' to 'BBB+' and upgraded DTE Electric's secured debt rating from 'A' to 'A+'.

CRITICAL ACCOUNTING ESTIMATES

The preparation of the Registrants' Consolidated Financial Statements in conformity with generally accepted accounting principles requires that management apply accounting policies and make estimates and assumptions that affect results of operations and the amounts of assets and liabilities reported in the Consolidated Financial Statements. The Registrants' management believes that the areas described below require significant judgment in the application of accounting policy or in making estimates and assumptions in matters that are inherently uncertain and that may change in subsequent periods. Additional discussion of these accounting policies can be found in the Combined Notes to Consolidated Financial Statements in Item 8 of this Report.

Regulation

A significant portion of the Registrants' businesses are subject to regulation. This results in differences in the application of generally accepted accounting principles between regulated and non-regulated businesses. DTE Electric and DTE Gas are required to record regulatory assets and liabilities for certain transactions that would have been treated as revenue or expense in non-regulated businesses. Future regulatory changes or changes in the competitive environment could result in the discontinuance of this accounting treatment for regulatory assets and liabilities for some or all of the Registrants' businesses. The Registrants' management believes that currently available facts support the continued use of regulatory assets and liabilities and that all regulatory assets and liabilities are recoverable or refundable in the current rate environment.

See Note 89 to the Consolidated Financial Statements in Item 8 of this Report, "Regulatory ~~Matters".~~Matters."

Derivatives

Derivatives are generally recorded at fair value and shown as Derivative assets or liabilities. Changes in the fair value of the derivative instruments are recognized in earnings in the period of change. The normal purchases and normal sales exception requires, among other things, physical delivery in quantities expected to be used or sold over a reasonable period in the normal course of business. Contracts that are designated as normal purchases and normal sales are not recorded at fair value. Substantially all of the commodity contracts entered into by DTE Electric and DTE Gas meet the criteria specified for this exception.

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets ~~and~~or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable inputs. The ~~Registrants' management makes~~Registrants make certain assumptions ~~it believes~~they believe that market participants would use in pricing assets ~~and~~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 ~~the~~ assets and liabilities through the use of credit reserves, the impact of which was immaterial at December 31, ~~2015~~2017 and ~~2014.~~2016. The ~~Registrants' management believes it uses~~Registrants believe they use valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.

The fair values the Registrants calculate for their derivatives may change significantly as inputs and assumptions are updated for new information. Actual cash returns realized on derivatives may be different from the results the Registrants estimate using models. As fair value calculations are estimates based largely on commodity prices, the Registrants perform sensitivity analyses on the fair values of forward contracts. See the sensitivity analysis in Item 7A. of this report, "Quantitative and Qualitative Disclosures About Market ~~Risk".~~Risk." See also the ~~Fair Value~~"Fair Value" section herein.

See Notes 1112 and 1213 to the Consolidated Financial Statements in Item 8 of this Report, "Fair Value" and "Financial and Other Derivative ~~Instruments",~~Instruments," respectively.

~~Allowance for Doubtful Accounts~~

The Registrants each establish an allowance for doubtful accounts based on historical losses and their respective management's assessment of existing economic conditions, customer trends, and other factors. The allowance for doubtful accounts for DTE Electric and DTE Gas is calculated using the aging approach that utilizes rates developed in reserve studies and applies these factors to past due receivable balances. The Registrants believe the allowance for doubtful accounts is based on reasonable estimates.

Asset Impairments

Goodwill

Certain of DTE Energy's reporting units have goodwill or allocated goodwill resulting from business combinations. DTE Energy performs an impairment test for each of the reporting units with goodwill annually or whenever events or circumstances indicate that the value of goodwill may be impaired.

In performing Step 1 of the impairment test, DTE Energy compares the fair value of the reporting unit to its carrying value including goodwill. If the carrying value including goodwill were to exceed the fair value of a reporting unit, Step 2 of the test would be performed. Step 2 of the impairment test requires the carrying value of goodwill to be reduced to its fair value, if lower, as of the test date.

For Step 1 of the test, DTE Energy estimates the reporting unit's fair value using standard valuation techniques, including techniques which use estimates of projected future results and cash flows to be generated by the reporting unit. Such techniques generally include a terminal value that utilizes an earnings multiple approach, which incorporates the current market values of comparable entities. These cash flow valuations involve a number of estimates that require broad assumptions and significant judgment by management regarding future performance. DTE Energy also employs market-based valuation techniques to test the reasonableness of the indications of value for the reporting units determined under the cash flow technique.

DTE Energy performs an annual impairment test each October. In between annual tests, DTE Energy monitors its estimates and assumptions regarding estimated future cash flows, including the impact of movements in market indicators in future quarters, and will update the impairment analyses if a triggering event occurs. While DTE Energy believes the assumptions are reasonable, actual results may differ from projections. To the extent projected results or cash flows are revised downward, the reporting unit may be required to write down all or a portion of its goodwill, which would adversely impact DTE Energy's earnings.

DTE Energy performed its annual impairment test as of October 1, ~~2015~~2017 and determined that the estimated fair value of each reporting unit exceeded its carrying value, and no impairment existed. As part of the annual impairment test, DTE Energy also compared the aggregate fair value of the reporting units to its overall market capitalization. The implied premium of the aggregate fair value over market capitalization is likely attributable to an acquisition control premium (the price in excess of a stock's market price that investors typically pay to gain control of an entity).

The results of the test and key estimates that were incorporated are as follows as of the October 1, ~~2015~~2017 valuation date:


Reporting Unit	Goodwill		Fair Value Reduction % (a)		Discount Rate		Terminal Multiple (b)	Valuation Methodology (c)	Goodwill		Fair Value Reduction %^(a)		Discount Rate		Terminal Multiple^(b)	Valuation Methodology^(c)
	(In millions)								(In millions)
Electric	$	1,208	37	%	7	%	9.5x	DCF, assuming stock sale	$	1,208	46	%	6	%	10.0x	DCF, assuming stock sale
Gas	743		31	%	6	%	10.5x	DCF, assuming stock sale	743		35	%	6	%	11.0x	DCF, assuming stock sale
Gas Storage and Pipelines	24		74	%	8	%	11.0x	DCF, assuming asset sale	299		48	%	8	%	11.0x	DCF, assuming asset sale
Power and Industrial Projects (d)	26		23	%	7	%	10.0x	DCF, assuming asset sale (e)	26		21	%	8	%	10.0x	DCF, assuming asset sale^(e)
Energy Trading	17		47	%	10	%	n/a (f)	DCF, assuming asset sale	17		32	%	13	%	n/a^(f)	DCF, assuming asset sale
	$	2,018							$	2,293


(a)	Percentage by which the fair value of equity of the reporting unit would need to decline to equal its carrying value, including goodwill.


(b)	Multiple of enterprise value (sum of debt plus equity value) to earnings before interest, taxes, depreciation, and amortization (EBITDA).


(c)	Discounted cash flows (DCF) incorporated ~~2016-2020~~2018-2022 projected cash flows plus a calculated terminal value.


(d)	Power and Industrial Projects excludes the Biomass reporting unit, as this unit has no allocated goodwill.


(e)	Asset sales were assumed, except for Power and Industrial Projects' reduced emissions fuels projects, which assumed stock sales.


(f)	Due to lack of market comparable information for Energy Trading, DTE Energy capitalized the terminal year cash flows at the weighted average cost of capital (WACC) in lieu of applying a terminal EBITDA multiple.

DTE Energy identified a goodwill impairment test trigger for its Power and Industrial Projects reporting unit during the fourth quarter of 2015. The trigger related to the closure of the Shenango coke battery plant and the testing for recoverability of the long-lived asset for another coke battery in response to a sharp downturn in the North American steel industry. Accordingly, DTE Energy performed an interim goodwill impairment test for the Power and Industrial Projects reporting unit as of November 30, 2015 using updated cash flow and discount rate assumptions. As compared to the annual test, the interim valuation was negatively impacted by the projected lower value expected to be realized from DTE Energy's steel-related projects during 2016 and a higher discount rate. The fair value reduction percentage decreased from 23% to 16%. The fair value of the reporting unit exceeded its carrying value including goodwill. Therefore, the reporting unit passed Step 1 of the impairment test. No other triggers were identified during the fourth quarter of 2015. In 2016, DTE Energy will continue to monitor the North American steel industry for other events that may indicate the fair value of goodwill is below the carrying value of the Power and Industrial Projects reporting unit.

Long-Lived Assets

The Registrants evaluate the carrying value of long-lived assets, excluding goodwill, when circumstances indicate that the carrying value of those assets may not be recoverable. Conditions that could have an adverse impact on the cash flows and fair value of the long-lived assets are deteriorating business climate, condition of the asset, or plans to dispose of the asset before the end of its useful life. The review of long-lived assets for impairment requires significant assumptions about operating strategies and estimates of future cash flows, which require assessments of current and projected market conditions. An impairment evaluation is based on an undiscounted cash flow analysis at the lowest level for which independent cash flows of long-lived assets can be identified from other groups of assets and liabilities. Impairment may occur when the carrying value of the asset exceeds the future undiscounted cash flows. When the undiscounted cash flow analysis indicates a long-lived asset is not recoverable, the amount of the impairment loss is determined by measuring the excess of the long-lived asset over its fair value. An impairment would require the Registrants to reduce both the long-lived asset and current period earnings by the amount of the impairment, which would adversely impact their earnings.

During the fourth quarter of 2015, DTE Energy announced the closure of the Shenango coke battery plant. As a result of the closure, long-lived assets with a carrying value of $96 million were fully impaired.

In connection with the closure of the Shenango coke battery plant, DTE Energy reviewed another coke battery asset for events and circumstances that indicate the long-lived asset, of approximately $108 million, within the Power and Industrial Projects reporting unit might be impaired. However, DTE Energy’s estimate of undiscounted cash flows indicated that such carrying amounts were expected to be recovered. DTE Energy will continue to monitor the assumptions used in this analysis. Further deterioration of the steel industry could lead to a future impairment of the asset.

Pension and Other Postretirement Costs

DTE Energy sponsors defined benefit pension plans and other postretirement benefit plans for eligible employees of the Registrants. The measurement of the plan obligations and cost of providing benefits under these plans involve various factors, including numerous assumptions and accounting elections. When determining the various assumptions that are required, DTE Energy considers historical information as well as future expectations. The benefit costs are affected by, among other things, the actual rate of return on plan assets, the long-term expected return on plan assets, the discount rate applied to benefit obligations, the incidence of mortality, the expected remaining service period of plan participants, level of compensation and rate of compensation increases, employee age, length of service, the anticipated rate of increase of health care costs, benefit plan design changes, and the level of benefits provided to employees and retirees. Pension and other postretirement benefit costs attributed to the segments are included with labor costs and ultimately allocated to projects within the segments, some of which are capitalized.

DTE Energy had pension costs of $172 million in 2017, $167 million in 2016, and $221 million in ~~2015, $179 million in 2014, and $228 million in 2013.~~2015. Other postretirement benefit credits were $31 million in 2017, $111 million in 2016, and $99 million in ~~2015, $123 million in 2014, and $42 million in 2013.~~2015. Pension costs and other postretirement benefit credits for ~~2015 are~~2017 were calculated based upon ~~a number of~~several actuarial assumptions, including an expected long-term rate of return on plan assets of ~~7.75%~~7.50% for the pension plans and ~~8.00%~~7.75% for the other postretirement benefit plans. In developing the expected long-term rate of return assumptions, DTE Energy evaluated asset class risk and return expectations, as well as inflation assumptions. Projected returns are based on broad equity, bond, and other markets. DTE Energy's ~~2016~~2018 expected long-term rate of return on pension plan assets is based on an asset allocation assumption utilizing active investment management of ~~47%~~40% in equity markets, ~~25%~~32% in fixed income markets, including long duration bonds, and 28% invested in other assets. DTE Energy's ~~2016~~2018 expected long-term rate of return on other postretirement plan assets is based on an asset allocation assumption utilizing active investment management of ~~41%~~40% in equity markets, ~~25%~~26% in fixed income markets, and 34% invested in other assets. Because of market volatility, DTE Energy periodically reviews the asset allocation and rebalances the portfolio when considered appropriate. Given market conditions and financial market risk considerations, DTE Energy is maintaining its long-term rate of return assumptions for the pension plans and ~~the~~ other ~~postretirement~~post retirement plans at ~~7.75%~~7.50% and ~~8.00%~~7.75%, respectively for ~~2016.~~2018. DTE Energy believes these rates are reasonable assumptions for the long-term rate of return on the plan assets for ~~2016~~2018 given its investment strategy. DTE Energy will continue to evaluate the actuarial assumptions, including its expected rate of return, at least annually.

DTE Energy calculates the expected return on pension and other postretirement benefit plan assets by multiplying the expected return on plan assets by the market-related value (MRV) of plan assets at the beginning of the year, taking into consideration anticipated contributions and benefit payments that are to be made during the year. Current accounting rules provide that the MRV of plan assets can be either fair value or a calculated value that recognizes changes in fair value in a systematic and rational manner over not more than five years. For the pension plans, DTE Energy uses a calculated value when determining the MRV of the pension plan assets and recognizes changes in fair value over a three-year period. Accordingly, the future value of assets will be impacted as previously deferred gains or losses are recognized. ~~Financial markets~~Positive asset performance in ~~2015 detracted from DTE Energy's investment performance resulting~~2017 resulted in unrecognized net ~~losses.~~gains. As of December 31, ~~2015,~~2017, DTE Energy had ~~$175~~$223 million of cumulative ~~losses~~gains that remain to be recognized in the calculation of the MRV of pension assets related to investment performance in ~~2015~~2017 and ~~2014.~~2016. For the other postretirement benefit plans, DTE Energy uses fair value when determining the MRV of other postretirement benefit plan assets, therefore all investment gains and losses have been recognized in the calculation of MRV for these plans.

The discount rate that DTE Energy utilizes for determining future pension and other postretirement benefit obligations is based on a yield curve approach and a review of bonds that receive one of the two highest ratings given by a recognized rating agency. The yield curve approach matches projected pension plan and other postretirement benefit payment streams with bond portfolios reflecting actual liability duration unique to the plans. The discount rate determined on this basis was ~~4.50%~~3.70% for the pension ~~plans~~ and ~~4.50% for the~~ other postretirement plans at December 31, ~~2015~~2017 compared to ~~4.12%~~4.25% for the pension ~~plans~~ and ~~4.10% for the~~ other postretirement plans at December 31, ~~2014.~~2016.

~~The mortality assumptions that~~ DTE Energy ~~used to determine~~changed the ~~pension and other postretirement benefit obligations~~mortality assumption as of December 31, ~~2015, were~~2017 to reflect the updated ~~to incorporate the MP-2015 generational~~MP-2017 projection scale, ~~issued by~~along with the ~~Society~~actual experience and credibility of ~~Actuaries in 2015.~~each population. The mortality assumptions used at December 31, ~~2015~~2017 are the RP-2014 mortality table, ~~with variations by type of plan and participant’s union status and employment status,~~ projected back to 2006 using Scale MP-2014 and projected forward using Scale ~~MP-2015.~~MP-2017 with generational projection. The base mortality tables vary by type of plan, employee's union status and employment status, with additional adjustments to reflect the actual experience and credibility of each population.

DTE Energy estimates ~~that~~ the ~~2016~~2018 total pension costs will ~~approximate $175~~be approximately $150 million in 2018, compared to ~~$221~~$172 million in ~~2015,~~2017. The reduction in total pension costs is primarily due to ~~higher discount rates~~updated demographic assumptions and ~~changes to the mortality tables, partially~~positive asset performance, offset by ~~less than expected 2015 returns.~~a lower discount rate. The ~~2016~~2018 other postretirement benefit credit will ~~approximate $110~~be approximately $30 million compared to ~~$99~~$31 million in ~~2015 due to higher discount rate, changes to the mortality tables, and favorable retiree medical utilization trends, partially offset by lower than expected financial market returns.~~2017.

The health care trend rates for DTE Energy assume ~~6.25%~~6.75% for pre-65 participants and ~~6.75%~~7.25% for post-65 participants for ~~2016,~~2018, trending down to 4.50% for both pre-65 and post-65 participants in ~~2027.~~2030.

Future actual pension and other postretirement benefit costs ~~(credits)~~or credits will depend on future investment performance, changes in future discount rates, and various other factors related to plan design.

Lowering the expected long-term rate of return on the plan assets by one percentage point would have increased the ~~2015~~2017 pension costs by approximately ~~$38~~$42 million. Lowering the discount rate and the salary increase assumptions by one percentage point would have increased the ~~2015~~2017 pension costs by approximately ~~$21~~$38 million. Lowering the expected long-term rate of return on plan assets by one percentage point would have decreased the ~~2015~~2017 other postretirement credit by approximately ~~$15~~$18 million. Lowering the discount rate assumption by one percentage point would have decreased the ~~2015~~2017 other postretirement credit by approximately ~~$27~~$26 million. Lowering the health care cost trend assumptions by one percentage point would have increased the other postretirement credit for ~~2015~~2017 by approximately $6$5 million.

The value of the qualified pension and other postretirement benefit plan assets was ~~$5.4~~$6.5 billion at December 31, ~~2015~~2017 and ~~$5.5~~$5.8 billion at December 31, ~~2014.~~2016. At December 31, ~~2015,~~2017, DTE Energy's qualified pension plans were underfunded by ~~$1 billion~~$807 million and its other postretirement benefit plans were underfunded by ~~$230~~$62 million. The ~~2015~~2017 funding levels ~~generally increased due to increased discount rates, a change in the mortality tables,~~improved as positive asset performance and plan sponsor contributions ~~partially~~ offset ~~by lower than expected financial market returns.~~a decrease in discount rates.

Pension and other postretirement costs and pension cash funding requirements may increase in future years without typical returns in the financial markets. DTE Energy made contributions to its qualified pension plans of ~~$177~~$223 million in ~~2015~~2017 and ~~$188~~$179 million in ~~2014.~~2016. At the discretion of management, consistent with the Pension Protection Act of 2006, and depending upon financial market conditions, DTE Energy anticipates making contributions to its qualified pension plans of up to ~~$180~~$200 million in ~~2016~~2018 and up to ~~$960~~$415 million over the next five years. DTE Energy ~~made~~did not make other postretirement benefit plan contributions in 2017 and made contributions of ~~$199~~$20 million in ~~2015 and $24 million in 2014.~~2016. DTE Energy ~~is required by orders issued by the MPSC to make other postretirement benefit contributions at least equal to the amounts included in the utilities' base rates. As a result, DTE Energy anticipates~~does not anticipate making ~~up to $20 million of~~any contributions to its other postretirement plans in ~~2016 and~~2018 or over the next five years. The planned pension contributions will be made in cash and/or ~~a combination of cash and~~ DTE Energy common stock.

See Note 1820 to the Consolidated Financial Statements in Item 8 of this Report, "Retirement Benefits and Trusteed ~~Assets".~~Assets."

Legal Reserves

The Registrants are involved in various legal proceedings, claims, and litigation arising in the ordinary course of business. The Registrants regularly assess their liabilities and contingencies in connection with asserted or potential matters, and establish reserves when appropriate. Legal reserves are based upon the Registrants' management’s assessment of pending and threatened legal proceedings and claims against the Registrants.

Accounting for Tax Obligations

The Registrants are required to make judgments regarding the potential tax effects of various financial transactions and results of operations in order to estimate their obligations to taxing authorities. The Registrants account for uncertain income tax positions using a benefit recognition model with a two-step approach, a more-likely-than-not recognition criterion, and a measurement attribute that measures the position as the largest amount of tax benefit that is greater than 50% likely of being realized upon ultimate settlement. If the benefit does not meet the more likely than not criteria for being sustained on its technical merits, no benefit will be recorded. Uncertain tax positions that relate only to timing of when an item is included on a tax return are considered to have met the recognition threshold. The Registrants also have non-income tax obligations related to property, sales and use, and employment-related taxes, and ongoing appeals related to these tax matters.

Accounting for tax obligations requires judgments, including assessing whether tax benefits are more likely than not to be sustained, and estimating reserves for potential adverse outcomes regarding tax positions that have been taken. The Registrants also assess their ability to utilize tax attributes, including those in the form of carry-forwards, for which the benefits have already been reflected in the Consolidated Financial Statements. The Registrants believe the resulting tax reserve balances as of December 31, ~~2015~~2017 and ~~2014~~2016 are appropriate. The ultimate outcome of such matters could result in favorable or unfavorable adjustments to the Registrants' Consolidated Financial Statements, and such adjustments could be material.

See Note 910 to the Consolidated Financial Statements in Item 8 of this Report, "Income ~~Taxes".~~Taxes."

NEW ACCOUNTING PRONOUNCEMENTS

See Note 3 to the Consolidated Financial Statements in Item 8 of this Report, "New Accounting ~~Pronouncements".~~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 1112 and 1213 to the Consolidated Financial Statements in Item 8 of this Report, "Fair Value" and "Financial and Other Derivative ~~Instruments",~~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 1112 to the Consolidated Financial Statements in Item 8 of this Report, "Fair ~~Value".~~Value."

The following ~~tables provide~~table provides details on changes in ~~the Registrants'~~DTE Energy's MTM net asset (or liability) ~~position during 2015:~~position:


	Total			Total
	(In millions)			(In millions)
MTM at December 31, 2014	$	87
MTM at December 31, 2016				$	(86	)
Reclassified to realized upon settlement	(45		)	(52		)
Changes in fair value recorded to income	(28		)	128
Amounts recorded to unrealized income	(73		)	76
Changes in fair value recorded in regulatory liabilities	12			25
Change in collateral held by (for) others	16
Option premiums paid (received) and other	(2		)
MTM at December 31, 2015	$	40
Change in collateral				(7		)
MTM at December 31, 2017				$	8

The table below shows the maturity of ~~the Registrants'~~DTE Energy's MTM positions. The positions from ~~2019~~2021 and beyond principally represent longer tenor gas structured transactions:


Source of Fair Value	2016			2017			2018			2019 and Beyond			Total Fair Value			2018			2019		2020			2021 and Beyond			Total Fair Value
	(In millions)															(In millions)
Level 1	$	(13	)	$	(14	)	$	(2	)	$	4		$	(25	)	$	3		$	3	$	(1	)	$	2		$	7
Level 2	21			7			5			2			35			(16		)	6		4			3			(3		)
Level 3	41			6			1			(52		)	(4		)	(5		)	10		1			(15		)	(9		)
MTM before collateral adjustments	$	49		$	(1	)	$	4		$	(46	)	6			$	(18	)	$	19	$	4		$	(10	)	(5		)
Collateral adjustments													34														13
MTM at December 31, 2015													$	40
MTM at December 31, 2017																											$	8

Item 7A. Quantitative and Qualitative Disclosures About Market Risk

Market Price Risk

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

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

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

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

Credit Risk

~~Bankruptcies~~

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

Trading Activities

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

The following table displays the credit quality of DTE Energy's trading counterparties as of December 31, ~~2015:~~2017:


	Credit Exposure Before Cash Collateral		Cash Collateral			Net Credit Exposure		Credit Exposure Before Cash Collateral		Cash Collateral			Net Credit Exposure
	(In millions)							(In millions)
Investment Grade (a)
A- and Greater	$	164	$	(2	)	$	162	$	226	$	—		$	226
BBB+ and BBB	230		—			230		265		—			265
BBB-	56		—			56		65		—			65
Total Investment Grade	450		(2		)	448		556		—			556
Non-investment grade (b)	7		—			7		6		—			6
Internally Rated — investment grade (c)	238		—			238		295		(1		)	294
Internally Rated — non-investment grade (d)	21		(4		)	17		20		(2		)	18
Total	$	716	$	(6	)	$	710	$	877	$	(3	)	$	874


(a)	This category includes counterparties with minimum credit ratings of Baa3 assigned by Moody’s Investors Service (Moody’s) or BBB- assigned by Standard & Poor’s Rating Group, a division of McGraw-Hill Companies, Inc. (Standard & Poor’s). The five largest counterparty exposures, combined, for this category represented approximately ~~24%~~15% of the total gross credit exposure.


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


(c)	This category includes counterparties that have not been rated by Moody’s or Standard & Poor’s, but are considered investment grade based on DTE Energy’s evaluation of the counterparty’s creditworthiness. The five largest counterparty exposures, combined, for this category represented approximately ~~13%~~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 approximately 3%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).~~LIBOR. As of December 31, ~~2015,~~2017, DTE Energy had a floating rate debt-to-total debt ratio of approximately ~~5.2%~~4.8%.

Foreign Currency Exchange Risk

DTE Energy has foreign currency exchange risk arising from market price fluctuations associated with fixed priced contracts. These contracts are denominated in Canadian dollars and are primarily for the purchase and sale of natural gas and power, as well as for long-term transportation capacity. To limit DTE Energy's exposure to foreign currency exchange fluctuations, DTE Energy has entered into a series of foreign currency exchange forward contracts through June ~~2020.~~2022.

Summary of Sensitivity Analyses

The Registrants performed sensitivity analyses on the fair values of commodity contracts and long-term debt ~~obligations, and foreign currency exchange forward contracts.~~obligations. The commodity contracts ~~and foreign currency exchange risk~~ listed below principally relate to energy marketing and trading activities. The sensitivity ~~analysis~~analyses involved increasing and decreasing forward prices and rates at December 31, ~~2015~~2017 and ~~2014~~2016 by a hypothetical 10% and calculating the resulting change in the fair values.

The results of the sensitivity ~~analysis calculations as of December 31, 2015 and 2014:~~analyses:


	Assuming a 10% Increase in Prices/Rates						Assuming a 10% Decrease in Prices/Rates						Assuming a 10% Increase in Prices/Rates						Assuming a 10% Decrease in Prices/Rates
	As of December 31,						As of December 31,						As of December 31,						As of December 31,
Activity	2015			2014			2015			2014		Change in the Fair Value of	2017			2016			2017			2016			Change in the Fair Value of
	(In millions)												(In millions)
Gas contracts	$	(5	)	$	(4	)	$	5		$	5	Commodity contracts	$	—		$	14		$	—		$	(14	)	Commodity contracts
Power contracts	$	16		$	—		$	(16	)	$	—	Commodity contracts	$	5		$	18		$	(7	)	$	(18	)	Commodity contracts
Oil contracts	$	1		$	—		$	(1	)	$	—	Commodity contracts
Interest rate risk — DTE Energy	$	(372	)	$	(336	)	$	395		$	356	Long-term debt	$	(576	)	$	(529	)	$	581		$	510		Long-term debt
Interest rate risk — DTE Electric	$	(225	)	$	(202	)	$	243		$	216	Long-term debt	$	(246	)	$	(235	)	$	263		$	252		Long-term debt

For further discussion of market risk, see Management's Discussion and Analysis in Item 7 of this Report and Note 1213 to the Consolidated Financial Statements in Item 8 of this Report, "Financial and Other Derivative ~~Instruments".~~Instruments."

Item 8. Financial Statements and Supplementary Data

The following Consolidated Financial Statements and financial statement schedules are included herein:



	Page
DTE Energy — Controls and Procedures	5156
DTE Energy — Report of Independent Registered Public Accounting Firm	5257
DTE Energy — Consolidated Statements of Operations	5359
DTE Energy — Consolidated Statements of Comprehensive Income	5460
DTE Energy — Consolidated Statements of Financial Position	5561
DTE Energy — Consolidated Statements of Cash Flows	5763
DTE Energy — Consolidated Statements of Changes in Equity	5864
DTE Electric — Controls and Procedures	5965
DTE Electric — Report of Independent Registered Public Accounting Firm	6066
DTE Electric — Consolidated Statements of Operations	6167
DTE Electric — Consolidated Statements of Comprehensive Income	6268
DTE Electric — Consolidated Statements of Financial Position	6369
DTE Electric — Consolidated Statements of Cash Flows	6571
DTE Electric — Consolidated Statements of Changes in Shareholder's Equity	6672
Combined Notes to Consolidated Financial Statements	6773
Note 1 — Organization and Basis of Presentation	6773
Note 2 — Significant Accounting Policies	7077
Note 3 — New Accounting Pronouncements	7682
Note 4 — Acquisitions and Exit Activities	7783
Note 5 — ~~Property, Plant, and Equipment~~Goodwill	7885
Note 6 — ~~Jointly-Owned Utility~~Property, Plant,	80
~~Note 7 — Asset Retirement Obligations~~	80
~~Note 8 — Regulatory Matters~~	81
~~Note 9 — Income Taxes~~ and Equipment	86
Note 107 — ~~Earnings Per Share~~Jointly-Owned Utility Plant	88
Note 8 — Asset Retirement Obligations	88
Note 9 — Regulatory Matters	89
Note 10 — Income Taxes	93
Note 11 — Earnings Per Share	97
Note 12 — Fair Value	8998
Note 1213 — Financial and Other Derivative Instruments	97105
Note 1314 — Long-Term Debt	~~102~~110
Note 1415 — Preferred and Preference Securities	~~104~~113
Note 1516 — Short-Term Credit Arrangements and Borrowings	~~104~~113
Note 1617 — Capital and Operating Leases	~~105~~114
Note 1718 — Commitments and Contingencies	~~106~~115
Note 1819 — Nuclear Operations	120
Note 20 — Retirement Benefits and Trusteed Assets	~~112~~122
Note 1921 — Stock-Based Compensation	~~126~~132
Note 2022 — Segment and Related Information	~~128~~135
Note 2123 — Related Party Transactions	~~131~~137
Note 2224 — Supplementary Quarterly Financial Information (Unaudited)	~~132~~139
Financial Statement Schedule
Schedule II — Valuation and Qualifying Accounts	~~145~~153

DTE Energy — Controls and Procedures

(a) Evaluation of disclosure controls and procedures

Management of DTE Energy carried out an evaluation, under the supervision and with the participation of DTE ~~Energy’s~~Energy's Chief Executive Officer (CEO) and Chief Financial Officer (CFO), of the effectiveness of the design and operation of DTE Energy's disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of December 31, ~~2015,~~2017, which is the end of the period covered by this report. Based on this evaluation, DTE ~~Energy’s~~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~~Energy's management, including its CEO and CFO, as appropriate to allow timely decisions regarding required disclosure. Due to the inherent limitations in the effectiveness of any disclosure controls and procedures, management cannot provide absolute assurance that the objectives of its disclosure controls and procedures will be attained.

(b) Management’s report on internal control over financial reporting

Management of DTE Energy is responsible for establishing and maintaining adequate internal control over financial reporting as such term is defined in Exchange Act Rules 13a-15(f) and 15d-15(f). Internal control over financial reporting is a process designed by, or under the supervision of, DTE Energy's CEO and CFO, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Management of DTE Energy has assessed the effectiveness of DTE Energy’s internal control over financial reporting as of December 31, ~~2015.~~2017. In making this assessment, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (2013 COSO) in Internal Control - Integrated Framework. Based on this assessment, management concluded that, as of December 31, ~~2015,~~2017, DTE Energy’s internal control over financial reporting was effective based on those criteria.

The effectiveness of DTE Energy’s internal control over financial reporting as of December 31, ~~2015~~2017 has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm who also audited DTE Energy’s financial statements, as stated in their report which appears herein.

There have been no changes in DTE ~~Energy’s~~Energy's internal control over financial reporting during the quarter ended December 31, ~~2015~~2017 that have materially affected, or are reasonably likely to materially affect, DTE ~~Energy’s~~Energy's internal control over financial reporting.

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholders of

DTE Energy Company

Opinions on the Financial Statements and Internal Control over Financial Reporting

~~In our opinion, the consolidated financial statements listed in~~We have audited the accompanying ~~index present fairly, in all material respects, the~~consolidated statements of financial position of DTE Energy Company and its subsidiaries atas of December 31, ~~2015~~2017 and ~~2014,~~ 2016,and the ~~results~~related consolidated statements of ~~their~~ operations, of comprehensive income, of changes in equity and ~~their~~of cash flows for each of the three years in the period ended December 31, ~~2015~~2017, including the related notes and schedule of valuation and qualifying accounts for each of the three years in the period ended December 31, 2017 listed in the accompanying index (collectively referred to as the “consolidated financial statements”).We also have audited the Company's internal control over financial reporting as of December 31, 2017, based on criteria established in Internal Control - Integrated Framework(2013)issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).

In our opinion, the consolidatedfinancial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2017and 2016, and the results of theiroperations and theircash flows for each of the three years in the period ended December 31, 2017 in conformity with accounting principles generally accepted in the United States of America. ~~In addition, in our opinion, the financial statement schedule listed in the accompanying indexpresents fairly, in all material respects, the information set forth therein when read in conjunction with the related consolidatedfinancial statements.~~ Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, ~~2015,~~2017, based on criteria established in Internal Control - Integrated Framework ~~2013~~(2013)issued by the ~~Committee of Sponsoring Organizations of the Treadway Commission (COSO).~~ COSO.

Basis for Opinions

The Company's management is responsible for these consolidated financial statements, ~~and financial statement schedule,~~ for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s ~~report~~Report on ~~internal control~~Internal Control over ~~financial reporting.~~Financial Reporting. Our responsibility is to express opinions on ~~these~~ the Company’s consolidatedfinancial statements ~~on the financial statement schedule,~~ and on the Company's internal control over financial reporting based on our ~~integrated~~ audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) ("PCAOB") and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the ~~Public Company Accounting Oversight Board (United States).~~PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects.

Our audits of the consolidatedfinancial statements included performing procedures to assess the risks of material misstatement of the consolidatedfinancial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence ~~supporting~~regarding the amounts and disclosures in the consolidatedfinancial ~~statements, assessing~~statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, ~~and~~as well as evaluating the overall presentation of the consolidatedfinancial ~~statement presentation.~~statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

Definition and Limitations of Internal Control over Financial Reporting

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

/s/ PricewaterhouseCoopers LLP

Detroit, Michigan

February ~~10, 2016~~16, 2018

52We have served as the Company’s auditor since 2008.

DTE Energy Company

Consolidated Statements of Operations


	Year Ended December 31,									Year Ended December 31,
	2015			2014			2013			2017			2016			2015
	(In millions, except per share amounts)									(In millions, except per share amounts)
Operating Revenues
Utility operations	$	6,238		$	6,884		$	6,643		$	6,434		$	6,497		$	6,238
Non-utility operations	4,099			5,417			3,018			6,173			4,133			4,099
	10,337			12,301			9,661			12,607			10,630			10,337

Operating Expenses
Fuel, purchased power, and gas — utility	2,081			2,407			2,281			1,881			1,968			2,081
Fuel, purchased power, and gas — non-utility	3,481			4,615			2,544			5,283			3,562			3,481
Operation and maintenance	2,214			2,204			2,208			2,335			2,302			2,214
Depreciation and amortization	852			1,145			1,094			1,030			976			852
Taxes other than income	364			352			340			391			370			364
Asset (gains) losses and impairments, net	106			(12		)	(9		)	41			7			106
	9,098			10,711			8,458			10,961			9,185			9,098
Operating Income	1,239			1,590			1,203			1,646			1,445			1,239

Other (Income) and Deductions
Interest expense	450			429			436			536			472			450
Interest income	(13		)	(10		)	(9		)	(12		)	(20		)	(13		)
Other income	(209		)	(196		)	(201		)	(268		)	(207		)	(209		)
Other expenses	61			92			55			103			95			61
	289			315			281			359			340			289
Income Before Income Taxes	950			1,275			922			1,287			1,105			950

Income Tax Expense	230			364			254			175			271			230

Net Income	720			911			668			1,112			834			720

Less: Net Income (Loss) Attributable to Noncontrolling Interests	(7		)	6			7
Less: Net Loss Attributable to Noncontrolling Interests										(22		)	(34		)	(7		)

Net Income Attributable to DTE Energy Company	$	727		$	905		$	661		$	1,134		$	868		$	727

Basic Earnings per Common Share
Net Income Attributable to DTE Energy Company	$	4.05		$	5.11		$	3.76		$	6.32		$	4.84		$	4.05

Diluted Earnings per Common Share
Net Income Attributable to DTE Energy Company	$	4.05		$	5.10		$	3.76		$	6.32		$	4.83		$	4.05

Weighted Average Common Shares Outstanding
Basic	179			177			175			179			179			179
Diluted	179			177			175			179			179			179
Dividends Declared per Common Share	$	2.84		$	2.69		$	2.59		$	3.36		$	3.06		$	2.84

See Combined Notes to Consolidated Financial Statements

DTE Energy Company

Consolidated Statements of Comprehensive Income

Year Ended December 31,
2015 2014 2013
(In millions)
Net Income $ 720
$ 911
$ 668

Other comprehensive income (loss), net of tax:
Benefit obligations, net of taxes of $8, $(9), and $13, respectively 13
(18 ) 22
Net unrealized gains on investments during the period, net of taxes of $—, $1, and $1, respectively 1
1
2
Foreign currency translation (4 ) (2 ) (2 )
Other comprehensive income (loss) 10
(19 ) 22

Comprehensive income 730
892
690
Less comprehensive income (loss) attributable to noncontrolling interests (7 ) 6
7
Comprehensive income attributable to DTE Energy Company $ 737
$ 886
$ 683



	Year Ended December 31,
	2017			2016			2015
	(In millions)
Net Income	$	1,112		$	834		$	720

Other comprehensive income (loss), net of tax:
Benefit obligations, net of taxes of $5, $6, and $8, respectively	10			11			13
Net unrealized gains on derivatives during the period, net of taxes of $—, $—, and $—, respectively	1			—			—
Net unrealized gains on investments during the period, net of taxes of $1, $1, and $—, respectively	1			1			1
Foreign currency translation	1			—			(4		)
Other comprehensive income	13			12			10

Comprehensive income	1,125			846			730
Less: Comprehensive loss attributable to noncontrolling interests	(22		)	(34		)	(7		)
Comprehensive Income Attributable to DTE Energy Company	$	1,147		$	880		$	737

See Combined Notes to Consolidated Financial Statements

DTE Energy Company

Consolidated Statements of Financial Position


	December 31,						December 31,
	2015			2014			2017			2016
	(In millions)						(In millions)
ASSETS
Current Assets
Cash and cash equivalents	$	37		$	48		$	66		$	92
Restricted cash	23			120			23			21
Accounts receivable (less allowance for doubtful accounts of $49 and $54, respectively)
Accounts receivable (less allowance for doubtful accounts of $49 and $41, respectively)
Customer	1,276			1,504			1,758			1,522
Other	72			94			98			71
Inventories
Fuel and gas	480			512			399			416
Materials and supplies	323			292			380			356
Derivative assets	129			128			103			47
Regulatory assets	32			76			55			42
Other	203			238			199			195
	2,575			3,012			3,081			2,762
Investments
Nuclear decommissioning trust funds	1,236			1,241			1,492			1,320
Investments in equity method investees	514			434			1,073			752
Other	186			194			232			201
	1,936			1,869			2,797			2,273
Property
Property, plant, and equipment	28,121			26,538			31,424			30,029
Less accumulated depreciation and amortization	(10,087		)	(9,718		)
Accumulated depreciation and amortization							(10,703		)	(10,299		)
	18,034			16,820			20,721			19,730
Other Assets
Goodwill	2,018			2,018			2,293			2,286
Regulatory assets	3,692			3,651			3,723			3,871
Securitized regulatory assets	—			34
Intangible assets	89			102			867			842
Notes receivable	85			90			73			73
Derivative assets	54			44			51			34
Other	254			259			161			170
	6,192			6,198			7,168			7,276
Total Assets	$	28,737		$	27,899		$	33,767		$	32,041

See Combined Notes to Consolidated Financial Statements

DTE Energy Company

Consolidated Statements of Financial Position — (Continued)


	December 31,						December 31,
	2015			2014			2017			2016
	(In millions, except shares)						(In millions, except shares)
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	809		$	973		$	1,171		$	1,079
Accrued interest	89			86			111			96
Dividends payable	131			122			158			148
Short-term borrowings	499			398			621			499
Current portion long-term debt, including capital leases	473			274			109			14
Derivative liabilities	57			77			99			69
Regulatory liabilities	41			153			18			34
Other	429			494			525			498
	2,528			2,577			2,812			2,437
Long-Term Debt (net of current portion)
Mortgage bonds, notes, and other	8,340			7,860			11,039			10,506
Junior subordinated debentures	480			480			1,145			756
Capital lease obligations	15			3			1			7
	8,835			8,343			12,185			11,269
Other Liabilities
Deferred income taxes	3,923			3,701			1,888			4,162
Regulatory liabilities	569			667			2,875			555
Asset retirement obligations	2,194			1,962			2,320			2,197
Unamortized investment tax credit	62			41			122			93
Derivative liabilities	86			8			47			98
Accrued pension liability	1,133			1,280			924			1,152
Accrued postretirement liability	228			515			61			36
Nuclear decommissioning	177			182			220			194
Other	207			281			323			349
	8,579			8,637			8,780			8,836

Commitments and Contingencies (Notes 8 and 17)
Commitments and Contingencies (Notes 9 and 18)

Equity
Common stock, without par value, 400,000,000 shares authorized, and 179,470,213 and 176,991,231 shares issued and outstanding, respectively	4,123			3,904
Common stock, without par value, 400,000,000 shares authorized, and 179,386,967 and 179,432,581 shares issued and outstanding, respectively							3,989			4,030
Retained earnings	4,794			4,578			5,643			5,114
Accumulated other comprehensive loss	(145		)	(155		)	(120		)	(133		)
Total DTE Energy Company Equity	8,772			8,327			9,512			9,011
Noncontrolling interests	23			15			478			488
Total Equity	8,795			8,342			9,990			9,499
Total Liabilities and Equity	$	28,737		$	27,899		$	33,767		$	32,041

See Combined Notes to Consolidated Financial Statements

DTE Energy Company

Consolidated Statements of Cash Flows


	Year Ended December 31,									Year Ended December 31,
	2015			2014			2013			2017			2016			2015
Operating Activities	(In millions)									(In millions)
Net Income	$	720		$	911		$	668		$	1,112		$	834		$	720
Adjustments to reconcile Net Income to net cash from operating activities:
Adjustments to reconcile Net Income to Net cash from operating activities:
Depreciation and amortization	852			1,145			1,094			1,030			976			852
Nuclear fuel amortization	46			48			38			53			58			46
Allowance for equity funds used during construction	(21		)	(21		)	(15		)	(23		)	(21		)	(21		)
Deferred income taxes	237			356			164			196			265			237
Equity earnings of equity method investees	(66		)	(48		)	(59		)	(102		)	(68		)	(66		)
Dividends from equity method investees	64			55			61			74			68			64
Asset (gains) losses and impairments, net	107			(4		)	(8		)	38			8			107
Changes in assets and liabilities:
Accounts receivable, net	259			48			(154		)	(252		)	(226		)	259
Inventories	1			(177		)	123			(4		)	37			1
Accounts payable	(158		)	128			14			129			145			(158		)
Accrued pension liability	(147		)	627			(644		)	(228		)	19			(147		)
Accrued postretirement liability	(287		)	165			(526		)	25			(192		)	(287		)
Derivative assets and liabilities	47			(199		)	107			(94		)	126			47
Regulatory assets and liabilities	85			(1,177		)	1,269			217			(40		)	85
Other current and noncurrent assets and liabilities	172			(18		)	22			(54		)	95			177
Net cash from operating activities	1,911			1,839			2,154			2,117			2,084			1,916
Investing Activities
Plant and equipment expenditures — utility	(1,817		)	(1,784		)	(1,534		)	(2,037		)	(1,898		)	(1,817		)
Plant and equipment expenditures — non-utility	(203		)	(265		)	(342		)	(213		)	(147		)	(203		)
Acquisition	(241		)	—			—
Proceeds from sale of assets	16			45			36
Acquisition, net of cash acquired										—			(1,147		)	(241		)
Restricted cash for debt redemption, principally Securitization, net	97			3			(1		)	(2		)	1			97
Proceeds from sale of nuclear decommissioning trust fund assets	885			1,146			1,118			1,240			1,457			885
Investment in nuclear decommissioning trust funds	(898		)	(1,156		)	(1,134		)	(1,226		)	(1,463		)	(898		)
Distributions from equity method investees	19			13			8			10			11			19
Contributions to equity method investees	(98		)	(42		)	(21		)	(299		)	(239		)	(98		)
Other	36			(20		)	(36		)	(37		)	37			52
Net cash used for investing activities	(2,204		)	(2,060		)	(1,906		)	(2,564		)	(3,388		)	(2,204		)
Financing Activities
Issuance of long-term debt, net of issuance costs	956			1,736			1,234			1,398			2,035			956
Redemption of long-term debt	(286		)	(1,237		)	(961		)	(385		)	(807		)	(286		)
Repurchase of long-term debt										—			(59		)	—
Issuance of equity units, net of issuance costs										—			654			—
Short-term borrowings, net	101			267			(109		)	122			—			101
Issuance of common stock	9			—			39
Repurchase of common stock	—			(52		)	—			(51		)	(33		)	—
Dividends on common stock	(501		)	(470		)	(445		)	(592		)	(531		)	(501		)
Contributions from noncontrolling interests										50			114			23
Distributions to noncontrolling interests										(40		)	(5		)	(8		)
Other	3			(27		)	(19		)	(81		)	(9		)	(8		)
Net cash from (used for) financing activities	282			217			(261		)
Net Decrease in Cash and Cash Equivalents	(11		)	(4		)	(13		)
Net cash from financing activities										421			1,359			277
Net Increase (Decrease) in Cash and Cash Equivalents										(26		)	55			(11		)
Cash and Cash Equivalents at Beginning of Period	48			52			65			92			37			48
Cash and Cash Equivalents at End of Period	$	37		$	48		$	52		$	66		$	92		$	37

Supplemental disclosure of cash information
Cash paid (received) for:
Interest, net of interest capitalized	$	428		$	415		$	418		$	495		$	448		$	428
Income taxes	$	14		$	(35	)	$	121		$	4		$	(1	)	$	14
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	$	207		$	212		$	329		$	295		$	312		$	207
Premium on equity units										$	—		$	98		$	—

See Combined Notes to Consolidated Financial Statements

DTE Energy Company

Consolidated Statements of Changes in Equity


									Accumulated														Retained Earnings				Accumulated Other Comprehensive Income (Loss)			Noncontrolling Interests
									Other			Non-						Common Stock
	Common Stock					Retained			Comprehensive			Controlling						Shares		Amount						Total
	Shares		Amount			Earnings			Income (Loss)			Interest			Total			(Dollars in millions, shares in thousands)
	(Dollars in millions, shares in thousands)
Balance, December 31, 2012	172,352		$	3,587		$	3,944		$	(158	)	$	38		$	7,411
Net Income	—		—			661			—			7			668
Balance, December 31, 2014																		176,991		$	3,904					$			4,578		$	(155	)		$	15			$	8,342
Net Income (Loss)																		—		—						727				—				(7		)		720
Dividends declared on common stock	—		—			(454		)	—			—			(454		)	—		—			(510		)			—			—				(510		)
Issuance of common stock	589		39			—			—			—			39			105		9			—				—			—				9
Contribution of common stock to pension plan	3,026		200			—			—			—			200			1,428		117			—				—			—				117
Benefit obligations, net of tax	—		—			—			22			—			22			—		—			—				13			—				13
Net change in unrealized gains on investments, net of tax	—		—			—			2			—			2			—		—			—				1			—				1
Foreign currency translation	—		—			—			(2		)	—			(2		)	—		—			—				(4		)	—				(4		)
Stock-based compensation, distributions to noncontrolling interests, and other	1,120		81			(1		)	—			(12		)	68
Balance, December 31, 2013	177,087		$	3,907		$	4,150		$	(136	)	$	33		$	7,954
Net Income	—		—			905			—			6			911
Stock-based compensation, net contributions from noncontrolling interests, and other																		946		93			(1		)		—			15				107
Balance, December 31, 2015																		179,470		$	4,123		$	4,794			$	(145	)	$	23			$	8,795
Implementation of ASU 2016-09																		—		—			3				—			—				3
Net Income (Loss)																		—		—			868				—			(34		)		834
Dividends declared on common stock																		—		—			(548		)		—			—				(548		)
Repurchase of common stock																		(394	)	(33		)	—				—			—				(33		)
Premium on equity units																		—		(98		)	—				—			—				(98		)
Issuance costs of equity units																		—		(18		)	—				—			—				(18		)
Acquisition of SGG																		—		—			—				—			390				390
Benefit obligations, net of tax																		—		—			—				11			—				11
Net change in unrealized gains on investments, net of tax																		—		—			—				1			—				1
Stock-based compensation, net contributions from noncontrolling interests, and other																		357		56			(3		)		—			109				162
Balance, December 31, 2016																		179,433		$	4,030		$	5,114			$	(133	)	$	488			$	9,499
Net Income (Loss)																		—		—			1,134				—			(22		)		1,112
Dividends declared on common stock	—		—			(476		)	—			—			(476		)	—		—			(602		)		—			—				(602		)
Repurchase of common stock	(713	)	(52		)	—			—			—			(52		)	(524	)	(51		)	—				—			—				(51		)
Benefit obligations, net of tax	—		—			—			(18		)	—			(18		)	—		—			—				10			—				10
Net change in unrealized gains on investments, net of tax	—		—			—			1			—			1
Foreign currency translation									(2		)				(2		)
Stock-based compensation, distributions to noncontrolling interests, and other	617		49			(1		)	—			(24		)	24
Balance, December 31, 2014	176,991		$	3,904		$	4,578		$	(155	)	$	15		$	8,342
Net Income (Loss)	—		—			727			—			(7		)	720
Dividends declared on common stock	—		—			(510		)	—			—			(510		)
Issuance of common stock	105		9			—			—			—			9
Contribution of common stock to VEBA Trust	1,428		117			—			—			—			117
Benefit obligations, net of tax	—		—			—			13			—			13
Net change in unrealized gains on derivatives, net of tax																		—		—			—				1			—				1
Net change in unrealized gains on investments, net of tax	—		—			—			1			—			1			—		—			—				1			—				1
Foreign currency translation	—		—			—			(4		)	—			(4		)	—		—			—				1			—				1
Stock-based compensation, net contributions from noncontrolling interests, and other	946		93			(1		)	—			15			107			478		10			(3		)		—			12				19
Balance, December 31, 2015	179,470		$	4,123		$	4,794		$	(145	)	$	23		$	8,795
Balance, December 31, 2017																		179,387		$	3,989		$	5,643			$	(120	)	$	478			$	9,990

See Combined Notes to Consolidated Financial Statements

DTE Electric — Controls and Procedures

(a) Evaluation of disclosure controls and procedures

Management of DTE Electric carried out an evaluation, under the supervision and with the participation of DTE Electric’s Chief Executive Officer (CEO) and Chief Financial Officer (CFO), of the effectiveness of the design and operation of DTE Electric’s disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of December 31, ~~2015,~~2017, which is the end of the period covered by this report. Based on this evaluation, DTE Electric’s CEO and CFO have concluded that such disclosure controls and procedures are effective in providing reasonable assurance that information required to be disclosed by DTE Electric in reports that it files or submits under the Exchange Act (i) is recorded, processed, summarized, and reported within the time periods specified in the U.S. Securities and Exchange Commission's rules and forms and (ii) is accumulated and communicated to DTE Electric’s management, including its CEO and CFO, as appropriate to allow timely decisions regarding required disclosure. Due to the inherent limitations in the effectiveness of any disclosure controls and procedures, management cannot provide absolute assurance that the objectives of its disclosure controls and procedures will be attained.

(b) Management’s report on internal control over financial reporting

Management of DTE Electric is responsible for establishing and maintaining adequate internal control over financial reporting as such term is defined in Exchange Act Rules 13a-15(f) and 15d-15(f). Internal control over financial reporting is a process designed by, or under the supervision of, DTE Electric's CEO and CFO, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles.

Management of DTE Electric has assessed the effectiveness of DTE Electric’s internal control over financial reporting as of December 31, ~~2015.~~2017. In making this assessment, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (2013 COSO) in Internal Control - Integrated Framework. Based on this assessment, management concluded that, as of December 31, ~~2015,~~2017, DTE Electric’s internal control over financial reporting was effective based on those criteria.

This annual report does not include an audit report of DTE Electric’s independent registered public accounting firm regarding internal control over financial reporting. Management’s report was not subject to audit by DTE Electric’s independent registered public accounting firm pursuant to rules of the Securities and Exchange Commission that permit DTE Electric to provide only management’s report in this annual report.

There have been no changes in DTE Electric’s internal control over financial reporting during the quarter ended December 31, ~~2015~~2017 that have materially affected, or are reasonably likely to materially affect, DTE Electric’s internal control over financial reporting.

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Shareholder of

DTE Electric Company

Opinion on the Financial Statements

~~In our opinion, the consolidated financial statements listed in~~We have audited the accompanying ~~index present fairly, in all material respects, the~~consolidatedstatements of financial positionof DTE Electric Company and itssubsidiaries atas of December 31, ~~2015~~2017 and ~~2014,~~2016, and the ~~results~~related consolidated statements of ~~their~~ operations, of comprehensive income, of changes in equity and ~~their~~of cash flows for each of the three years in the period ended December 31, ~~2015~~2017, including the related notes and schedule of valuation and qualifying accounts for each of the three years in the period ended December 31, 2017 listed in the accompanying index (collectively referred to as the “consolidated financial statements”). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2017 and 2016, and the results of their operations and theircash flows for each of the three years in the period ended December 31, 2017 in conformity with accounting principles generally accepted in the United States of America. ~~In addition, in our opinion, the~~

Basis for Opinion

These consolidated financial ~~statement schedule listed in the accompanying indexpresents fairly, in all material respects, the information set forth therein when read in conjunction with the related consolidatedfinancial statements. These financial~~ statements ~~and financial statement schedule~~ are the responsibility of the ~~Company’s~~Company's management. Our responsibility is to express an opinion on ~~these~~the Company’s consolidated financial statements ~~and financial statement schedule~~ based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (“PCAOB”) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits of these consolidated financial statements in accordance with the standards of the ~~Public Company Accounting Oversight Board (United States).~~PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material ~~misstatement. An~~misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit ~~includes~~of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion.

Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence ~~supporting~~regarding the amounts and disclosures in the consolidated financial ~~statements, assessing~~statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, ~~and~~as well as evaluating the overall presentation of the consolidated financial ~~statement presentation.~~statements. We believe that our audits provide a reasonable basis for our opinion.

/s/ PricewaterhouseCoopers LLP

Detroit, Michigan

February ~~10, 2016~~16, 2018

60We have served as the Company's auditor since 2008.

DTE Electric Company

Consolidated Statements of Operations


	Year Ended December 31,									Year Ended December 31,
	2015			2014			2013			2017			2016			2015
	(In millions)									(In millions)
Operating Revenues — Utility operations	$	4,900		$	5,282		$	5,197		$	5,102		$	5,225		$	4,900

Operating Expenses
Fuel and purchased power — utility	1,574			1,706			1,668			1,454			1,532			1,574
Operation and maintenance	1,342			1,331			1,376			1,428			1,455			1,342
Depreciation and amortization	633			927			896			753			750			633
Taxes other than income	277			267			260			302			284			277
Asset (gains) losses and impairments, net	—			(1		)	(3		)
	3,826			4,230			4,197			3,937			4,021			3,826
Operating Income	1,074			1,052			1,000			1,165			1,204			1,074

Other (Income) and Deductions
Interest expense	258			250			268			274			264			258
Interest income	—			(1		)	—			—			(8		)	—
Other income	(60		)	(62		)	(54		)	(77		)	(61		)	(60		)
Other expenses	40			35			45			40			34			40
	238			222			259			237			229			238
Income Before Income Taxes	836			830			741			928			975			836

Income Tax Expense	292			298			254			327			353			292

Net Income	$	544		$	532		$	487		$	601		$	622		$	544

See Combined Notes to Consolidated Financial Statements

DTE Electric Company

Consolidated Statements of Comprehensive Income

Year Ended December 31,
2015 2014 2013
(In millions)
Net Income $ 544
$ 532
$ 487
Other comprehensive income (loss), net of tax:

Transfer of benefit obligations, net of taxes of $18 in 2015 27
—
—
Benefit obligations, net of taxes of $(4) and $4 for 2014 and 2013, respectively —
(10 ) 5
Net unrealized gains on investments during the period, net of taxes of $—, $—, and $—, respectively 1
—
1
Other comprehensive income (loss) 28

(10 )
6
Comprehensive income $ 572

$ 522

$ 493



	Year Ended December 31,
	2017		2016		2015
	(In millions)
Net Income	$	601	$	622	$	544
Other comprehensive income, net of tax:
Transfer of benefit obligations, net of taxes of $18 in 2015	—		—		27
Net unrealized gains on investments during the period, net of taxes of $1, $—, and $—, respectively	1		—		1
Other comprehensive income	1		—		28
Comprehensive Income	$	602	$	622	$	572

See Combined Notes to Consolidated Financial Statements

DTE Electric Company

Consolidated Statements of Financial Position


	December 31,						December 31,
	2015			2014			2017			2016
	(In millions)						(In millions)
ASSETS
Current Assets
Cash and cash equivalents	$	15		$	14		$	15		$	13
Restricted cash, principally Securitization	—			96
Accounts receivable (less allowance for doubtful accounts of $28 and $29, respectively)
Accounts receivable (less allowance for doubtful accounts of $31 and $25, respectively)
Customer	657			688			791			728
Affiliates	14			31			20			12
Other	40			15			37			29
Inventories
Fuel	271			269			190			225
Materials and supplies	251			231			275			271
Notes receivable
Affiliates	—			8
Other	—			8
Regulatory assets	17			46			50			36
Other	66			73			68			63
	1,331			1,479			1,446			1,377
Investments
Nuclear decommissioning trust funds	1,236			1,241			1,492			1,320
Other	35			172			36			36
	1,271			1,413			1,528			1,356
Property
Property, plant, and equipment	21,391			19,805			22,972			22,094
Less accumulated depreciation and amortization	(7,646		)	(7,216		)
Accumulated depreciation and amortization							(7,984		)	(7,721		)
	13,745			12,589			14,988			14,373
Other Assets
Regulatory assets	2,969			2,913			3,005			3,113
Securitized regulatory assets	—			34
Intangible assets	34			37			25			31
Prepaid postretirement costs — affiliates	24			—			113			114
Other	180			182			123			125
	3,207			3,166			3,266			3,383
Total Assets	$	19,554		$	18,647		$	21,228		$	20,489

See Combined Notes to Consolidated Financial Statements

DTE Electric Company

Consolidated Statements of Financial Position — (Continued)


	December 31,					December 31,
	2015		2014			2017		2016
	(In millions, except shares)					(In millions, except shares)
LIABILITIES AND SHAREHOLDER'S EQUITY
Current Liabilities
Accounts payable
Affiliates	$	40	$	60		$	52	$	58
Other	329		366			416		452
Accrued interest	62		58			72		65
Current portion long-term debt, including capital leases	157		118			5		6
Regulatory liabilities	19		150			17		27
Short-term borrowings
Affiliates	75		84			116		117
Other	272		50			238		62
Other	138		151			145		146
	1,092		1,037			1,061		933
Long-Term Debt (net of current portion)
Mortgage bonds, notes, and other	5,473		5,144			6,017		5,878
Capital lease obligations	15		—			1		7
	5,488		5,144			6,018		5,885
Other Liabilities
Deferred income taxes	3,498		3,186			2,088		3,793
Regulatory liabilities	199		245			2,137		229
Asset retirement obligations	2,020		1,796			2,125		2,012
Unamortized investment tax credit	58		36			120		90
Nuclear decommissioning	177		182			220		194
Accrued pension liability — affiliates	976		1,200			811		1,008
Accrued postretirement liability — affiliates	307		520			311		269
Other	66		105			72		81
	7,301		7,270			7,884		7,676

Commitments and Contingencies (Notes 8 and 17)	—		—
Commitments and Contingencies (Notes 9 and 18)

Shareholder's Equity
Common stock, $10 par value, 400,000,000 shares authorized, and 138,632,324 shares issued and outstanding	4,086		3,786			4,306		4,206
Retained earnings	1,585		1,436			1,956		1,787
Accumulated other comprehensive income (loss)	2		(26		)
Accumulated other comprehensive income						3		2
Total Shareholder's Equity	5,673		5,196			6,265		5,995
Total Liabilities and Shareholder's Equity	$	19,554	$	18,647		$	21,228	$	20,489

See Combined Notes to Consolidated Financial Statements

DTE Electric Company

Consolidated Statements of Cash Flows


	Year Ended December 31,
	2015			2014			2013			Year Ended December 31,
	(In millions)									2017			2016			2015
Operating Activities										(In millions)
Net Income	$	544		$	532		$	487		$	601		$	622		$	544
Adjustments to reconcile Net Income to net cash from operating activities:
Adjustments to reconcile Net Income to Net cash from operating activities:
Depreciation and amortization	633			927			896			753			750			633
Nuclear fuel amortization	46			48			38			53			58			46
Allowance for equity funds used during construction	(20		)	(21		)	(14		)	(18		)	(18		)	(20		)
Deferred income taxes	320			297			108			345			342			320
Asset (gains) losses and impairments, net	—			(1		)	(3		)
Changes in assets and liabilities:
Accounts receivable, net	33			33			(30		)	(80		)	(64		)	33
Inventories	(22		)	(97		)	36			31			26			(22		)
Prepaid postretirement benefit costs — affiliates	(24		)	—			—			1			(90		)	(24		)
Accounts payable	(46		)	11			(23		)	(2		)	59			(46		)
Accrued pension liability — affiliates	(224		)	495			(663		)	(197		)	32			(224		)
Accrued postretirement liability — affiliates	(213		)	151			(417		)	42			(38		)	(213		)
Regulatory assets and liabilities	65			(926		)	1,029			202			10			65
Other current and noncurrent assets and liabilities	58			(65		)	44			(147		)	(34		)	58
Net cash from operating activities	1,150			1,384			1,488			1,584			1,655			1,150
Investing Activities
Plant and equipment expenditures	(1,545		)	(1,561		)	(1,325		)	(1,574		)	(1,503		)	(1,545		)
Acquisitions	(310		)	—			—			—			—			(310		)
Restricted cash for debt redemption, principally Securitization, net	96			4			2			—			—			96
Notes receivable — affiliate	8			192			(200		)
Proceeds from sale of nuclear decommissioning trust fund assets	885			1,146			1,118			1,240			1,457			885
Investment in nuclear decommissioning trust funds	(898		)	(1,156		)	(1,134		)	(1,226		)	(1,463		)	(898		)
Transfer of Rabbi Trust assets to affiliate	137			—			—			—			—			137
Other	6			(14		)	(33		)	18			36			14
Net cash used for investing activities	(1,621		)	(1,389		)	(1,572		)	(1,542		)	(1,473		)	(1,621		)
Financing Activities
Issuance of long-term debt, net of issuance costs	495			942			768			435			355			495
Redemption of long-term debt	(135		)	(837		)	(590		)	(300		)	(10		)	(135		)
Repurchase of long-term debt										—			(59		)	—
Capital contribution by parent company	300			190			400			100			120			300
Short-term borrowings, net — affiliate										(1		)	41			(8		)
Short-term borrowings, net — other	222			50			(130		)	176			(210		)	222
Short-term borrowings, net — affiliate	(8		)	26			(22		)
Dividends on common stock	(395		)	(370		)	(342		)	(432		)	(420		)	(395		)
Other	(7		)	(9		)	(3		)	(18		)	(1		)	(7		)
Net cash from (used for) financing activities	472			(8		)	81			(40		)	(184		)	472
Net Increase (Decrease) in Cash and Cash Equivalents	1			(13		)	(3		)	2			(2		)	1
Cash and Cash Equivalents at Beginning of Period	14			27			30			13			15			14
Cash and Cash Equivalents at End of Period	$	15		$	14		$	27		$	15		$	13		$	15

Supplemental disclosure of cash information
Cash paid (received) for:
Interest, net of interest capitalized	$	244		$	240		$	256		$	252		$	252		$	244
Income taxes	$	(53	)	$	4		$	183		$	(16	)	$	6		$	(53	)
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	$	150		$	162		$	231		$	191		$	232		$	150

See Combined Notes to Consolidated Financial Statements

DTE Electric Company

Consolidated Statements of Changes in Shareholder's Equity


									Accumulated									Additional Paid-in Capital			Retained Earnings				Accumulated Other Comprehensive Income (Loss)
				Additional					Other						Common Stock
	Common Stock			Paid in		Retained			Comprehensive						Shares	Amount				Total
	Shares	Amount		Capital		Earnings			Income (Loss)			Total			(Dollars in millions, shares in thousands)
	(Dollars in millions, shares in thousands)
Balance, December 31, 2012	138,632	$	1,386	$	1,810	$	1,129		$	(22	)	$	4,303
Net Income	—	—		—		487			—			487
Dividends declared on common stock	—	—		—		(342		)	—			(342		)
Benefit obligations, net of tax	—	—		—		—			5			5
Net change in unrealized gains on investments, net of tax	—	—		—		—			1			1
Capital contribution by parent company	—	—		400		—			—			400
Balance, December 31, 2013	138,632	$	1,386	$	2,210	$	1,274		$	(16	)	$	4,854
Net Income	—	—		—		532			—			532
Dividends declared on common stock	—	—		—		(370		)	—			(370		)
Benefit obligations, net of tax	—	—		—		—			(10		)	(10		)
Capital contribution by parent company	—	—		190		—			—			190
Balance, December 31, 2014	138,632	$	1,386	$	2,400	$	1,436		$	(26	)	$	5,196		138,632	$	1,386			$			2,400			$	1,436		$	(26	)		$	5,196
Net Income	—	—		—		544			—			544			—	—				—					544			—				544
Dividends declared on common stock	—	—		—		(395		)	—			(395		)	—	—		—				(395		)		—			(395		)
Transfer of benefit obligations, net of tax	—	—		—		—			27			27			—	—		—			—				27			27
Net change in unrealized gains on investments, net of tax	—	—		—		—			1			1			—	—		—			—				1			1
Capital contribution by parent company	—	—		300		—			—			300			—	—		300			—				—			300
Balance, December 31, 2015	138,632	$	1,386	$	2,700	$	1,585		$	2		$	5,673		138,632	$	1,386	$	2,700		$	1,585			$	2		$	5,673
Net Income															—	—		—			622				—			622
Dividends declared on common stock															—	—		—			(420		)		—			(420		)
Capital contribution by parent company															—	—		120			—				—			120
Balance, December 31, 2016															138,632	$	1,386	$	2,820		$	1,787			$	2		$	5,995
Net Income															—	—		—			601				—			601
Dividends declared on common stock															—	—		—			(432		)		—			(432		)
Net change in unrealized gains on investments, net of tax															—	—		—			—				1			1
Capital contribution by parent company															—	—		100			—				—			100
Balance, December 31, 2017															138,632	$	1,386	$	2,920		$	1,956			$	3		$	6,265

See Combined Notes to Consolidated Financial Statements

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements

Index of Combined Notes to Consolidated Financial Statements

The Combined Notes to Consolidated Financial Statements are a combined presentation for DTE Energy and DTE Electric. The following list indicates the Registrant(s) to which each note applies:



Note 1	Organization and Basis of Presentation	DTE Energy and DTE Electric
Note 2	Significant Accounting Policies	DTE Energy and DTE Electric
Note 3	New Accounting Pronouncements	DTE Energy and DTE Electric
Note 4	Acquisitions and Exit Activities	DTE Energy ~~and DTE Electric~~
Note 5	Goodwill	DTE Energy
Note 6	Property, Plant, and Equipment	DTE Energy and DTE Electric
Note 67	Jointly-Owned Utility Plant	DTE Energy and DTE Electric
Note 78	Asset Retirement Obligations	DTE Energy and DTE Electric
Note 89	Regulatory Matters	DTE Energy and DTE Electric
Note 910	Income Taxes	DTE Energy and DTE Electric
Note 1011	Earnings Per Share	DTE Energy
Note 1112	Fair Value	DTE Energy and DTE Electric
Note 1213	Financial and Other Derivative Instruments	DTE Energy and DTE Electric
Note 1314	Long-Term Debt	DTE Energy and DTE Electric
Note 1415	Preferred and Preference Securities	DTE Energy and DTE Electric
Note 1516	Short-Term Credit Arrangements and Borrowings	DTE Energy and DTE Electric
Note 1617	Capital and Operating Leases	DTE Energy and DTE Electric
Note 1718	Commitments and Contingencies	DTE Energy and DTE Electric
Note 1819	Nuclear Operations	DTE Energy and DTE Electric
Note 20	Retirement Benefits and Trusteed Assets	DTE Energy and DTE Electric
Note 1921	Stock-Based Compensation	DTE Energy and DTE Electric
Note 2022	Segment and Related Information	DTE Energy
Note 2123	Related Party Transactions	DTE Electric
Note 2224	Supplementary Quarterly Financial Information (Unaudited)	DTE Energy and DTE Electric

NOTE 1 — ORGANIZATION AND BASIS OF PRESENTATION

Corporate Structure

DTE Energy owns the following businesses:

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

DTE Gas is a public ~~gas~~ utility engaged in the purchase, storage, transportation, distribution, and sale of natural gas to approximately ~~1.2~~1.3 million customers throughout Michigan and the sale of storage and transportation capacity; and

Other businesses involved in 1) natural gas pipelines, gathering, and storage; 2) power and industrial projects; and 3) energy marketing and trading operations.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

Basis of Presentation

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

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

Certain prior year balances for the Registrants were reclassified to match the current year's Consolidated Financial Statements presentation. Such revisions include amounts reclassified to separate Operating Revenues and Fuel, purchased power, and gas between Utility operations and Non-utility operations and from Operations and maintenance to Fuel, purchased power, and gas — non-utility related to the Power and Industrial Projects segment. The reclassifications did not affect DTE Energy's Net Income for the prior periods, as such, they are not deemed material to the previously issued Consolidated Financial Statements. For reclassifications of deferred tax assets and liabilities arising from ASU 2015-17 see Note 3 to the Consolidated Financial Statements, "New Accounting Pronouncements".

Principles of Consolidation

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

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

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

DTE Energy owns a 55% interest in SGG, which owns and operates midstream natural gas assets. SGG has contracts through which certain construction risk is designed to pass-through to the customers, with DTE Energy retaining operational and customer default risk. SGG is a VIE with DTE Energy as the primary beneficiary. See Note 4 to the Consolidated Financial Statements, "Acquisitions and Exit Activities," for more information.

The Registrants hold variable interests in NEXUS, including a 50% ownership interest. 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 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 Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

DTE Energy has variable interests in VIEs through certain of its long-term purchase and sale contracts. DTE Electric has variable interests in VIEs through certain of its long-term purchase contracts. As of December 31, ~~2015,~~2017, the carrying amount of assets and liabilities in DTE Energy's Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase and sale contracts are predominantly related to working capital accounts and generally represent the amounts owed by or to DTE Energy for the deliveries associated with the current billing cycle under the contracts. As of December 31, ~~2015,~~2017, the carrying amount of assets and liabilities in DTE Electric's Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase contracts are predominantly related to working capital accounts and generally represent the amounts owed by DTE Electric for the deliveries associated with the current billing cycle under the contracts. The Registrants have not provided any significant form of financial support associated with these long-term contracts. There is no significant potential exposure to loss as a result of DTE Energy's variable interests through these long-term purchase and sale contracts. In addition, there is no significant potential exposure to loss as a result of DTE Electric's variable interests through these long-term purchase contracts.

~~DTE Energy Company — DTE Electric Company~~

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

In 2001, DTE Electric financed a regulatory asset related to Fermi 2 and certain other regulatory assets through the sale of rate reduction bonds by a wholly-owned special purpose entity, Securitization. DTE Electric performed servicing activities including billing and collecting surcharge revenue for Securitization. The remaining amounts due on the rate reduction bonds were paid in March 2015. The associated regulatory assets were fully amortized by March 31, 2015. Subsequent to the pay-down of the bonds, Securitization is no longer a VIE but continues to be consolidated by the Registrants as a voting interest entity.

The maximum risk exposure for consolidated VIEs is reflected on the Registrants' Consolidated Statements of Financial ~~Position.~~Position and in Note 18 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 ~~its~~their investment, notes receivable, future funding commitments, and amounts which itDTE Energy has guaranteed. See Note 18 to the Consolidated Financial Statements, "Commitments and Contingencies," for further discussion of the NEXUS guarantee arrangements.

The following table summarizes the major Consolidated Statements of Financial Position items for consolidated VIEs as of December 31, ~~2015~~2017 and ~~2014.~~2016. All assets and liabilities of a consolidated VIE are presented where it has been determined that a consolidated VIE has either (1) assets that can be used only to settle obligations of the VIE or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary. ~~Securitization, included in the DTE Energy table below for December 31, 2014, also relates to DTE Electric.~~ 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.


	December 31, 2015		December 31, 2014						December 31, 2017						December 31, 2016
	Total		Securitization		Other		Total		SGG^(a)		Other		Total		SGG^(a)		Other		Total
	(In millions)								(In millions)
ASSETS
Cash and cash equivalents	$	14	$	—	$	7	$	7	$	23	$	14	$	37	$	36	$	27	$	63
Restricted cash	8		96		8		104		—		8		8		—		7		7
Accounts receivable	18		26		15		41		11		42		53		8		34		42
Inventories	82		—		67		67		3		114		117		3		112		115
Property, plant, and equipment, net	66		—		81		81		400		75		475		398		76		474
Securitized regulatory assets	—		34		—		34
Goodwill									25		—		25		17		—		17
Intangible assets									572		—		572		586		—		586
Other current and long-term assets	4		1		6		7		4		—		4		1		1		2
	$	192	$	157	$	184	$	341	$	1,038	$	253	$	1,291	$	1,049	$	257	$	1,306

LIABILITIES
Accounts payable and accrued current liabilities	$	13	$	3	$	8	$	11	$	26	$	47	$	73	$	19	$	32	$	51
Current portion long-term debt, including capital leases	8		105		10		115		—		4		4		—		5		5
Current regulatory liabilities	—		32		—		32
Mortgage bonds, notes, and other	10		—		15		15		—		1		1		—		5		5
Capital lease obligations	—		—		3		3
Other current and long-term liabilities	6		9		6		15		1		16		17		2		15		17
	$	37	$	149	$	42	$	191	$	27	$	68	$	95	$	21	$	57	$	78


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

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

Amounts for DTE Energy's non-consolidated VIEs ~~as of December 31, 2015 and 2014~~ are as follows:


	December 31, 2015		December 31, 2014		December 31, 2017		December 31, 2016
	(In millions)				(In millions)
Investment in equity method investees	$	136	$	134
Investments in equity method investees					$	811	$	509
Notes receivable	$	15	$	15	$	17	$	15
Future funding commitments					$	598	$	692

Equity Method Investments

Investments in non-consolidated affiliates that are not controlled by the Registrants, but over which they have significant influence, are accounted for using the equity method. Certain of the equity method investees are also considered VIEs and disclosed in the non-consolidated VIEs table above. At December 31, ~~2015~~2017 and ~~2014,~~2016, DTE Energy's share of the underlying equity in the net assets of the investees exceeded the carrying amounts of Investments in equity method investees by ~~$81~~$72 million and $73 million, respectively. The difference is being amortized over the life of the underlying assets.

DTE Energy ~~Company — DTE Electric Company~~

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

~~Equity~~equity method investees are described below:


	Investments				% Owned			Investments				% Owned
Segment	2015		2014		2015	2014	Description	2017		2016		2017	2016	Description
	(In millions)							(In millions)
Significant Equity Method Investees
Gas Storage and Pipelines
NEXUS Pipeline	$	89	$	16	50%	50%	A proposed 255-mile pipeline to transport Utica and Marcellus shale gas to Ohio, Michigan, and Ontario market centers	$	640	$	322	50%	50%	A 255-mile pipeline under construction to transport Utica and Marcellus shale gas to Ohio, Michigan, and Ontario market centers
Vector Pipeline	96		98		40%	40%	348-mile pipeline connecting Chicago, Michigan, and Ontario market centers	115		100		40%	40%	348-mile pipeline connecting Chicago, Michigan, and Ontario market centers
Millennium Pipeline	111		110		26%	26%	182-mile pipeline serving markets in the Northeast	124		116		26%	26%	251-mile pipeline serving markets in the Northeast
	$	296	$	224				879		538
Other Equity Method Investees
Other Segments	218		210					194		214
	$	514	$	434				$	1,073	$	752

The ~~balance~~balances in Other Equity Method Investees are individually insignificant and are primarily from the Power and Industrial Projects segment. These investments are comprised of projects that deliver energy and utility-type products and services to an industrial customer, sell electricity from renewable energy projects under long-term power purchase agreements, and produce and sell metallurgical coke.

For further information by segment, see Note 2022 to the Consolidated Financial Statements, "Segment and Related ~~Information".~~Information."

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

NOTE 2 — SIGNIFICANT ACCOUNTING POLICIES

Revenues

The Registrants' revenues from the sale and delivery of electricity, and DTE Energy's revenues from the sale, delivery, and storage of natural gas are recognized as services are provided. DTE Electric and DTE Gas record revenues for electricity and gas provided but unbilled at the end of each month. 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 further discussion of recovery mechanisms authorized by the MPSC, see Note 89 to the Consolidated Financial Statements, "Regulatory ~~Matters".~~Matters."

DTE Energy's non-utility businesses recognize revenues as services are provided and products are delivered. For discussion of derivative contracts, see Note 1213 to the Consolidated Financial Statements, "Financial and Other Derivative ~~Instruments".~~Instruments."

~~DTE Energy Company — DTE Electric Company~~

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

Other Income

Other income for the Registrants is recognized for non-operating income such as equity earnings of equity method investees, allowance for equity funds used during construction, contract services, and ~~contract services.~~gains (losses) from trading securities. DTE Energy's Power and Industrial Projects segment also recognizes Other income in connection with the sale of membership interests in reduced emissions fuel facilities to investors. In exchange for the cash received, the investors will receive a portion of the economic attributes of the facilities, including income tax attributes. The transactions are not treated as a sale of membership interests for financial reporting purposes. Other income is considered earned when refined coal is produced and tax credits are generated. ~~Power and Industrial Projects recognized approximately $83 million, $78 million, and $81 million~~

The following is a summary of DTE Energy's Other ~~income for the years ended December 31, 2015, 2014, and 2013, respectively.~~income:



	2017		2016		2015
	(In millions)
Equity earnings of equity method investees	$	102	$	68	$	66
Income from REF entities	77		75		83
Gains from trading securities	26		15		1
Allowance for equity funds used during construction	23		21		21
Contract services	19		21		27
Other	21		7		11
	$	268	$	207	$	209

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



	2017		2016		2015
	(In millions)
Gains from trading securities allocated from DTE Energy	$	26	$	15	$	1
Contract services	21		20		27
Allowance for equity funds used during construction	18		18		20
Equity earnings of equity method investees	1		2		2
Other	11		6		10
	$	77	$	61	$	60

For information on equity earnings of equity method investees by segment, see Note 2022 to the Consolidated Financial Statements, "Segment and Related ~~Information".~~Information."

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

Accounting for ISO Transactions

DTE Electric participates in the energy market through MISO. MISO requires that DTE Electric submit hourly day-ahead, real-time, and FTR bids and offers for energy at locations across the MISO region. DTE Electric accounts for MISO transactions on a net hourly basis in each of the day-ahead, real-time, and FTR markets and net transactions across all MISO energy market locations. In any single hour DTE Electric records net purchases in Fuel, purchased power, and gas — utility and net sales in Operating Revenues — Utility operations on the Registrants' Consolidated Statements of Operations.

The Energy Trading segment participates in the energy markets through various ~~independent system operators~~ISOs and ~~regional transmission organizations (ISOs and RTOs).~~RTOs. These markets require that Energy Trading submits hourly day-ahead, real-time bids and offers for energy at locations across each region. Energy Trading submits bids in the annual and monthly auction revenue rights and FTR auctions to the ~~regional transmission organizations.~~RTOs. Energy Trading accounts for these transactions on a net hourly basis for the day-ahead, real-time, and FTR markets. These transactions are related to trading contracts which, if derivatives, are presented on a net basis in Operating Revenues — Non-utility operations, and if non-derivatives, the realized gains and losses for sales are recorded in Operating Revenues — Non-utility operations and purchases are recorded in Fuel, purchased power, and gas — non-utility in the DTE Energy Consolidated Statements of Operations.

DTE Electric and Energy Trading record accruals for future net purchases adjustments based on historical experience, and reconcile accruals to actual costs when invoices are received from MISO and other ISOs and RTOs.

Changes in Accumulated Other Comprehensive Income (Loss)

Comprehensive income (loss) is the change in common shareholders’ equity during a period from transactions and events from non-owner sources, including Net Income. The amounts recorded to Accumulated other comprehensive income (loss) for the Registrants include unrealized gains and losses on available-for-sale securities and changes in benefit obligations, consisting of deferred actuarial losses and prior service costs. The amounts recorded to Accumulated other comprehensive income (loss) relating solely to DTE Energy also include unrealized gains and losses from derivatives accounted for as cash flow hedges, DTE Energy's interest in other comprehensive income of equity investees which comprise the net unrealized gains and losses on investments, and foreign currency translation adjustments. Refer to Note 1820 to the Consolidated Financial Statements, "Retirement Benefits and Trusteed ~~Assets",~~Assets," regarding the transfer of a portion of DTE Electric benefit obligations ~~during the year.~~

in 2015.

~~DTE Energy Company — DTE Electric Company~~

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

The following table summarizes the changes in DTE Energy's Accumulated other comprehensive income (loss) by component^(a) for the years ended December 31, ~~2015~~2017 and ~~2014:~~2016:


	Changes in Accumulated Other Comprehensive Income (Loss) by Component (a)															Net Unrealized Gain (Loss) on Derivatives			Net Unrealized Gain (Loss) on Investments			Benefit Obligations^(b)			Foreign Currency Translation			Total
	Net Unrealized Loss on Derivatives			Net Unrealized Gain/(Loss) on Investments			Benefit Obligations (b)			Foreign Currency Translation			Total			(In millions)
	(In millions)
Balance, December 31, 2013	$	(4	)	$	(6	)	$	(126	)	$	—		$	(136	)
Balance, December 31, 2015																$	(4	)	$	(4	)	$	(131	)	$	(6	)	$	(145	)
Other comprehensive loss before reclassifications																—			—			(3		)	—			(3		)
Amounts reclassified from Accumulated other comprehensive income																—			1			14			—			15
Net current-period Other comprehensive income																—			1			11			—			12
Balance, December 31, 2016																$	(4	)	$	(3	)	$	(120	)	$	(6	)	$	(133	)
Other comprehensive income (loss) before reclassifications	—			1			(25		)	(2		)	(26		)	—			1			(3		)	1			(1		)
Amounts reclassified from Accumulated other comprehensive income	—			—			7			—			7			1			—			13			—			14
Net current-period Other comprehensive income (loss)	—			1			(18		)	(2		)	(19		)
Balance, December 31, 2014	$	(4	)	$	(5	)	$	(144	)	$	(2	)	$	(155	)
Other comprehensive income (loss) before reclassifications	—			1			2			(4		)	(1		)
Amounts reclassified from Accumulated other comprehensive income	—			—			11			—			11
Net current-period Other comprehensive income (loss)	—			1			13			(4		)	10
Balance, December 31, 2015	$	(4	)	$	(4	)	$	(131	)	$	(6	)	$	(145	)
Net current-period Other comprehensive income																1			1			10			1			13
Balance, December 31, 2017																$	(3	)	$	(2	)	$	(110	)	$	(5	)	$	(120	)

~~(a)All amounts are net of tax, except for Foreign currency translation.~~


(a)	All amounts are net of tax, except for Foreign currency translation.


(b)	The amounts reclassified from Accumulated other comprehensive income (loss) are included in the computation of the net periodic pension and other postretirement benefit costs (see Note 1820 to the Consolidated Financial Statements "Retirement Benefits and Trusteed Assets").

~~The following table summarizes the changes in~~

DTE ~~Electric's Accumulated other comprehensive income (loss) by component for the years ended December 31, 2015 and 2014:~~Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

Changes in Accumulated Other Comprehensive Income (Loss) by Component (a)
Net Unrealized Gain on Investments Benefit Obligations (b) Total
(In millions)
Balance, December 31, 2013 $ 1
$ (17 ) $ (16 )
Other comprehensive loss before reclassifications —
(12 ) (12 )
Amounts reclassified from Accumulated other comprehensive income —
2
2
Net current-period Other comprehensive loss —
(10 ) (10 )
Balance, December 31, 2014 $ 1
$ (27 ) $ (26 )
Other comprehensive income before reclassifications 1
—
1
Transfer of amounts from Accumulated other comprehensive income to affiliate —
27
27
Amounts reclassified from Accumulated other comprehensive income —
—
—
Net current-period Other comprehensive income 1
27
28
Balance, December 31, 2015 $ 2
$ —
$ 2

~~(a)All amounts are net of tax.~~


~~(b)~~	The amounts reclassified from Accumulated other comprehensive income (loss) are included in the computation of the net periodic pension and other postretirement benefit costs (see Note 18 to the Consolidated Financial Statements "Retirement Benefits and Trusteed Assets").

Cash, Cash Equivalents, and Restricted Cash

Cash and cash equivalents include cash on hand, cash in banks, and temporary investments purchased with remaining maturities of three months or less. Restricted cash consists of funds held 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.

~~DTE Energy Company — DTE Electric Company~~

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

Receivables

Accounts receivable are primarily composed of trade receivables and unbilled revenue. The Registrants' Accounts receivable are stated at net realizable value.

The allowance for doubtful accounts for DTE Electric and DTE Gas is generally calculated using the aging approach that utilizes rates developed in reserve studies. DTE Electric and DTE Gas establish an allowance for uncollectible accounts based on historical losses and management’s assessment of existing economic conditions, customer trends, and other factors. Customer accounts are generally considered delinquent if the amount billed is not received by the due date, which is typically in 21 days, however, factors such as assistance programs may delay aggressive action. DTE Electric and DTE Gas assess late payment fees on trade receivables based on past-due terms with customers. Customer accounts are written off when collection efforts have been exhausted. The time period for write-off is 150 days after service has been terminated.

The customer allowance for doubtful accounts for DTE Energy's other businesses is calculated based on specific review of probable future collections based on receivable balances generally in excess of 30 days.

DTE Energy unbilled revenues of ~~$620~~$1 billion and $814 million, including $290 million and ~~$773 million, including $237 million and $250~~$267 million of DTE Electric unbilled revenues, are included in Customer Accounts receivable at December 31, ~~2015~~2017 and ~~2014,~~2016, respectively.

Notes Receivable

Notes receivable, or financing receivables, for DTE Energy are primarily comprised of capital lease receivables and loans and are included in Notes receivable and Other current assets on DTE Energy’s Consolidated Statements of Financial Position. Notes receivable, or financing receivables, for DTE Electric are primarily comprised of loans.

Notes receivable are typically considered delinquent when payment is not received for periods ranging from 60 to 120 days. The Registrants cease accruing interest (nonaccrual status), consider a note receivable impaired, and establish an allowance for credit loss when it is probable that all principal and interest amounts due will not be collected in accordance with the contractual terms of the note receivable. Cash payments received on nonaccrual status notes receivable, that do not bring the account contractually current, are first applied to contractually owed past due interest, with any remainder applied to principal. Accrual of interest is generally resumed when the note receivable becomes contractually current.

In determining the allowance for credit losses for notes receivable, the Registrants consider the historical payment experience and other factors that are expected to have a specific impact on the counterparty’s ability to pay. In addition, the Registrants monitor the credit ratings of the counterparties from which they have ~~Notes~~notes receivable.

Inventories

Inventory related to utility operations is generally valued at average cost. Inventory related to non-utility operations is valued at the lower of cost or ~~market.~~net realizable value.

DTE Gas' natural gas inventory of ~~$65~~$29 million and ~~$43~~$45 million as of December 31, ~~2015~~2017 and ~~2014,~~2016, respectively, is determined using the last-in, first-out (LIFO) method. The replacement cost of gas ~~remaining~~ in ~~storage~~inventory exceeded the LIFO cost by ~~$60~~$81 million and ~~$110~~$132 million at December 31, ~~2015~~2017 and ~~2014,~~2016, respectively.

Property, Retirement and Maintenance, and Depreciation and Amortization

Property is stated at cost and includes construction-related labor, materials, overheads, and AFUDC for utility property. The cost of utility properties retired is charged to accumulated depreciation. Expenditures for maintenance and repairs are charged to expense when incurred, except for outage-related maintenance repairs for Fermi 2.

Utility property at DTE Electric and DTE Gas is depreciated over its estimated useful life using straight-line rates approved by the MPSC.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

DTE Energy's non-utility property is depreciated over its estimated useful life using the straight-line method.

Depreciation and amortization expense also includes the amortization of certain regulatory assets for the Registrants.

~~DTE Energy Company — DTE Electric Company~~

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

Approximately $4$15 million and ~~$16~~$27 million of expenses related to Fermi 2 refueling outages were accrued at December 31, ~~2015~~2017 and ~~2014,~~2016, respectively. Amounts are accrued on a pro-rata basis, generally over an 18-month period, that coincides with scheduled refueling outages at Fermi 2. This accrual of outage costs matches the regulatory recovery of these costs in rates set by the MPSC. See Note 89 to the Consolidated Financial Statements, "Regulatory ~~Matters".~~Matters."

The cost of nuclear fuel is capitalized. The amortization of nuclear fuel is included within Fuel, purchased power, and gas — utility in the DTE Energy Consolidated Statements of Operations, and Fuel and purchased power in the DTE Electric Consolidated Statements of Operations, and is recorded using the units-of-production method.

See Note 6 to the Consolidated Financial Statements, "Property, Plant, and Equipment."

Long-Lived Assets

Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of an asset may not be recoverable. If the carrying amount of the asset exceeds the expected ~~discounted~~undiscounted future cash flows generated by the asset, an impairment loss is recognized resulting in the asset being written down to its estimated fair value. Assets to be disposed of are reported at the lower of the carrying amount or fair value, less costs to sell.

Intangible Assets

~~DTE Energy has~~The Registrants have certain Intangible assets as shown below:

December 31,
2015 2014
(In millions)
Emission allowances $ 1
$ 1
Renewable energy credits 38
45
Contract intangible assets 117
122
156
168
Less accumulated amortization 62
57
Intangible assets, net 94
111
Less current intangible assets 5
9
$ 89
$ 102



		December 31, 2017							December 31, 2016
	Useful Lives	Gross Carrying Value		Accumulated Amortization			Net Carrying Value		Gross Carrying Value		Accumulated Amortization			Net Carrying Value
		(In millions)
Intangible assets subject to amortization
Customer relationships^(a)	40 years^(b)	$	770	$	(24	)	$	746	$	770	$	(5	)	$	765
Contract intangibles	6 to 26 years	168		(72		)	96		111		(65		)	46
		938		(96		)	842		881		(70		)	811

DTE Electric renewable energy credits	(c)	24		—			24		30		—			30
DTE Electric emission allowances	(c)	1		—			1		1		—			1
		25		—			25		31		—			31
Long-term intangible assets
DTE Electric		$	25	$	—		$	25	$	31	$	—		$	31
DTE Energy		$	963	$	(96	)	$	867	$	912	$	(70	)	$	842


(a)	In October 2016, DTE Energy acquired midstream natural gas assets that are part of the Gas Storage and Pipelines segment. The intangible assets recorded as a result of the acquisition pertain to existing customer relationships. See Note 4 to the Consolidated Financial Statements, "Acquisitions and Exit Activities," for additional information.


(b)	The useful life of the customer relationship intangible assets is based on the number of years in which the assets are expected to economically contribute to the business. The expected economic benefit incorporates existing customer contracts and expected renewal rates based on the estimated volume and production lives of gas resources in the region.


(c)	Emission allowances and renewable energy credits are charged to expense, using average cost, as the allowances and credits are consumed in the operation of the business.

The following table summarizes DTE ~~Electric has certain Intangible assets as shown below:~~Energy's estimated customer relationship and contract intangible amortization expense expected to be recognized during each year through 2022:

December 31,
2015 2014
(In millions)
Emission allowances $ 1
$ 1
Renewable energy credits 38
45
39
46
Less current intangible assets 5
9
$ 34
$ 37



	2018		2019		2020		2021		2022
	(In millions)
Estimated amortization expense	$	26	$	26	$	25	$	25	$	25

Emission allowances and renewable energy credits are charged to expense, using average cost, as the allowances and credits are consumed in the operation of the businesses by the Registrants. DTE Energy amortizes contract Intangible assets on a straight-line basis over the expected period of benefit, ranging from 1 to 26 years. DTE Energy's Intangible assets amortization expense was $11 million in 2015, $12 million in 2014, and $14 million in 2013.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

~~The following table summarizes~~DTE Energy amortizes customer relationship and contract intangible assets on a straight-line basis over the expected period of benefit. DTE Energy's ~~estimated contract intangible~~Intangible assets amortization expense ~~expected to be recognized during each year through 2020:~~

Estimated amortization expense (In millions)
2016 $ 10
2017 $ 7
2018 $ 7
2019 $ 7
2020 $ 5
was $29 million in 2017, $16 million in 2016, and $11 million in 2015.

Excise and Sales Taxes

The Registrants record the billing of excise and sales taxes as a receivable with an offsetting payable to the applicable taxing authority, with no net impact on the ~~Registrants'~~Registrants’ Consolidated Statements of Operations.

Deferred Debt Costs

The costs related to the issuance of long-term debt are deferred and amortized over the life of each debt issue. The deferred amounts are included as a direct deduction from the carrying amount of each debt issue in ~~Other long-term assets~~Mortgage bonds, notes, and other and Junior subordinated debentures on ~~the Registrant's~~DTE Energy's Consolidated Statements of Financial Position and in Mortgage bonds, notes, and other on DTE Electric's Consolidated Statements of Financial Position. In accordance with MPSC regulations applicable to DTE Energy’s electric and gas utilities, the unamortized discount, premium, and expense related to utility debt redeemed with a refinancing are amortized over the life of the replacement issue. Discount, premium, and expense on early redemptions of debt associated with DTE Energy's non-utility operations are charged to earnings.

Investments in Debt and Equity Securities

The Registrants generally classify investments in debt and equity securities as either trading or available-for-sale and have recorded such investments at market value with unrealized gains or losses included in earnings or in Other comprehensive income or loss, respectively. Changes in the fair value of Fermi 2 nuclear decommissioning investments are recorded as adjustments to Regulatory assets or liabilities, due to a recovery mechanism from customers. The Registrants' equity investments are reviewed for impairment each reporting period. If the assessment indicates that the impairment is other than temporary, a loss is recognized resulting in the equity investment being written down to its estimated fair value. See Note 1112 of the Consolidated Financial Statements, "Fair ~~Value".~~Value."

Government Grants

Grants are recognized when there is reasonable assurance that the grant will be received and that any conditions associated with the grant will be met. When grants are received related to Property, plant, and equipment, the Registrants reduce the cost of the assets on their Consolidated Statements of Financial Position, resulting in lower depreciation expense over the life of the associated asset. Grants received related to expenses are reflected as a reduction of the associated expense in the period in which the expense is incurred.

DTE Energy Foundation

DTE Energy's charitable contributions to the DTE Energy Foundation were ~~$12~~$43 million, ~~$25~~$26 million, and ~~$18~~$12 million for the years ended December 31, ~~2015, 2014,~~2017, 2016, and ~~2013,~~2015, respectively. The DTE Energy Foundation is a non-consolidated not-for-profit private foundation, the purpose of which is to contribute to and assist charitable organizations.

~~DTE Energy Company — DTE Electric Company~~

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

Other Accounting Policies

See the following notes for other accounting policies impacting the Registrants’ Consolidated Financial Statements:



Note		Title
78		Asset Retirement Obligations
89		Regulatory Matters
910		Income Taxes
1112		Fair Value
1213		Financial and Other Derivative Instruments
1920		Retirement Benefits and Trusteed Assets
21		Stock-Based Compensation

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

NOTE 3 — NEW ACCOUNTING PRONOUNCEMENTS

Recently Issued Pronouncements

In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with ~~Customers.~~Customers (Topic 606), as amended. The objectives of this ASU are to improve upon revenue recognition requirements by providing a single comprehensive model to determine the measurement of revenue and timing of recognition. The core principle is that an entity will recognize revenue to depict the transfer of goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services. This ASU also requires expanded qualitative and quantitative disclosures regarding the nature, amount, timing, and uncertainty of revenues and cash flows arising from contracts with customers. ~~In July 2015, the FASB deferred implementation of the revenue standard to be effective for the first interim period within annual reporting periods beginning after December 15, 2017.~~ The standard is to be applied ~~retrospectively~~retrospectively. The Registrants will adopt the standard effective January 1, 2018 using the modified retrospective approach. The Registrants have substantially completed the assessment of the amended ASU's impact, on their Consolidated Financial Statements. The ASU will not significantly affect the Registrants' financial position or results of operations. The Registrants will continue to monitor the impact of the ASU on existing revenue recognition internal controls, policies, and procedures. Industry-related issues being vetted through the final stages of the American Institute of Certified Public Accountants' Power and Utilities Industry Task Force process, which are not expected to have a significant impact on the Registrants, will continue to be monitored. The ASU will result in additional disclosures for revenue compared to the current guidance. Accordingly, the Registrants are evaluating information that would be useful for users of the Consolidated Financial Statements.

In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842), a replacement of Leases (Topic 840). This guidance requires a lessee to account for leases as finance or operating leases, and include disclosure of 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. For lessors, the standard modifies the classification criteria and the accounting for sales-type and direct financing leases. Entities will classify leases to determine how to recognize lease-related revenue and expense. This standard is effective for public entities for fiscal years, and interim periods within those years, beginning after December 15, 2018, and early adoption is ~~permitted~~permitted. The Registrants do not plan to early adopt the standard. A modified retrospective approach is required for leases existing or entered into after the beginning of the earliest comparative period in the ~~preceding year.~~Consolidated Financial Statements, with certain practical expedients permitted. The Registrants expect an increase in assets and liabilities, as well as additional disclosures, however, they are currently assessing the impact of this ASU on their Consolidated Financial Statements. This assessment includes monitoring unresolved utility industry implementation guidance. The Registrants have conducted outreach activities across their lines of business and have begun implementation of a third-party software tool that will assist with the initial adoption and ongoing compliance.

In ~~February 2015,~~June 2016, the FASB issued ASU No. ~~2015-02,~~ 2016-13,~~Amendments~~ 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 ~~Consolidation Analysis~~,new guidance as a cumulative-effect adjustment to retained earnings as of the beginning of the first reporting period in which ~~changes~~ the ~~analysis that a reporting entity must perform to determine whether it should consolidate certain types of legal entities.~~guidance is adopted. The ASU affects (1) limited partnerships and similar legal entities, (2) evaluating fees paid to a decision maker or a service provider as a variable interest, (3) the effect of fee arrangements on the primary beneficiary determination, (4) the effect of related parties on the primary beneficiary determination, and (5) certain investment funds. It is effective for the Registrants ~~for the first interim period within annual reporting periods~~ beginning after December 15, ~~2015~~2019, and ~~early~~interim periods therein. Early adoption is permitted. The Registrants are currently assessing the impact of this ~~ASU~~standard on their Consolidated Financial Statements.

In ~~April 2015,~~March 2017, the FASB issued ASU No. ~~2015-03,~~2017-07, ~~Simplifying~~Compensation — Retirement Benefits (Topic 715): Improving the Presentation of ~~Debt Issuance Costs~~Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. ~~. This ASU requires~~The amendments in this update require that ~~debt issuance~~an employer report the service cost component in the same line item or items as other compensation costs ~~related~~arising from services rendered by the pertinent employees during the period. The other components of net benefit cost are required to ~~a recognized debt liability~~ be presented in the ~~balance sheet as a direct deduction~~income statement separately from the ~~carrying amount~~service cost component and outside income from operations. The amendments in this update also allow only the service cost component to be eligible for capitalization when applicable. The standard will be applied retrospectively for the presentation of ~~that debt liability, consistent with debt discounts. This~~the service cost component and the other components of net periodic pension cost and net periodic postretirement benefit cost in the income statement and prospectively for the capitalization of the service cost component of net periodic pension cost and net periodic postretirement benefit in assets. The ASU is effective for ~~reporting~~the Registrants for fiscal years, and interim periods within those years, beginning after December 15, ~~2015 and interim periods therein. It is to be applied retrospectively~~2017, and early adoption is permitted. ~~Had~~The Registrants will adopt the ~~Registrants early adopted this ASU it would have decreased assets~~standard effective January 1, 2018. The components of net periodic benefit costs (credits) for pension benefits and ~~liabilities on DTE Energy’s~~other postretirement benefits are disclosed in Note 20 to the Consolidated Financial Statements, "Retirement Benefits and ~~DTE Electric’s Consolidated Statements of Financial Position by $74 million and $36 million, respectively, at December 31, 2015, and $73 million and $35 million, respectively, at December 31, 2014.~~

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

~~In November 2015, the FASB issued ASU No. 2015-17,~~ ~~Balance Sheet Classification of Deferred Taxes~~. This ASU requires that all deferred tax assets and liabilities, along with any related valuation allowance, be classified as noncurrent on the balance sheet. This ASU is effective for reporting periods beginning after December 15, 2016, including interim periods therein. It may be applied either prospectively or retrospectively, and early adoption is permitted. The Registrants adopted this ASU at December 31, 2015. The adoption of this ASU impacted DTE Energy’s and DTE Electric’s Consolidated Statements of Financial Position by decreasing assets and liabilities for 2014 by $75 million and $2 million, respectively.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

In February 2018, the FASB issued ASU No. 2018-02, Income Statement - Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income. The amendments in this update allow a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the TCJA. The amendments in this update also require entities to disclose their accounting policy for releasing income tax effects from accumulated other comprehensive income. The 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.

NOTE 4 — ACQUISITIONS AND EXIT ACTIVITIES

~~Acquisitions~~Gas Storage and Pipelines Acquisition

~~On January 21, 2015,~~Effective October 1, 2016, DTE ~~Electric~~Energy closed on ~~an acquisition~~the purchase of ~~a 732 MW simple-cycle~~midstream natural gas ~~facility~~assets in ~~Carson City, Michigan~~support of the strategy to continue to grow and earn competitive returns for shareholders. DTE Energy purchased 100% of AGS, located in Pennsylvania and West Virginia, and 40% of SGG, located in West Virginia, from M3 Midstream. In addition, DTE Energy purchased 15% of SGG from Vega Energy Partners, resulting in 55% total ownership of SGG by DTE Energy.

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

DTE ~~Electric has completed its valuation analysis~~Energy applied purchase accounting to ~~arrive at~~the acquired entities. The excess purchase price over the fair value of net assets acquired was classified as goodwill. September 30, 2017 marked the expiration of the one-year period from the acquisition to revise the fair value of assets ~~acquired.~~acquired and liabilities assumed. As a result, the purchase accounting adjustments through September 30, 2017 contributed approximately $7 million of additional goodwill. The ~~cash consideration~~factors contributing to the recognition of goodwill were based on various strategic benefits that are expected to be realized from the AGS and ~~total~~SGG acquisition. The acquisition provides DTE Energy with a platform for midstream growth and access to further investment opportunities in the Appalachian basin, an additional connection to the NEXUS Pipeline which should drive incremental volumes on the NEXUS Pipeline, and a new set of producer relationships that may lead to more partnering opportunities. The goodwill is expected to be deductible for income tax purposes.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

The final allocation of the purchase price ~~of approximately $241 million~~ was ~~allocated~~ based on estimated fair values of the ~~underlying~~AGS and SGG assets acquired and liabilities assumed at the date of acquisition, October 1, 2016. The components of the final purchase price allocation, inclusive of purchase accounting adjustments, are as follows:



	(In millions)
Assets
Cash	$	83
Accounts receivable	24
Inventory	6
Property, plant, and equipment, net	719
Goodwill	275
Customer relationship intangibles	770
Other current assets	1
	$	1,878
Liabilities
Accounts payable	$	19
Other current liabilities	11
Long-term debt	204
Other long-term liabilities	20
	$	254
Less: Noncontrolling interest	392
Total cash consideration	$	1,232

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

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

DTE Energy evaluated pre-acquisition contingencies relating to the purchase that existed as of the acquisition date. Based on the evaluation, DTE Energy determined that $30 million of certain pre-acquisition contingencies, related to repairing existing rights-of-way, were probable in nature and estimable as of the acquisition date. Accordingly, DTE Energy recorded its best estimates for these contingencies as part of purchase accounting, which are included in the Other current and long-term liabilities in the purchase price allocation table above.

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

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

~~On October 1, 2015,~~

DTE Energy Company — DTE Electric ~~closed on an acquisition of a 350 MW simple-cycle natural gas facility in East China Township, Michigan from a non-utility affiliate of DTE Energy. The facility will serve~~Company

Combined Notes to meet customer needs during periods of peak demand. DTE Electric has completed its purchase accounting. The cash consideration and total purchase price of approximately $69 million was based on the net book value of the assets acquired, which was primarily Property, plant, and equipment. The pro forma results of operations have not been presented for DTE Electric as the effects of the acquisition were not material to its Consolidated Financial Statements ~~of Operations.~~— (Continued)

Exit Activities

On December 17, 2015, DTE Energy announced the closure of the Shenango coke battery plant in response to a sharp downturn in the North American steel industry. The plant, which iswas included in the Power and Industrial Projects segment, is located in Pittsburgh, PA. As a result of the closure, DTE Energy recorded a one-time pre-tax non-cash impairment charge of $111 million. The charge included $96 million to fully impair the long-lived assets, employee severance expenses related to the workforce reduction of approximately 170 employees for $3 million, and other expenses, including write downs of inventory, of $12 million. DTE Energy's coke production has been shifted to a larger, more efficient coke battery plant in the Power and Industrial Projects segment. Production of coke from the Shenango coke battery plant ceased in January 2016.

A summary of the charges in the Consolidated Statements of Operations resulting from DTE Energy's exit activities is shown below:


	2015		2015
	(In millions)		(In millions)
Fuel, purchased power, and gas — non-utility	$	5	$	5
Operation and maintenance	10		10
Asset (gains) losses and impairments, net	96		96
Total Exit Activity Charges	$	111
Total exit activity charges			$	111

~~For amounts accrued at~~As of December 31, ~~2015~~2017, DTE Energy had approximately $1 million accrued related to these exit activities ~~DTE Energy~~and expects future cash payments of ~~approximately $7 million~~this remaining balance to be made in ~~2016.~~2018. DTE Energy ~~anticipates~~does not anticipate incurring significant additional ~~costs,~~expenses, including required environmental remediation costs, in connection with the closure. ~~An estimate~~

NOTE 5 — GOODWILL

DTE Energy has goodwill resulting from business combinations.

The following is the summary of change in the carrying amount of ~~additional costs and timing of~~goodwill for the ~~activities cannot be determined at~~years ended December ~~31, 2015 as alternatives are currently being evaluated, however,~~31:



	2017		2016
	(In millions)
Balance as of January 1	$	2,286	$	2,018
Goodwill attributable to Gas Storage and Pipelines acquisition	7		268
Balance at December 31	$	2,293	$	2,286

Refer to Note 4 to the ~~likelihood of these costs being material to DTE Energy's~~ Consolidated Financial Statements, ~~is remote.~~"Acquisitions and Exit Activities," for additional information related to the acquisition.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

NOTE 56 — PROPERTY, PLANT, AND EQUIPMENT

The following is a summary of Property, plant, and equipment by classification as of December 31:


	2015			2014			2017			2016
Property, plant, and equipment	(In millions)						(In millions)
DTE Electric
Generation	$	11,767		$	10,712		$	12,166		$	11,990
Distribution	7,816			7,414			8,637			8,134
Other	1,808			1,679			2,169			1,970
Total DTE Electric	21,391			19,805			22,972			22,094
DTE Gas
Distribution	3,124			2,946			3,523			3,382
Storage	453			448			533			503
Transmission and other	890			863			1,118			925
Total DTE Gas	4,467			4,257			5,174			4,810
Non-utility and other	2,263			2,476			3,278			3,125
Total DTE Energy	28,121			26,538			31,424			30,029
Less accumulated depreciation and amortization
Accumulated depreciation and amortization
DTE Electric
Generation	(4,346		)	(3,863		)	(4,403		)	(4,364		)
Distribution	(2,707		)	(2,822		)	(2,914		)	(2,769		)
Other	(593		)	(531		)	(667		)	(588		)
Total DTE Electric	(7,646		)	(7,216		)	(7,984		)	(7,721		)
DTE Gas
Distribution	(1,163		)	(1,130		)	(1,238		)	(1,198		)
Storage	(147		)	(142		)	(159		)	(152		)
Transmission and other	(370		)	(363		)	(384		)	(370		)
Total DTE Gas	(1,680		)	(1,635		)	(1,781		)	(1,720		)
Non-utility and other	(761		)	(867		)	(938		)	(858		)
Total DTE Energy	(10,087		)	(9,718		)	(10,703		)	(10,299		)
Net DTE Energy Property, plant, and equipment	$	18,034		$	16,820		$	20,721		$	19,730
Net DTE Electric Property, plant, and equipment	$	13,745		$	12,589		$	14,988		$	14,373

The following is a summary of the Registrants' AFUDC and interest capitalized ~~was approximately $34 million and $37 million for DTE Energy~~ for the years ended December ~~31, 2015 and 2014, respectively, including AFUDC capitalized of approximately $31 million and $32 million for DTE Electric for the years ended December 31, 2015 and 2014, respectively.~~31:



	DTE Energy				DTE Electric
	2017		2016		2017		2016
	(In millions)
Allowance for debt funds used during construction and interest capitalized	$	13	$	10	$	8	$	8
Allowance for equity funds used during construction	23		21		18		18
Total	$	36	$	31	$	26	$	26

The composite depreciation rate for DTE Electric was approximately 3.6% in 2017 and 3.5% in ~~2015~~2016 and ~~3.4% in 2014 and 2013.~~2015. The composite depreciation rate for DTE Gas was 2.7%, 2.4%, and 2.6% in 2017, 2016, and 2015, ~~and 2.4% in 2014 and 2013.~~respectively. The average estimated useful life for each major class of utility Property, plant, and equipment as of December 31, ~~2015~~2017 follows:

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

The estimated useful lives for DTE Electric's Other utility assets range from 54 to 62 years, while the estimated useful lives for DTE Gas' Transmission and other utility assets range from 5 to 70 years. The estimated useful lives for major classes of DTE Energy's non-utility assets and facilities range from 3 to 5583 years.

~~DTE Energy Company — DTE Electric Company~~

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

The following is a summary of Depreciation and amortization expense for DTE ~~Energy, including DTE Electric:~~Energy:


	2015			2014		2013		2017		2016		2015
	(In millions)							(In millions)
Property, plant, and equipment	$	740		$	683	$	630	$	865	$	783	$	740
Regulatory assets and liabilities	150			159		163		165		193		150
Securitized regulatory assets (a)	(38		)	303		301		—		—		(38		)
	$	852		$	1,145	$	1,094	$	1,030	$	976	$	852


(a)	Securitization surcharges ended in December 2014 with remaining over recovery refunded to customers in 2015. Securitization bonds were paid and Securitization regulatory assets amortization was completed in 2015. The $38 million credit represents the final adjustments to close out the Securitization program.

The following is a summary of Depreciation and amortization expense for DTE Electric:


	2015			2014		2013		2017		2016		2015
	(In millions)							(In millions)
Property, plant, and equipment	$	545		$	489	$	457	$	620	$	582	$	545
Regulatory assets and liabilities	126			135		138		133		168		126
Securitized regulatory assets (a)	(38		)	303		301		—		—		(38		)
	$	633		$	927	$	896	$	753	$	750	$	633


(a)	Securitization surcharges ended in December 2014 with remaining over recovery refunded to customers in 2015. Securitization bonds were paid and Securitization regulatory assets amortization was completed in 2015. The $38 million credit represents the final adjustments to close out the Securitization program.

Capitalized software costs are classified as Property, plant, and equipment and the related amortization is included in accumulated depreciation and amortization on the Registrants' Consolidated Financial Statements. The Registrants capitalize the costs associated with computer software developed or obtained for use in their businesses. The Registrants amortize capitalized software costs on a straight-line basis over the expected period of benefit, ranging from 3 to 15 years for DTE Energy and 54 to 15 years for DTE Electric.

The following balances for capitalized software relate to DTE ~~Energy, including DTE Electric:~~Energy:


	Year Ended December 31,						Year Ended December 31,
	2015		2014		2013		2017		2016		2015
	(In millions)						(In millions)
Amortization expense of capitalized software	$	98	$	77	$	71	$	101	$	89	$	98
Gross carrying value of capitalized software	$	770	$	668			$	890	$	715
Accumulated amortization of capitalized software	$	439	$	335			$	500	$	435

The following balances for capitalized software relate to DTE Electric:


	Year Ended December 31,						Year Ended December 31,
	2015		2014		2013		2017		2016		2015
	(In millions)						(In millions)
Amortization expense of capitalized software	$	80	$	71	$	64	$	93	$	83	$	80
Gross carrying value of capitalized software	$	664	$	590			$	774	$	610
Accumulated amortization of capitalized software	$	369	$	293			$	423	$	365

~~Property under capital leases for the Registrants is as follows:~~

DTE Energy DTE Electric
2015 2014 2015 2014
(In millions)
Gross property under capital leases $ 48
$ 35
$ 22
$ 9
Accumulated amortization of property under capital leases $ 26
$ 27
$ 1
$ 5

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

Property under capital leases for the Registrants is as follows:



	DTE Energy				DTE Electric
	2017		2016		2017		2016
	(In millions)
Gross property under capital leases	$	44	$	44	$	18	$	18
Accumulated amortization of property under capital leases	$	38	$	32	$	12	$	6

NOTE 67 — JOINTLY-OWNED UTILITY PLANT

DTE Electric has joint ownership interest in two power plants, Belle River and Ludington Hydroelectric Pumped Storage. DTE Electric’s share of direct expenses of the jointly-owned plants are included in Fuel, purchased power, and gas — utility and Operation and maintenance expenses in the DTE Energy Consolidated Statements of Operations and Fuel and purchased power— utility and Operation and maintenance expenses in the DTE Electric Consolidated Statements of Operations.

Ownership information of the two utility plants as of December 31, ~~2015~~2017 was as follows:


	Belle River		Ludington Hydroelectric Pumped Storage		Belle River		Ludington Hydroelectric Pumped Storage
In service date	1984-1985		1973
In-service date					1984-1985		1973
Total plant capacity	1,270 MW		1,955 MW		1,270 MW		2,080 MW
Ownership interest	(a)		49%		(a)		49%
Investment in Property, plant, and equipment (in millions)	$	1,779	$	443	$	1,814	$	559
Accumulated depreciation (in millions)	$	1,053	$	154	$	1,060	$	188


(a)	DTE Electric's ownership interest is 63% in Unit No. 1, 81% of the facilities applicable to Belle River used jointly by the Belle River and St. Clair Power Plants and 75% in common facilities used at Unit No. 2.

Belle River

The Michigan Public Power Agency (MPPA) has an ownership interest in Belle River Unit No. 1 and other related facilities. The MPPA is entitled to 19% of the total capacity and energy of the plant and is responsible for the same percentage of the plant’s operation, maintenance, and capital improvement costs.

Ludington Hydroelectric Pumped Storage

Consumers Energy Company has an ownership interest in the Ludington Hydroelectric Pumped Storage Plant. Consumers Energy is entitled to 51% of the total capacity and energy of the plant and is responsible for the same percentage of the plant’s operation, maintenance, and capital improvement costs.

NOTE 78 — ASSET RETIREMENT OBLIGATIONS

DTE Electric has a legal retirement obligation for the decommissioning costs for its Fermi 1 and Fermi 2 nuclear plants, dismantlement of facilities located on leased property, and various other operations. DTE Electric has conditional retirement obligations for asbestos and PCB removal at certain of its power plants and various distribution equipment. DTE Gas has conditional retirement obligations for gas pipelines, certain service centers, compressor and gate stations. The Registrants recognize such obligations as liabilities at fair market value when they are incurred, which generally is at the time the associated assets are placed in service. Fair value is measured using expected future cash outflows discounted at the Registrants' credit-adjusted risk-free rate. For its utility operations, the Registrants recognize in the Consolidated Statements of Operations removal costs in accordance with regulatory treatment. Any differences between costs recognized related to asset retirement and those reflected in rates are recognized as either a Regulatory asset or liability on the Consolidated Statements of Financial Position.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

If a reasonable estimate of fair value cannot be made in the period in which the retirement obligation is incurred, such as for assets with indeterminate lives, the liability is recognized when a reasonable estimate of fair value can be made. Natural gas storage system and certain other distribution assets for DTE Gas and substations, manholes, and certain other distribution assets for DTE Electric have an indeterminate life. Therefore, no liability has been recorded for these assets.

~~DTE Energy Company — DTE Electric Company~~

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

A reconciliation of the asset retirement obligations for ~~2015~~2017 follows:

DTE Energy DTE Electric
(In millions)
Asset retirement obligations at December 31, 2014 $ 1,962
$ 1,796
Accretion 119
111
Liabilities incurred 33
33
Revision in estimated cash flows 80
80
Asset retirement obligations at December 31, 2015 $ 2,194
$ 2,020

The Revision in estimated cash flows was principally attributed to the impact of the Coal Combustion Residuals on DTE Electric's coal ash storage facility AROs. Refer to Note 17 to the Consolidated Financial Statements, "Commitments and Contingencies", for discussion of the implications of the Coal Combustion Residuals.



	DTE Energy			DTE Electric
	(In millions)
Asset retirement obligations at December 31, 2016	$	2,197		$	2,012
Accretion	131			120
Liabilities incurred	2			1
Liabilities settled	(6		)	(2		)
Revision in estimated cash flows	(4		)	(6		)
Asset retirement obligations at December 31, 2017	$	2,320		$	2,125

Approximately ~~$1.8~~$1.9 billion of the asset retirement obligations represent nuclear decommissioning liabilities that are funded through a surcharge to electric customers over the life of the Fermi 2 nuclear plant. The NRC has jurisdiction over the decommissioning of nuclear power plants and requires minimum decommissioning funding based upon a formula. The MPSC and FERC regulate the recovery of costs of decommissioning nuclear power plants and both require the use of external trust funds to finance the decommissioning of Fermi 2. Rates approved by the MPSC provide for the recovery of decommissioning costs of Fermi 2 and the disposal of low-level radioactive waste. DTE Electric ~~is continuing to fund FERC jurisdictional amounts for decommissioning even though explicit provisions are not included in FERC rates. DTE Electric~~ believes the MPSC ~~and FERC~~ collections will be adequate to fund the estimated cost of decommissioning. The decommissioning assets, anticipated earnings thereon, and future revenues from decommissioning collections will be used to decommission Fermi 2. DTE Electric expects the liabilities to be reduced to zero at the conclusion of the decommissioning activities. If amounts remain in the trust funds for Fermi 2 following the completion of the decommissioning activities, those amounts will be disbursed based on rulings by the MPSC and FERC.

A portion of the funds recovered through the Fermi 2 decommissioning surcharge and deposited in external trust accounts is designated for the removal of non-radioactive assets and returning the site to greenfield. This removal and greenfielding is not considered a legal liability. Therefore, it is not included in the asset retirement obligation, but is reflected as the Nuclear decommissioning liability. The decommissioning of Fermi 1 is funded by DTE Electric. Contributions to the Fermi 1 trust are discretionary. For additional discussion of Nuclear decommissioning trust fund assets, see Note 1112 to the Consolidated Financial Statements, "Fair ~~Value".~~Value."

NOTE 89 — REGULATORY MATTERS

Regulation

DTE Electric and DTE Gas are subject to the regulatory jurisdiction of the MPSC, which issues orders pertaining to rates, recovery of certain costs, including the costs of generating facilities and regulatory assets, conditions of service, accounting, and operating-related matters. DTE Electric is also regulated by the FERC with respect to financing authorization and wholesale electric activities. Regulation results in differences in the application of generally accepted accounting principles between regulated and non-regulated businesses.

The Registrants are unable to predict the outcome of the unresolved regulatory matters discussed herein. Resolution of these matters is dependent upon future MPSC orders and appeals, which may materially impact the Consolidated Financial Statements of the Registrants.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

Regulatory Assets and Liabilities

DTE Electric and DTE Gas are required to record Regulatory assets and liabilities for certain transactions that would have been treated as revenue or expense in non-regulated businesses. Continued applicability of regulatory accounting treatment requires that rates be designed to recover specific costs of providing regulated services and be charged to and collected from customers. Future regulatory changes or changes in the competitive environment could result in the discontinuance of this accounting treatment for Regulatory assets and liabilities for some or all of the Registrants' businesses and may require the write-off of the portion of any Regulatory asset or liability that was no longer probable of recovery through regulated rates. Management believes that currently available facts support the continued use of Regulatory assets and liabilities and that all Regulatory assets and liabilities are recoverable or refundable in the current regulatory environment.

The following are balances and a brief description of the Registrants' Regulatory assets and liabilities at December 31:


	DTE Energy						DTE Electric						DTE Energy						DTE Electric
	2015			2014			2015			2014			2017			2016			2017			2016
Assets	(In millions)												(In millions)
Recoverable pension and other postretirement costs:
Recoverable pension and other postretirement costs
Pension	$	2,112		$	2,284		$	1,592		$	1,743		$	2,000		$	2,159		$	1,502		$	1,642
Other postretirement costs	256			234			198			191			278			286			211			207
Asset retirement obligation	565			448			565			448			569			613			569			613
Removal costs asset													299			193			299			193
Recoverable Michigan income taxes	248			267			203			220			213			231			171			187
Removal costs asset	118			15			118			15
Deferred environmental costs													75			78			—			—
Unamortized loss on reacquired debt	63			67			41			44			65			59			46			39
Transitional Reconciliation Mechanism													46			30			46			30
Customer360 deferred costs													45			33			45			33
Recoverable income taxes related to AFUDC equity													41			59			35			53
Other recoverable income taxes	61			66			61			66			26			57			26			57
Deferred environmental costs	54			59			—			—
Transitional Reconciliation Mechanism	43			14			43			14
Cost to achieve Performance Excellence Process	33			54			28			46
Nuclear Performance Evaluation and Review Committee Tracker													22			—			22			—
Accrued PSCR/GCR revenue	12			61			—			34			17			22			17			19
Recoverable income taxes related to Securitized regulatory assets	—			19			—			19
Other	159			139			137			119			82			93			66			76
	3,724			3,727			2,986			2,959			3,778			3,913			3,055			3,149
Less amount included in Current Assets	(32		)	(76		)	(17		)	(46		)	(55		)	(42		)	(50		)	(36		)
	$	3,692		$	3,651		$	2,969		$	2,913		$	3,723		$	3,871		$	3,005		$	3,113
Securitized regulatory assets	$	—		$	34		$	—		$	34


	DTE Energy						DTE Electric						DTE Energy						DTE Electric
	2015			2014			2015			2014			2017			2016			2017			2016
Liabilities	(In millions)												(In millions)
Refundable federal income taxes													$	2,384		$	—		$	1,946		$	—
Removal costs liability	$	291		$	308		$	—		$	—		265			266			—			—
Renewable energy	197			227			197			227			112			145			112			145
Negative other postretirement offset													80			56			67			55
Negative pension offset	46			67			—			—			21			36			—			—
Accrued PSCR/GCR refund	37			—			15			—
Refundable income taxes	23			33			—			—
Energy optimization	10			24			—			14
Fermi 2 refueling outage	4			16			4			16			15			27			15			27
Securitization over recovery	—			71			—			71
Refundable revenue decoupling/deferred gain	—			63			—			63
Refundable self-implemented rates													2			27			2			27
Other	2			11			2			4			14			32			12			2
	$	610		$	820		$	218		$	395		2,893			589			2,154			256
Less amount included in Current Liabilities	(41		)	(153		)	(19		)	(150		)	(18		)	(34		)	(17		)	(27		)
	$	569		$	667		$	199		$	245		$	2,875		$	555		$	2,137		$	229

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

As noted below, certain Regulatory assets for which costs have been incurred have been included (or are expected to be included, for costs incurred subsequent to the most recently approved rate case) in DTE Electric's or DTE Gas' rate base, thereby providing a return on invested costs (except as noted). Certain other regulatory assets are not included in rate base but accrue recoverable carrying charges until surcharges to collect the assets are billed. Certain Regulatory assets do not result from cash expenditures and therefore do not represent investments included in rate base or have offsetting liabilities that reduce rate base.

ASSETS

•

Recoverable pension and other postretirement costs — Accounting standards for pension and other postretirement benefit costs require, among other things, the recognition in Other comprehensive income of the actuarial gains or losses and the prior service costs that arise during the period but that are not immediately recognized as components of net periodic benefit costs. DTE Electric and DTE Gas record the impact of actuarial gains or losses and prior service costs as a Regulatory asset since the traditional rate setting process allows for the recovery of pension and other postretirement costs. The asset will reverse as the deferred items are amortized and recognized as components of net periodic benefit costs.^(a) — Accounting rules for pension and other postretirement benefit costs require, among other things, the recognition in Other comprehensive income of the actuarial gains or losses and the prior service costs that arise during the period but that are not immediately recognized as components of net periodic benefit costs. DTE Electric and DTE Gas record the impact of actuarial gains or losses and prior service costs as a Regulatory asset since the traditional rate setting process allows for the recovery of pension and other postretirement costs. The asset will reverse as the deferred items are amortized and recognized as components of net periodic benefit costs. ~~(a)~~

~~Asset retirement obligation~~ — This obligation is for Fermi 2 decommissioning costs. The asset captures the timing differences between expense recognition and current recovery in rates and will reverse over the remaining life of the related plant. ~~(a)~~


•	Asset retirement obligation — This obligation is for Fermi 2 decommissioning costs. The asset captures the timing differences between expense recognition and current recovery in rates and will reverse over the remaining life of the related plant.^(a)


•	Removal costs asset — Receivable for the recovery of asset removal expenditures in excess of amounts collected from customers.^(a)

Recoverable Michigan income taxes— ~~In July 2007, the MBT was enacted by the~~The State of ~~Michigan. State~~Michigan enacted a corporate income tax resulting in the establishment of state deferred tax liabilities ~~were established~~ for DTE ~~Energy’s utilities and offsetting~~Energy's utilities. Offsetting Regulatory assets were also recorded as the impacts of the deferred tax liabilities will be reflected in rates as the related taxable temporary differences reverse and flow through current income tax expense. ~~In May 2011, the MBT was repealed and the MCIT was enacted. The Regulatory asset was remeasured to reflect the impact of the MCIT tax rate.~~ ~~(a)~~

~~Removal costs asset~~

•

Deferred environmental costs — The MPSC approved the deferral of investigation and remediation costs associated with DTE Gas' former MGP sites. Amortization of deferred costs is over a ten-year period beginning in the year after costs were incurred, with recovery (net of any insurance proceeds) through base rate filings.^(a) ~~— Receivable for the recovery of asset removal expenditures in excess of amounts collected from customers.~~

Unamortized loss on reacquired debt — The unamortized discount, premium, and expense related to debt redeemed with a refinancing are deferred, amortized, and recovered over the life of the replacement issue.

~~Other recoverable income taxes~~ — Income taxes receivable from DTE Electric’s customers representing the difference in property-related deferred income taxes and amounts previously reflected in DTE Electric’s rates. This asset will reverse over the remaining life of the related plant. ~~(a)~~

~~Deferred environmental costs~~ — The MPSC approved the deferral of investigation and remediation costs associated with DTE Gas' former MGP sites. Amortization of deferred costs is over a ten-year period beginning in the year after costs were incurred, with recovery (net of any insurance proceeds) through base rate filings. (a)

Transitional Reconciliation Mechanism(~~TRM)~~ — The MPSC approved the recovery of the deferred net incremental revenue requirement associated with the transition of PLD customers to DTE Electric's distribution system, effective July 1, 2014. Annual reconciliations will be filed and surcharges will be implemented to recover approved amounts.

~~Cost to achieve Performance Excellence Process (PEP)~~Customer360 deferred costs — The MPSC ~~authorized~~approved the deferral and amortization of certain costs ~~to implement the PEP. These costs consist of employee severance, project~~associated with implementing Customer360, which is an integrated software application that enables improved interface among customer service, billing, meter reading, credit and collections, device management, account management, and ~~consultant support. These~~retail access. Amortization of deferred costs ~~are amortized~~ over a ~~ten-year~~15-year amortization period ~~beginning with~~began after the ~~year subsequent~~billing system was put into operation during the second quarter of 2017.

Recoverable income taxes related to AFUDC equity — Accounting standards for income taxes require recognition of a deferred tax liability for the equity component of AFUDC. A regulatory asset is required for the future increase in taxes payable related to the ~~year~~equity component of AFUDC that will be recovered from customers through future rates over the remaining life of the related plant.

Other recoverable income taxes — Income taxes receivable from DTE Electric's customers representing the difference in property-related deferred income taxes and amounts previously reflected in DTE Electric's rates. This asset will reverse over the remaining life of the related plant.

Nuclear Performance Evaluation and Review Committee Tracker — Deferral and amortization of certain costs ~~were deferred.~~associated with oversight and review of DTE Electric's nuclear power generation program, including safety and regulatory compliance, nuclear leadership, nuclear facilities, as well as operation and financial performance, pursuant to the MPSC authorization. The approved five-year amortization period began January 1, 2018, with recovery (net of carrying costs) through base rate filings.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

Accrued PSCR/GCR revenue — Receivable for the temporary under-recovery of and carrying costs on fuel and purchased power costs incurred by DTE Electric which are recoverable through the PSCR mechanism and temporary under-recovery of and carrying costs on gas costs incurred by DTE Gas which are recoverable through the GCR mechanism.


(a)	Regulatory assets not earning a return or accruing carrying charges.

LIABILITIES

~~Recoverable~~Refundable federal income taxes ~~related to Securitized regulatory assets~~ — Receivable for the recovery of income taxes to be paid on the non-bypassable securitization bond surcharge. A non-bypassable securitization tax surcharge, which ended in December 2014, was in place to recover the income tax over a 14-year period. (a)

~~DTE Energy Company~~ — DTE Electric ~~Company~~

~~Combined Notes~~and DTE Gas' remeasurement of deferred taxes due to ~~Consolidated Financial Statements — (Continued)~~

~~Securitized regulatory assets~~ ~~— The net book balance~~the enactment of the ~~Fermi 2 nuclear plant was written off in 1998 and an equivalent regulatory asset was established. In 2001,~~TCJA, which reflects the ~~Fermi 2 regulatory asset and certain other regulatory assets were securitized pursuant~~net impact of the tax rate change on cumulative temporary differences expected to ~~PA 142 and an MPSC order. A non-bypassable securitization bond surcharge, which ended in December 2014, was in place~~reverse after the effective date of January 1, 2018. Refer to ~~recover the Securitized regulatory asset over a 14-year period.~~"2017 Tax Reform" section below for additional information.

~~(a)Regulatory assets not earning a return or accruing carrying charges.~~

~~LIABILITIES~~

Removal costs liability — The amount collected from customers for the funding of future asset removal activities.

Renewable energy — Amounts collected in rates in excess of renewable energy expenditures.

Negative other postretirement offset — DTE Electric and DTE Gas' negative other postretirement costs are not included as a reduction to their authorized rates; therefore, DTE Electric and DTE Gas are accruing a Regulatory liability to eliminate the impact on earnings of the negative other postretirement expense accrual. The Regulatory liabilities will reverse to the extent DTE Electric and DTE Gas' other postretirement expense is positive in future years.

Negative pension offset — DTE Gas' negative pension costs are not included as a reduction to its authorized rates; therefore, DTE Gas is accruing a Regulatory liability to eliminate the impact on earnings of the negative pension expense accrued. This Regulatory liability will reverse to the extent DTE Gas' pension expense is positive in future years.

~~Accrued PSCR/GCR refund~~ — Liability for the temporary over-recovery of and a return on power supply costs and transmission costs incurred by DTE Electric which are recoverable through the PSCR mechanism and temporary over-recovery of and a return on gas costs incurred by DTE Gas which are recoverable through the GCR mechanism.

~~Refundable income taxes~~ ~~— Income taxes refundable to DTE Gas' customers representing the difference in property-related deferred income taxes payable and amounts recognized pursuant to MPSC authorization.~~

~~Energy optimization (EO)~~ ~~— Amounts collected in rates in excess of energy optimization expenditures.~~

Fermi 2 refueling outage — Accrued liability for refueling outage at Fermi 2 pursuant to MPSC authorization.

~~Securitization over recovery~~Refundable self-implemented rates — ~~Over recovery of securitization bond expenses.~~

~~Refundable revenue decoupling/deferred gain —~~Amounts ~~were originally accrued as~~ refundable to customers for base rates implemented from August 1, 2016 to December 31, 2016 in excess of amounts authorized in the January 2017 DTE Electric customers for the change in revenue resulting from the difference between actual average sales per customer compared to the base level of average sales per customer established by the MPSC. In 2012, the MCOA issued a decision reversing the MPSC's decision to authorize a RDM for DTE Electric. The revenue decoupling liability was reversed and, after receiving anrate order from the MPSC to defer the resulting gain for future amortization, DTE Electric created a regulatory liability representing its obligation to refund the gain. The deferred gain was amortized into earnings in 2014 and 2015.MPSC.

~~2014 Electric Rate Case Filing~~

DTE Electric filed a rate case with the MPSC on December 19, 2014 requesting an increase in base rates of $370 million based on a projected twelve-month period ending June 30, 2016. The requested increase in base rates was due primarily to an increase in net plant resulting from infrastructure investments, plant acquisitions, environmental compliance, and reliability improvement projects. The rate filing also included projected changes in sales, working capital, operation and maintenance expenses, return on equity, and capital structure. On July 1, 2015, DTE Electric realized an annual revenue increase of $230 million consisting of $190 million of self-implemented base rate increase related to the December 19, 2014 rate request and $40 million associated with the required elimination of a credit surcharge. On December 11, 2015, the MPSC issued an order approving an annual revenue increase of $238 million for service rendered on or after December 17, 2015. The rate order also provided for a reduction of the return on equity from 10.5% to 10.3% on a capital structure of 50% debt and 50% equity. On December 22, 2015, DTE Electric petitioned the MPSC for a rehearing and clarification of several issues related to the December 11, 2015 MPSC rate order. The three main issues addressed in the rehearing request were related to the recovery of the cost of the operating license for Fermi 3, the capitalization of the cost of tree trimming, and costs related to certain land and a building located near DTE Electric's Detroit headquarters. On January 19, 2016, the MPSC issued an order authorizing DTE Electric to begin amortization of the cost of the Fermi 3 operating license over a 20-year period without a return on the unamortized balance. The MPSC denied the capitalization of the tree trimming costs and the cost related to the land and building. DTE Electric recorded a disallowance of $10 million related to tree trim costs in the fourth quarter of 2015 which was previously capitalized as of September 30, 2015. The land and building have economic value independent of recovery through rates and therefore no impairment charge was recorded for these assets. The MPSC order also stated that any changes to the revenue deficiency will be addressed in a final rehearing order in this case.

~~DTE Energy Company — DTE Electric Company~~

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

2016 Electric Rate Case Filing

DTE Electric filed a rate case with the MPSC on February 1, 2016 requesting an increase in base rates of $344 million based on a projected twelve-month period ending July 31, 2017. On August 1, 2016, DTE Electric self-implemented a base rate increase of $245 million. On January 31, 2017, the MPSC issued an order approving an annual revenue increase of $184 million for service rendered on or after February 7, 2017. The MPSC authorized a return on equity of 10.1%. On April 28, 2017, DTE Electric filed to refund its customers their pro-rata share of the revenue collected through the self-implementation surcharge in effect from August 1, 2016 through February 7, 2017. On September 15, 2017, the MPSC approved a settlement authorizing DTE Electric to refund its customers $38.5 million of the self-implementation surcharge during the months of October through December 2017. DTE Electric has refunded the majority of the settlement liability as of December 31, 2017.

2017 Electric Rate Case Filing

DTE Electric filed a rate case with the MPSC on April 19, 2017 requesting an increase in base rates of $231 million based on a projected twelve-month period ending October 31, 2018. The requested increase in base rates is primarily due ~~primarily~~ to an increase in net plant resulting from infrastructure investments, environmental compliance, and reliability improvement projects. The rate filing also includes projected changes in sales, operation and maintenance expenses, and working capital. The rate filing also requests an increase in return on equity from ~~10.3%~~10.1% to 10.5% ~~on a capital structure of 50% equity and 50% debt.~~ . To mitigate the impact to its customers resulting from ASU No. 2017-07, Compensation — Retirement Benefits (Topic 715), DTE Electric ~~anticipates self-implementing~~suggested regulatory accounting treatment for the pension and postretirement cost components previously included as capital overhead. If the MPSC adopts DTE Electric's suggestion, the rate request will be reduced. For further discussion of ASU No. 2017-07, see Note 3 to the Consolidated Financial Statements, "New Accounting Pronouncements." On November 1, 2017, DTE Electric self-implemented a base rate increase ~~in August 2016 with an~~of $125 million. A final MPSC order in this case is expected by ~~February 2017.~~April 2018.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

PSCR Proceedings

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

~~2012~~2015 PSCR Year — In March ~~2013,~~2016, DTE Electric filed its ~~2012~~2015 PSCR reconciliation that included ~~purchased power~~the recovery of approximately $13 million of costs related to the ~~manual shutdown~~pass through of ~~the Fermi 2 nuclear power plant in June 2012 caused by the failure of one of the plant's two non-safety related feed-water pumps. The plant was restarted on~~a billing adjustment associated with a previous MPSC ordered customer refund. On July 30, 2012, which restored production to approximately 68% of full capacity. In September 2013, the repair to the plant was completed and production was returned to full capacity. DTE Electric was able to purchase sufficient power from MISO to continue to provide uninterrupted service to customers. On June 30, 2015,12, 2017, the MPSC issued an order that disallowed recovery of this 2015 PSCR billing adjustment pass through of approximately ~~$19~~$16 million, inclusive of ~~Fermi 2 related purchased power costs.~~interest. DTE Electric recorded the impact of ~~this~~the disallowance in the second quarter of ~~2015.~~2017 and filed a claim of appeal with the Michigan Court of Appeals in August 2017.

~~Customer Settlement~~Certificate of Necessity

InOn July ~~2014, an industrial customer of~~31, 2017, DTE Electric filed a ~~complaint with~~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 ~~alleging they had been overcharged~~to issue three CONs for the ~~period~~following: (1) power supplied by the proposed project is needed, (2) the size, fuel type, and other design characteristics of ~~February 2008 through March 2014,~~the proposed project represent the most reasonable and ~~sought payment~~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. DTE Electric ~~of $22 million, plus interest. In July 2015,~~expects an order in this proceeding from the MPSC issued an order that found the customer is entitled to a refund in the amount of $20 million, plus interest calculated at 7% per annum. In July 2015, DTE Electric issued a customer refund of $25 million, inclusive of interest. Approximately $16 million of the refund obligation is expected to be recovered through the PSCR and other regulatory mechanisms. DTE Electric does not expect this order to have a material impact to its Consolidated Statements of Operations.by April 27, 2018.

~~2015 DTE~~2017 Gas Rate Case Filing

DTE Gas filed a rate case with the MPSC on ~~December 18, 2015~~November 22, 2017 requesting an increase in base rates of ~~$183~~$85.1 million based on a projected twelve-month period ending ~~October 31, 2017.~~September 30, 2019. The requested increase in base rates is primarily due ~~primarily~~ to an increase in net ~~plant of $800 million, inclusive of IRM capital investments being recovered through approved IRM surcharge filings.~~plant. The rate filing also includes projected changes in sales, ~~operation and~~operations, maintenance expenses, and working capital. The rate filing also requests an increase in return on equity from ~~10.5%~~10.1% to ~~10.75% on a capital structure of 52% equity and 48% debt.~~ 10.5%. To mitigate the impact to its customers resulting from ASU No. 2017-07, Compensation — Retirement Benefits (Topic 715), DTE Gas ~~anticipates self-implementing a~~suggested regulatory accounting treatment for the pension and postretirement cost components previously included as capital overhead. If the MPSC adopts DTE Gas' suggestion, the rate ~~increase in November 2016 with an MPSC order expected by December 2016. Concurrent with~~request will be reduced. 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 ~~rate~~ case ~~the existing IRM surcharge will be terminated. However, in this rate case filing, DTE Gas requested to implement a new IRM surcharge to become effective in January 2017.~~is expected by September 2018.

~~DTE Gas IRM~~2017 Tax Reform

~~In November 2014, DTE Gas filed an application with the MPSC for approval of an increased IRM surcharge to recover an additional $47 million of annual capital expenditures in 2016 and~~On December 27, 2017, ~~for its gas main renewal program. In November 2015,~~ the MPSC issued an order ~~authorizing an expansion of its gas main renewal program and an increase~~to consider changes in the ~~IRM surcharge~~rates of ~~$16 million for 2016~~all Michigan rate-regulated utilities to reflect the effects of the federal TCJA. On January 19, 2018, DTE Electric and ~~$31 million for 2017. The 2017 increase is subject to a reduction~~DTE Gas filed information with the MPSC regarding the potential change in revenue requirements due to the ~~2016 level if~~TCJA effective January 1, 2018, and outlined our recommended method to flow the ~~2016 target is not met. The IRM surcharge authorized by the order in this filing will become effective in July 2016~~current and ~~will be terminated upon the implementation~~deferred tax benefits of ~~base rates requested in the December 18, 2015 rate case filing.~~those impacts to ratepayers.

~~DTE Energy Company — DTE Electric Company~~

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

NOTE 910 — INCOME TAXES

Income Tax Summary

DTE Energy files a consolidated federal income tax return. DTE Electric is a part of the consolidated federal income tax return of DTE Energy. DTE Energy and its subsidiaries file consolidated and/or separate company income tax returns in various states and localities, including a consolidated return in the State of Michigan. DTE Electric is part of the Michigan consolidated income tax return of DTE Energy. The federal, state and local income tax expense for DTE Electric is determined on an individual company basis with no allocation of tax expenses or benefits from other affiliates of DTE Energy. DTE Electric had an income tax ~~receivable from~~receivables with DTE Energy of $6$12 million and ~~$29~~$9 million at December 31, ~~2015~~2017 and ~~2014,~~2016, respectively.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

The Registrants' total Income Tax Expense varied from the statutory federal income tax rate for the following reasons:


	2015			2014			2013			2017			2016			2015
DTE Energy	(In millions)									(In millions)
Income Before Income Taxes	$	950		$	1,275		$	922		$	1,287		$	1,105		$	950
Income tax expense at 35% statutory rate	$	333		$	446		$	323		$	450		$	387		$	333
Production tax credits	(122		)	(119		)	(68		)	(189		)	(145		)	(122		)
Investment tax credits	(7		)	(6		)	(6		)	(4		)	(5		)	(7		)
Depreciation	(4		)	(4		)	(4		)	(4		)	(4		)	(4		)
AFUDC - Equity	(8		)	(7		)	(5		)
Noncontrolling interests										8			12			2
AFUDC equity										(18		)	(10		)	(8		)
Employee Stock Ownership Plan dividends	(5		)	(4		)	(4		)	(5		)	(5		)	(5		)
Domestic production activities deduction	—			—			(14		)
Stock based compensation										(14		)	—			—
Subsidiary stock loss										—			(10		)	—
State and local income taxes, net of federal benefit	35			51			37			51			58			35
Enactment of New York Corporate Income Tax Legislation, net of federal benefit	—			8			—
Enactment of the Tax Cuts and Jobs Act										(105		)	—			—
Other, net	8			(1		)	(5		)	5			(7		)	6
Income Tax Expense	$	230		$	364		$	254		$	175		$	271		$	230
Effective income tax rate	24.2		%	28.5		%	27.5		%	13.6		%	24.5		%	24.2		%


	2015			2014			2013			2017			2016			2015
DTE Electric	(In millions)									(In millions)
Income Before Income Taxes	$	836		$	830		$	741		$	928		$	975		$	836
Income tax expense at 35% statutory rate	$	293		$	291		$	260		$	325		$	341		$	293
Production tax credits	(31		)	(22		)	(15		)	(36		)	(30		)	(31		)
Investment tax credits	(5		)	(5		)	(5		)	(4		)	(4		)	(5		)
Depreciation	3			3			3			3			3			3
AFUDC - Equity	(7		)	(7		)	(5		)
AFUDC equity										(5		)	(6		)	(7		)
Employee Stock Ownership Plan dividends	(3		)	(3		)	(2		)	(3		)	(3		)	(3		)
Domestic production activities deduction	—			(2		)	(18		)
State and local income taxes, net of federal benefit	43			43			41			48			56			43
Other, net	(1		)	—			(5		)	(1		)	(4		)	(1		)
Income Tax Expense	$	292		$	298		$	254		$	327		$	353		$	292
Effective income tax rate	34.9		%	35.9		%	34.3		%	35.2		%	36.2		%	34.9		%

Components of the Registrants' Income Tax Expense were as follows:



	2017			2016			2015
DTE Energy	(In millions)
Current income tax expense (benefit)
Federal	$	(22	)	$	(1	)	$	(3	)
State and other income tax	1			7			(4		)
Total current income taxes	(21		)	6			(7		)
Deferred income tax expense
Federal	118			184			178
State and other income tax	78			81			59
Total deferred income taxes	196			265			237
	$	175		$	271		$	230

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

~~Components of the Registrants' Income Tax Expense were as follows:~~

2015 2014 2013
DTE Energy (In millions)
Current income tax expense (benefit)
Federal $ (3 ) $ (16 ) $ 74
State and other income tax (4 ) 24
16
Total current income taxes (7 ) 8
90
Deferred income tax expense
Federal 178
289
122
State and other income tax 59
67
42
Total deferred income taxes 237
356
164
Total $ 230
$ 364
$ 254


	2015			2014			2013		2017			2016		2015
DTE Electric	(In millions)								(In millions)
Current income tax expense (benefit)
Federal	$	(26	)	$	(19	)	$	123	$	(17	)	$	—	$	(26	)
State and other income tax	(2		)	20			23		(1		)	11		(2		)
Total current income taxes	(28		)	1			146		(18		)	11		(28		)
Deferred income tax expense
Federal	252			251			68		270			268		252
State and other income tax	68			46			40		75			74		68
Total deferred income taxes	320			297			108		345			342		320
Total	$	292		$	298		$	254
									$	327		$	353	$	292

Deferred tax assets and liabilities are recognized for the estimated future tax effect of temporary differences between the tax basis of assets or liabilities and the reported amounts in the Consolidated Financial Statements. Consistent with ~~rate making treatment,~~the original establishment of these deferred ~~taxes are offset~~tax liabilities (assets), no recognition of these non-cash transactions have been reflected in the ~~tables below for temporary differences which have related Regulatory assets and liabilities.~~Consolidated Statements of Cash Flows.

The Registrants' deferred tax assets (liabilities) were comprised of the following at December 31:


	DTE Energy						DTE Electric						DTE Energy						DTE Electric
	2015			2014			2015			2014			2017			2016			2017			2016
	(In millions)												(In millions)
Property, plant, and equipment	$	(4,211	)	$	(3,832	)	$	(3,468	)	$	(3,152	)	$	(3,276	)	$	(4,880	)	$	(2,698	)	$	(3,819	)
Securitized regulatory assets	5			(2		)	5			(3		)
Regulatory assets and liabilities													(94		)	(879		)	(31		)	(778		)
Tax credit carry-forwards	465			296			53			—			947			643			193			116
Pension and benefits	(301		)	(152		)	(193		)	(43		)	334			643			302			518
Federal net operating loss carry-forward	177			—			142			—			83			190			47			42
State and local net operating loss carry-forwards	63			39			16			—			70			59			5			1
Investments in equity method investees	(82		)	(84		)	—			—			(82		)	(119		)	—			—
Other	(4		)	65			(53		)	12			170			217			94			127
	(3,888		)	(3,670		)	(3,498		)	(3,186		)	(1,848		)	(4,126		)	(2,088		)	(3,793		)
Less valuation allowance	(35		)	(31		)	—			—			(40		)	(36		)	—			—
Long-term deferred income tax liabilities	$	(3,923	)	$	(3,701	)	$	(3,498	)	$	(3,186	)	$	(1,888	)	$	(4,162	)	$	(2,088	)	$	(3,793	)

Deferred income tax assets	$	1,088		$	861		$	453		$	357		$	1,814		$	1,463		$	830		$	569
Deferred income tax liabilities	(5,011		)	(4,562		)	(3,951		)	(3,543		)	(3,702		)	(5,625		)	(2,918		)	(4,362		)
	$	(3,923	)	$	(3,701	)	$	(3,498	)	$	(3,186	)	$	(1,888	)	$	(4,162	)	$	(2,088	)	$	(3,793	)

~~DTE Energy Company — DTE Electric Company~~

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

Tax credit ~~carry forwards~~carry-forwards for DTE Energy include ~~$181~~$640 million of general business credits that expire from 2034 through ~~2035~~2037 and ~~$284~~$307 million of alternative minimum tax credits that ~~may~~will be ~~carried forward indefinitely.~~refundable over the next four years. The alternative minimum tax credits are production tax credits earned prior to 2006 but not utilized. The majority of these alternative minimum tax credits were generated from projects that had received a private letter ruling (PLR) from the IRS. These PLRs provide assurance as to the appropriateness of using these credits to offset taxable income, however, these tax credits are subject to IRS audit and adjustment. No valuation allowance is required for the tax credits carry-forward deferred tax asset.

DTE Energy has a federal net operating loss carry-forward ~~available for use on the tax return~~ of ~~$517~~$397 million as of December 31, ~~2015,~~2017, which ~~includes approximately $9 million related to windfall tax benefits attributable to stock-based compensation for which a benefit~~ will ~~be recorded in additional paid-in capital if and when realized. The federal net operating loss carry-forward expires in 2035.~~expire from 2035 through 2037. No valuation allowance is required for the federal net operating loss deferred tax asset.

The above tables exclude unamortized investment tax credits that are shown separately on the Registrants' Consolidated Statements of Financial Position. Investment tax credits are deferred and amortized to income over the average life of the related property.

DTE Energy has state and local deferred tax assets related to net operating loss carry-forwards of ~~$63~~$70 million and ~~$39~~$59 million at December 31, ~~2015~~2017 and ~~2014,~~2016, respectively. The state and local net operating loss carry-forwards expire from ~~2016~~2018 through ~~2035.~~2037. DTE Energy has recorded valuation allowances at December 31, ~~2015~~2017 and ~~2014~~2016 of approximately ~~$35~~$40 million and ~~$31~~$36 million, respectively, with respect to these deferred tax assets. In assessing the realizability of deferred tax assets, DTE Energy considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

Tax credit carry-forwards for DTE Electric include $193 million of general business credits that expire from 2035 through 2037. No valuation allowance is required for the tax credits carry-forward deferred tax asset.

DTE Electric has a federal net operating loss carry-forward of $226 million as of December 31, 2017, which will expire in 2035. No valuation allowance is required for the federal net operating loss deferred tax asset.

DTE Electric has state and local deferred tax assets related to net operating loss carry-forwards of ~~$16~~$5 million at December 31, ~~2015,~~2017, while there was no$1 million state and local deferred tax asset related to net operating loss carry-forwards at December 31, ~~2014.~~2016. No valuation allowance is required for DTE Electric's state and local net operating loss carry-forwards.

Tax Cuts and Jobs Act

On December 22, 2017, the TCJA was enacted reducing the corporate income tax rate from 35% to 21%, effective January 1, 2018. As a result of the enactment, the deferred tax assets and liabilities were remeasured to reflect the impact of the TCJA on the cumulative temporary differences expected to reverse after the effective date. The net impact of this remeasurement was a decrease in deferred tax liabilities of $2.56 billion, of which $2.45 billion was attributable to regulated utilities and offset to regulatory assets and liabilities. This regulatory treatment is consistent with prior precedent set by the MPSC from previous tax law changes. The remaining $105 million was attributable to the non-utility entities and was recognized as a net reduction to income tax expense in 2017.

On December 22, 2017, the SEC issued guidance under Staff Accounting Bulletin No. 118, Income Tax Accounting Implications of the Tax Cuts and Jobs Act (SAB 118), directing 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. The amounts above represent our best estimate based on interpretations of the TCJA. In accordance with SAB 118, the amounts recorded are considered provisional and will continue to be analyzed throughout 2018, which may result in additional changes.

Uncertain Tax Positions

A reconciliation of the beginning and ending amount of unrecognized tax benefits for the Registrants is as follows:


	2015			2014			2013			2017		2016		2015
DTE Energy	(In millions)									(In millions)
Balance at January 1	$	9		$	10		$	11		$	10	$	3	$	9
Additions for tax positions of prior years										—		7		—
Lapse of statute of limitations	(6		)	(1		)	(1		)	—		—		(6		)
Balance at December 31	$	3		$	9		$	10		$	10	$	10	$	3


	2015		2014		2013		2017		2016		2015
DTE Electric	(In millions)						(In millions)
Balance at January 1	$	4	$	4	$	4	$	13	$	4	$	4
Additions for tax positions of prior years							—		9		—
Balance at December 31	$	4	$	4	$	4	$	13	$	13	$	4

DTE Energy had $2$8 million of unrecognized tax benefits at December 31, ~~2015~~2017 and ~~2014,~~2016 that, if recognized, would favorably impact its effective tax rate. DTE Energy does not anticipate any material decrease in unrecognized tax benefits in the next twelve months.

DTE Electric had ~~$3 million and $2~~$10 million of unrecognized tax benefits at December 31, ~~2015~~2017 and ~~2014, respectively,~~2016 that, if recognized, would favorably impact its effective tax rate. DTE Electric does not anticipate any material decrease in unrecognized tax benefits in the next twelve months.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

The Registrants recognize interest and penalties pertaining to income taxes in Interest expense and Other expenses, respectively, on their Consolidated Statements of Operations.

Accrued interest pertaining to income taxes for ~~both~~ DTE Energy ~~and DTE Electric~~ totaled $1$3 million at December 31, ~~2015~~2017 and ~~2014. The Registrants had no accrued penalties pertaining to income taxes. The Registrants~~2016. DTE Energy recognized interest expense ~~(income)~~ related to income taxes of a nominal amount in ~~2015, 2014,~~2017, $2 million in 2016, and ~~2013.~~

a nominal amount in 2015. DTE Energy ~~Company —~~had accrued no penalties pertaining to income taxes.

Accrued interest pertaining to income taxes for DTE Electric ~~Company~~

~~Combined Notes~~totaled $4 million at December 31, 2017 and 2016. DTE Electric recognized interest expense related to ~~Consolidated Financial Statements — (Continued)~~income taxes of a nominal amount in 2017, $3 million in 2016, and a nominal amount in 2015. DTE Electric had accrued no penalties pertaining to income taxes.

In ~~2015,~~2017, DTE Energy, including DTE Electric, settled a federal tax audit for the ~~2013~~2015 tax year. DTE Energy's federal income tax returns for ~~2014~~2016 and subsequent years remain subject to examination by the IRS. DTE Energy's ~~MBT~~Michigan Business Tax and ~~MCIT~~Michigan Corporate Income Tax returns for the year 2008 and subsequent years remain subject to examination by the State of Michigan. DTE Energy also files tax returns in numerous state and local jurisdictions with varying statutes of limitation.

NOTE 1011 — EARNINGS PER SHARE

~~DTE Energy reports both basic and diluted earnings per share. The calculation of diluted~~Basic earnings per share ~~assumes~~is calculated by dividing the ~~issuance~~net income, adjusted for income allocated to participating securities, by the weighted average number of ~~potentially dilutive~~ common shares outstanding during the ~~period from~~period. Diluted earnings per share reflect the ~~exercise of~~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 ~~options. A~~incentive program that contain rights to receive non-forfeitable dividends. Equity units, performance shares, and stock options do not receive cash dividends; as such, these awards are not considered participating securities. For additional information, see Notes 14 and 21 to Consolidated Financial Statements, "Long-Term Debt" and "Stock-Based Compensation," respectively.

The following is a reconciliation of ~~both calculations is presented in~~DTE Energy's basic and diluted income per share calculation for the ~~following table as of~~years ended December 31:

2015 2014 2013
(In millions, expect per share amounts)
Basic Earnings per Share
Net Income Attributable to DTE Energy Company $ 727
$ 905
$ 661
Average number of common shares outstanding 179
177
175
Weighted average net restricted shares outstanding —
—
1
Dividends declared — common shares $ 508
$ 475
$ 453
Dividends declared — net restricted shares 2
1
1
Total distributed earnings $ 510
$ 476
$ 454
Net Income less distributed earnings $ 217
$ 429
$ 207
Distributed (dividends per common share) $ 2.84
$ 2.69
$ 2.59
Undistributed 1.21
2.42
1.17
Total Basic Earnings per Common Share $ 4.05
$ 5.11
$ 3.76

Diluted Earnings per Share
Net Income Attributable to DTE Energy Company $ 727
$ 905
$ 661
Average number of common shares outstanding 179
177
175
Weighted average net restricted shares outstanding —
—
1
Dividends declared — common shares $ 508
$ 475
$ 453
Dividends declared — net restricted shares 2
1
1
Total distributed earnings $ 510
$ 476
$ 454
Net Income less distributed earnings $ 217
$ 429
$ 207
Distributed (dividends per common share) $ 2.84
$ 2.69
$ 2.59
Undistributed 1.21
2.41
1.17
Total Diluted Earnings per Common Share $ 4.05
$ 5.10
$ 3.76



	2017			2016			2015
	(In millions, except per share amounts)
Basic Earnings per Share
Net Income Attributable to DTE Energy Company	$	1,134		$	868		$	727
Less: Allocation of earnings to net restricted stock awards	(2		)	(2		)	(2		)
Net income available to common shareholders — basic	$	1,132		$	866		$	725

Average number of common shares outstanding	179			179			179
Basic Earnings per Common Share	$	6.32		$	4.84		$	4.05

Diluted Earnings per Share
Net Income Attributable to DTE Energy Company	$	1,134		$	868		$	727
Less: Allocation of earnings to net restricted stock awards	(2		)	(2		)	(2		)
Net income available to common shareholders — diluted	$	1,132		$	866		$	725

Average number of common shares outstanding	179			179			179
Diluted Earnings per Common Share^(a)	$	6.32		$	4.83		$	4.05


(a)	The 2016 Equity Units excluded from the calculation of diluted EPS were approximately 6 million and 7.1 million for the years ended December 31, 2017 and 2016, respectively, as the dilutive stock price threshold was not met. For more information, see Note 14 to the Consolidated Financial Statements, "Long-Term Debt."

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

NOTE 1112 — FAIR VALUE

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated, or generally unobservable inputs. The Registrants make certain assumptions they believe that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. Credit risk of the Registrants and their counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at December 31, ~~2015~~2017 and ~~2014.~~2016. The Registrants believe they use valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.

~~DTE Energy Company — DTE Electric Company~~

~~Combined Notes to Consolidated Financial Statements — (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.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

The following table presents assets and liabilities for DTE Energy measured and recorded at fair value on a recurring ~~basis as of December 31, 2015 and 2014:~~basis:


	December 31, 2015															December 31, 2014															December 31, 2017																	December 31, 2016
	Level 1			Level 2			Level 3			Netting (a)			Net Balance			Level 1			Level 2			Level 3			Netting (a)			Net Balance			Level 1			Level 2			Level 3			Other^(a)		Netting^(b)			Net Balance			Level 1			Level 2			Level 3			Netting^(b)			Net Balance
	(In millions)																														(In millions)
Assets:
Cash equivalents ~~(b)~~(c)	$	13		$	3		$	—		$	—		$	16		$	13		$	99		$	—		$	—		$	112		$	16		$	3		$	—		$	—	$	—		$	19		$	14		$	3		$	—		$	—		$	17
Nuclear decommissioning trusts	759			477			—			—			1,236			792			449			—			—			1,241
Other investments (c)	149			—			—			—			149			100			50			—			—			150
Equity securities																															978			—			—			—		—			978			887			—			—			—			887
Fixed income securities																															18			477			—			—		—			495			11			414			—			—			425
Private equity securities																															—			—			—			5		—			5			—			—			—			—			—
Cash equivalents																															14			—			—			—		—			14			8			—			—			—			8
Other investments^(d)
Equity securities																															118			—			—			—		—			118			104			—			—			—			104
Fixed income securities																															72			—			—			—		—			72			58			—			—			—			58
Cash equivalents																															4			—			—			—		—			4			3			—			—			—			3
Derivative assets:
Commodity Contracts:
Natural Gas	193			91			103			(285		)	102			555			140			92			(681		)	106			148			112			97			—		(256		)	101			216			79			53			(306		)	42
Electricity	—			239			68			(232		)	75			—			295			47			(280		)	62			—			243			42			—		(241		)	44			—			154			39			(157		)	36
Other	2			—			3			(2		)	3			42			—			3			(42		)	3			—			—			9			—		—			9			—			—			2			—			2
Other derivative contracts (d)	—			12			—			(9		)	3			—			4			—			(3		)	1
Foreign currency exchange contracts																															—			1			—			—		(1		)	—			—			6			—			(5		)	1
Total derivative assets	195			342			174			(528		)	183			597			439			142			(1,006		)	172			148			356			148			—		(498		)	154			216			239			94			(468		)	81
Total	$	1,116		$	822		$	174		$	(528	)	$	1,584		$	1,502		$	1,037		$	142		$	(1,006	)	$	1,675		$	1,368		$	836		$	148		$	5	$	(498	)	$	1,859		$	1,301		$	656		$	94		$	(468	)	$	1,583

Liabilities:
Derivative liabilities:
Commodity Contracts:
Natural Gas	$	(218	)	$	(57	)	$	(108	)	$	294		$	(89	)	$	(578	)	$	(78	)	$	(62	)	$	679		$	(39	)	$	(141	)	$	(111	)	$	(126	)	$	—	$	263		$	(115	)	$	(226	)	$	(86	)	$	(149	)	$	321		$	(140	)
Electricity	—			(243		)	(62		)	253			(52		)	—			(290		)	(52		)	298			(44		)	—			(245		)	(30		)	—		246			(29		)	—			(159		)	(30		)	163			(26		)
Other	(2		)	—			(8		)	8			(2		)	(32		)	(9		)	(4		)	45			—			—			—			(1		)	—		1			—			—			—			(3		)	2			(1		)
Other derivative contracts (d)	—			(7		)	—			7			—			—			(5		)	—			3			(2		)
Foreign currency exchange contracts																															—			(3		)	—			—		1			(2		)	—			(3		)	—			3			—
Total derivative liabilities	(220		)	(307		)	(178		)	562			(143		)	(610		)	(382		)	(118		)	1,025			(85		)	(141		)	(359		)	(157		)	—		511			(146		)	(226		)	(248		)	(182		)	489			(167		)
Total	$	(220	)	$	(307	)	$	(178	)	$	562		$	(143	)	$	(610	)	$	(382	)	$	(118	)	$	1,025		$	(85	)	$	(141	)	$	(359	)	$	(157	)	$	—	$	511		$	(146	)	$	(226	)	$	(248	)	$	(182	)	$	489		$	(167	)
Net Assets (Liabilities) at the end of the period	$	896		$	515		$	(4	)	$	34		$	1,441		$	892		$	655		$	24		$	19		$	1,590
Net Assets (Liabilities) at end of period																															$	1,227		$	477		$	(9	)	$	5	$	13		$	1,713		$	1,075		$	408		$	(88	)	$	21		$	1,416
Assets:
Current	$	174		$	284		$	128		$	(441	)	$	145		$	582		$	504		$	109		$	(955	)	$	240		$	157		$	298		$	104		$	—	$	(437	)	$	122		$	205		$	199		$	60		$	(400	)	$	64
Noncurrent (e)	942			538			46			(87		)	1,439			920			533			33			(51		)	1,435
Noncurrent																															1,211			538			44			5		(61		)	1,737			1,096			457			34			(68		)	1,519
Total Assets	$	1,116		$	822		$	174		$	(528	)	$	1,584		$	1,502		$	1,037		$	142		$	(1,006	)	$	1,675		$	1,368		$	836		$	148		$	5	$	(498	)	$	1,859		$	1,301		$	656		$	94		$	(468	)	$	1,583
Liabilities:
Current	$	(174	)	$	(260	)	$	(87	)	$	464		$	(57	)	$	(572	)	$	(357	)	$	(112	)	$	964		$	(77	)	$	(137	)	$	(313	)	$	(108	)	$	—	$	459		$	(99	)	$	(203	)	$	(211	)	$	(79	)	$	424		$	(69	)
Noncurrent	(46		)	(47		)	(91		)	98			(86		)	(38		)	(25		)	(6		)	61			(8		)	(4		)	(46		)	(49		)	—		52			(47		)	(23		)	(37		)	(103		)	65			(98		)
Total Liabilities	$	(220	)	$	(307	)	$	(178	)	$	562		$	(143	)	$	(610	)	$	(382	)	$	(118	)	$	1,025		$	(85	)	$	(141	)	$	(359	)	$	(157	)	$	—	$	511		$	(146	)	$	(226	)	$	(248	)	$	(182	)	$	489		$	(167	)
Net Assets (Liabilities) at the end of the period	$	896		$	515		$	(4	)	$	34		$	1,441		$	892		$	655		$	24		$	19		$	1,590
Net Assets (Liabilities) at end of period																															$	1,227		$	477		$	(9	)	$	5	$	13		$	1,713		$	1,075		$	408		$	(88	)	$	21		$	1,416


(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.

~~(b)~~(c)

At December 31, ~~2015,~~2017, available-for-sale securities of ~~$16~~$19 million included $8 million and $8$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, ~~2014,~~2016, available-for-sale securities of ~~$112~~$17 million, included ~~$105~~$7 million and $7$10 million of cash equivalents included in Restricted cash and Other investments on DTE Energy's Consolidated Statements of Financial Position, respectively.


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


~~(d)~~	~~Primarily includes foreign currency exchange contracts.~~


~~(e)~~	Includes $149 million and $150 million at December 31, 2015 and 2014, respectively, of other investments that are included in DTE Energy's Consolidated Statements of Financial Position in Other investments.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

The following table presents assets for DTE Electric measured and recorded at fair value on a recurring ~~basis as of December 31, 2015 and 2014:~~basis:


	December 31, 2015								December 31, 2014								December 31, 2017										December 31, 2016
	Level 1		Level 2		Level 3		Net Balance		Level 1		Level 2		Level 3		Net Balance		Level 1		Level 2		Level 3		Other^(a)		Net Balance		Level 1		Level 2		Level 3		Net Balance
	(In millions)																(In millions)
Assets:
Cash equivalents ~~(a)~~(b)	$	5	$	3	$	—	$	8	$	5	$	99	$	—	$	104	$	8	$	3	$	—	$	—	$	11	$	8	$	3	$	—	$	11
Nuclear decommissioning trusts	759		477		—		1,236		792		449		—		1,241
Equity securities																	978		—		—		—		978		887		—		—		887
Fixed income securities																	18		477		—		—		495		11		414		—		425
Private equity securities																	—		—		—		5		5		—		—		—		—
Cash equivalents																	14		—		—		—		14		8		—		—		8
Other investments	8		—		—		8		97		50		—		147
Equity securities																	11		—		—		—		11		9		—		—		9
Derivative assets — FTRs	—		—		3		3		—		—		3		3		—		—		9		—		9		—		—		2		2
Total	$	772	$	480	$	3	$	1,255	$	894	$	598	$	3	$	1,495	$	1,029	$	480	$	9	$	5	$	1,523	$	923	$	417	$	2	$	1,342

Assets:
Current	$	5	$	3	$	3	$	11	$	5	$	99	$	3	$	107	$	8	$	3	$	9	$	—	$	20	$	8	$	3	$	2	$	13
Noncurrent	767		477		—		1,244		889		499		—		1,388		1,021		477		—		5		1,503		915		414		—		1,329
Total Assets	$	772	$	480	$	3	$	1,255	$	894	$	598	$	3	$	1,495	$	1,029	$	480	$	9	$	5	$	1,523	$	923	$	417	$	2	$	1,342


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

(b)

At December 31, ~~2015,~~2017, available-for-sale securities of $8$11 million consisted of cash equivalents included in Other investments on DTE Electric's Consolidated Statements of Financial Position. At December 31, ~~2014,~~2016, available-for-sale securities of ~~$104~~$11 million ~~included $96 million and $8 million~~consisted of cash equivalents included in ~~Restricted cash and~~ Other investments ~~respectively,~~ 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. ~~The institutional mutual funds hold exchange-traded equity or debt securities and are valued based on stated NAVs.~~ Non-exchange-traded fixed income securities are valued based upon quotations available from brokers or pricing services. The institutional mutual funds hold exchange-traded equity or debt securities (exchange and non-exchange traded) and are valued based on publicly available NAVs. A primary price source is identified by asset type, class, or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustee determines that another price source is considered ~~to be~~ preferable. The Registrants have obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices. Additionally, the Registrants selectively corroborate the fair value of securities by comparison of market-based price sources. Investment policies and procedures are determined by DTE Energy's Trust Investments Department which reports to DTE Energy's Vice President and Treasurer.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

Derivative Assets and Liabilities

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

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 for the years ended December 31, ~~2015~~2017 and ~~2014:~~2016:


	Year Ended December 31, 2015												Year Ended December 31, 2014												Year Ended December 31, 2017												Year Ended December 31, 2016
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)																								(In millions)
Net Assets (Liabilities) as of December 31	$	30		$	(5	)	$	(1	)	$	24		$	(52	)	$	13		$	3		$	(36	)
Net Assets (Liabilities) as of January 1																									$	(96	)	$	9		$	(1	)	$	(88	)	$	(5	)	$	6		$	(5	)	$	(4	)
Transfers into Level 3 from Level 2	—			—			—			—			—			—			—			—			—			—			—			—			—			—			—			—
Transfers from Level 3 into Level 2	—			—			—			—			(2		)	—			—			(2		)	—			—			—			—			—			—			—			—
Total gains (losses):
Total gains (losses)
Included in earnings	(44		)	44			(8		)	(8		)	(40		)	25			(5		)	(20		)	(29		)	109			2			82			(159		)	(2		)	1			(160		)
Recorded in Regulatory assets/liabilities	—			—			12			12			—			—			8			8
Recorded in Regulatory liabilities																									—			—			25			25			—			—			6			6
Purchases, issuances, and settlements:
Purchases	—			2			—			2			—			1			—			1			—			—			—			—			—			1			—			1
Issuances	—			—			—			—			—			(3		)	—			(3		)
Settlements	9			(35		)	(8		)	(34		)	124			(41		)	(7		)	76			96			(106		)	(18		)	(28		)	68			4			(3		)	69
Net Assets (Liabilities) as of December 31	$	(5	)	$	6		$	(5	)	$	(4	)	$	30		$	(5	)	$	(1	)	$	24		$	(29	)	$	12		$	8		$	(9	)	$	(96	)	$	9		$	(1	)	$	(88	)
The amount of total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2015 and 2014 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations	$	(135	)	$	13		$	(7	)	$	(129	)	$	35		$	9		$	(4	)	$	40
The amount of total gains (losses) included in Net Income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2017 and 2016 and reflected in Operating Revenues — Non-utility operations and Fuel, purchased power, and gas — non-utility in DTE Energy's Consolidated Statements of Operations																									$	(30	)	$	50		$	1		$	21		$	(166	)	$	7		$	2		$	(157	)

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

The following table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for DTE Electric for the years ended December 31, ~~2015~~2017 and ~~2014:~~2016:


	Year Ended December 31,						Year Ended December 31,
	2015			2014			2017			2016
	(In millions)						(In millions)
Net Assets as of December 31	$	3		$	3
Change in fair value recorded in Regulatory assets/liabilities	12			8
Net Assets as of January 1							$	2		$	3
Change in fair value recorded in Regulatory liabilities							25			6
Purchases, issuances, and settlements:
Settlements	(12		)	(8		)	(18		)	(7		)
Net Assets as of December 31	$	3		$	3		$	9		$	2
The amount of total gains (losses) included in Regulatory assets and liabilities attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2015 and 2014 and reflected in DTE Electric's Consolidated Statements of Financial Position	$	3		$	3
The amount of total gains (losses) included in Regulatory liabilities attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2017 and 2016 and reflected in DTE Electric's Consolidated Statements of Financial Position							$	9		$	2

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

There were no transfers between Levels 1 and 2 for the Registrants during the years ended December 31, ~~2015~~2017 and ~~2014,~~2016, and there were no transfers from or into Level 3 for DTE Electric during the same periods.

The following tables present the unobservable inputs related to DTE Energy's Level 3 assets and liabilities as of December 31, ~~2015~~2017 and ~~2014:~~2016:


	December 31, 2015																December 31, 2017
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range						Weighted Average			Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)																(In millions)
Natural Gas	$	103	$	(108	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.50	) —	$	2.77	/MMBtu	$	(0.19	)/MMBtu	$	97	$	(126	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.10	)	—	$	9.75	/MMBtu	$	(0.03	)/MMBtu
Electricity	$	68	$	(62	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(11	) —	$	14	/MWh	$	2	/MWh	$	42	$	(30	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(5	)	—	$	15	/MWh	$	2	/MWh


	December 31, 2014																December 31, 2016
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range						Weighted Average			Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)																(In millions)
Natural Gas	$	92	$	(62	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(2.28	) —	$	7.83	/MMBtu	$	(0.22	)/MMBtu	$	53	$	(149	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.00	)	—	$	7.90	/MMBtu	$	(0.05	)/MMBtu
Electricity	$	47	$	(52	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(14	) —	$	15	/MWh	$	4	/MWh	$	39	$	(30	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(6	)	—	$	12	/MWh	$	1	/MWh

The unobservable inputs used in the fair value measurement of the electricity and natural gas commodity types consist of inputs that are less observable due in part to lack of available broker quotes, supported by little, if any, market activity at the measurement date or are based on internally developed models. Certain basis prices (i.e., the difference in pricing between two locations) included in the valuation of natural gas and electricity contracts were deemed unobservable.

The inputs listed above would have a direct impact on the fair values of the above security types if they were adjusted. A significant increase (decrease) in the basis price would result in a higher (lower) fair value for long positions, with offsetting impacts to short positions.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

Fair Value of Financial Instruments

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

The following table presents the carrying amount and fair value of financial instruments for DTE Energy as of December 31, ~~2015~~2017 and ~~2014:~~2016:


	December 31, 2015								December 31, 2014								December 31, 2017								December 31, 2016
	Carrying		Fair Value						Carrying		Fair Value						Carrying		Fair Value						Carrying		Fair Value
	Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3
	(In millions)																(In millions)
Notes receivable, excluding capital leases	$	32	$	—	$	—	$	32	$	41	$	—	$	—	$	41
Notes receivable^(a), excluding capital leases																	$	38	$	—	$	—	$	38	$	36	$	—	$	—	$	36
Dividends payable	$	131	$	131	$	—	$	—	$	122	$	122	$	—	$	—	$	158	$	158	$	—	$	—	$	148	$	148	$	—	$	—
Short-term borrowings	$	499	$	—	$	499	$	—	$	398	$	—	$	398	$	—	$	621	$	—	$	621	$	—	$	499	$	—	$	499	$	—
Long-term debt, excluding capital leases	$	9,285	$	496	$	8,136	$	1,203	$	8,606	$	489	$	8,308	$	706
Notes payable — Other^(b), excluding capital leases																	$	12	$	—	$	—	$	12	$	17	$	—	$	—	$	17
Long-term debt^(c)																	$	12,288	$	1,939	$	10,571	$	764	$	11,270	$	1,465	$	9,384	$	1,056


(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, premiums, and issuance costs. Excludes Capital lease obligations.

The following table presents the carrying amount and fair value of financial instruments for DTE Electric as of December 31, ~~2015~~2017 and ~~2014:~~2016:

December 31, 2015 December 31, 2014
Carrying Fair Value Carrying Fair Value
Amount Level 1 Level 2 Level 3 Amount Level 1 Level 2 Level 3
(In millions)
Notes receivable, excluding capital leases $ 5
$ —
$ —
$ 5
$ 12
$ —
$ —
$ 12
Notes receivable — affiliates $ —
$ —
$ —
$ —
$ 8
$ —
$ —
$ 8
Short-term borrowings — affiliates $ 75
$ —
$ —
$ 75
$ 84
$ —
$ —
$ 84
Short-term borrowings — other $ 272
$ —
$ 272
$ —
50
$ —
$ 50
$ —
Long-term debt, excluding capital leases $ 5,624
$ —
$ 5,432
$ 545
$ 5,259
$ —
$ 5,341
$ 496



	December 31, 2017								December 31, 2016
	Carrying		Fair Value						Carrying		Fair Value
	Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3
	(In millions)
Notes receivable^(a), excluding capital leases	$	—	$	—	$	—	$	—	$	5	$	—	$	—	$	5
Short-term borrowings — affiliates	$	116	$	—	$	—	$	116	$	117	$	—	$	—	$	117
Short-term borrowings — other	$	238	$	—	$	238	$	—	62		$	—	$	62	$	—
Notes payable — Other^(b), excluding capital leases	$	2	$	—	$	—	$	2	$	6	$	—	$	—	$	6
Long-term debt^(c)	$	6,017	$	—	$	6,441	$	171	$	5,878	$	—	$	6,026	$	264


(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 1213 to the Consolidated Financial Statements, "Financial and Other Derivative ~~Instruments".~~Instruments."

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

Nuclear Decommissioning Trust Funds

DTE Electric has a legal obligation to decommission its nuclear power plants following the expiration of its operating licenses. This obligation is reflected as an ~~ARO~~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. ~~DTE Electric is continuing to fund FERC jurisdictional amounts for decommissioning even though explicit provisions are not included in FERC rates.~~ See Note 78 to the Consolidated Financial Statements, "Asset Retirement ~~Obligations".~~Obligations."

~~DTE Energy Company — DTE Electric Company~~

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

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


	December 31, 2015		December 31, 2014		December 31, 2017		December 31, 2016
	(In millions)				(In millions)
Fermi 2	$	1,211	$	1,221	$	1,475	$	1,291
Fermi 1	3		3		3		3
Low-level radioactive waste	22		17		14		26
Total	$	1,236	$	1,241
					$	1,492	$	1,320

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


	Year Ended December 31,									Year Ended December 31,
	2015			2014			2013			2017			2016			2015
	(In millions)									(In millions)
Realized gains	$	39		$	54		$	83		$	83		$	74		$	39
Realized losses	$	(33	)	$	(33	)	$	(41	)	$	(29	)	$	(63	)	$	(33	)
Proceeds from sales of securities	$	885		$	1,146		$	1,118
Proceeds from sale of securities										$	1,240		$	1,457		$	885

Realized gains and losses from the sale of securities for ~~the~~ Fermi 2 ~~and the low-level radioactive waste funds~~ are recorded to the Regulatory asset and Nuclear decommissioning liability. Realized gains and losses from the sale of securities for low-level radioactive waste funds are recorded to the Nuclear decommissioning liability.

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

December 31, 2015 December 31, 2014
Fair
Value Unrealized
Gains Unrealized Losses Fair
Value Unrealized
Gains Unrealized Losses
(In millions)
Equity securities $ 731
$ 195
$ (68 ) $ 756
$ 204
$ (39 )
Debt securities 499
16
(4 ) 474
21
(2 )
Cash and cash equivalents 6
—
—
11
—
—
$ 1,236
$ 211

$ (72 ) $ 1,241
$ 225

$ (41 )



	December 31, 2017							December 31, 2016
	Fair Value		Unrealized Gains		Unrealized Losses			Fair Value		Unrealized Gains		Unrealized Losses
	(In millions)
Equity securities	$	978	$	320	$	(32	)	$	887	$	222	$	(46	)
Fixed income securities	495		13		(3		)	425		11		(5		)
Private equity securities	5		—		—			—		—		—
Cash equivalents	14		—		—			8		—		—
	$	1,492	$	333	$	(35	)	$	1,320	$	233	$	(51	)

The ~~debt~~following table summarizes the fair value of the fixed income securities ~~at December 31, 2015 and 2014 had an average maturity of approximately 6 years and 7 years, respectively.~~ held in nuclear decommissioning trust funds by contractual maturity:



	December 31, 2017
	(In millions)
Due within one year	$	23
Due after one through five years	102
Due after five through ten years	115
Due after ten years	255
	$	495

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

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

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

Other Securities

At December 31, ~~2015~~2017 and ~~2014,~~2016, the Registrants' securities were comprised primarily of money market and equity securities. There were no unrealized losses on available-for-sale securities which were reclassified out of Other comprehensive income (loss) and realized into Net Income for DTE Energy or DTE Electric during the years ended December 31, ~~2015~~2017 and ~~2014.~~2016. Gains related to trading securities held at December 31, 2017, 2016, and 2015 ~~2014, and 2013~~ were $1$26 million, ~~$14~~$15 million, and ~~$22~~$1 million, respectively, for ~~DTE Energy, including $1 million, $12 million, and $19 million, respectively, relating to DTE Electric.~~the Registrants. The trading gains or losses related to the Rabbi Trust assets, included in Other investments at DTE Energy, are allocated from DTE Energy to DTE Electric.

~~DTE Energy Company — DTE Electric Company~~

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

NOTE 1213 — 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 ~~2018.~~2020. Substantially all of these contracts meet the normal purchases and normal sales exception and are therefore accounted for under the accrual method. DTE Gas may also sell forward transportation and storage capacity contracts. Forward transportation and storage contracts are generally not derivatives and are therefore accounted for under the accrual method.

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

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

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

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. ~~DTE~~ 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.

~~DTE Energy Company — DTE Electric Company~~

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

Credit Risk — DTE Energy maintains credit policies that significantly minimize overall credit risk. These policies include an evaluation of potential customers’ and counterparties’ financial condition, including the viability of underlying productive assets, credit rating, collateral requirements, or other credit enhancements such as letters of credit or guarantees. DTE Energy generally uses standardized agreements that allow the netting of positive and negative transactions associated with a single counterparty. DTE Energy maintains a provision for credit losses based on factors surrounding the credit risk of its customers, historical trends, and other information. Based on DTE ~~Energy’s~~Energy's credit policies and its December 31, ~~2015~~2017 provision for credit losses, DTE Energy’s exposure to counterparty nonperformance is not expected to have a material adverse effect on DTE Energy's Consolidated Financial Statements.

Derivative Activities

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

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

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

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

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

~~The following table presents the fair value of derivative instruments as of December 31, 2015 and 2014 for DTE Energy:~~

December 31, 2015 December 31, 2014
Derivative
Assets Derivative
Liabilities Derivative
Assets Derivative
Liabilities
(In millions)
Derivatives not designated as hedging instruments:
Foreign currency exchange contracts $ 12
$ (7 ) $ 4
$ (5 )
Commodity Contracts:

Natural Gas 387
(383 ) 787
(718 )
Electricity 307
(305 ) 342
(342 )
Other 5
(10 ) 45
(45 )
Total derivatives not designated as hedging instruments: $ 711
$ (705 ) $ 1,178
$ (1,110 )

Current $ 570
$ (521 ) $ 1,083
$ (1,041 )
Noncurrent 141
(184 ) 95
(69 )
Total derivatives $ 711
$ (705 ) $ 1,178
$ (1,110 )

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

The following table presents the fair value of derivative instruments as of December 31, ~~2015~~2017 and ~~2014~~2016 for DTE Energy:



	December 31, 2017					December 31, 2016
	Derivative Assets		Derivative Liabilities			Derivative Assets		Derivative Liabilities
	(In millions)
Derivatives not designated as hedging instruments:
Commodity Contracts:
Natural Gas	$	357	$	(378	)	$	348	$	(461	)
Electricity	285		(275		)	193		(189		)
Other	9		(1		)	2		(3		)
Foreign currency exchange contracts	1		(3		)	6		(3		)
Total derivatives not designated as hedging instrument	$	652	$	(657	)	$	549	$	(656	)

Current	$	540	$	(558	)	$	447	$	(493	)
Noncurrent	112		(99		)	102		(163		)
Total derivatives	$	652	$	(657	)	$	549	$	(656	)

The following table presents the fair value of derivative instruments as of December 31, 2017 and 2016 for DTE Electric:


	December 31,				December 31,
	2015		2014		2017		2016
	(In millions)				(In millions)
FTRs — Other current assets	$	3	$	3	$	9	$	2
Total derivatives not designated as hedging instrument	$	3	$	3
Total derivatives not designated as hedging instruments					$	9	$	2

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

DTE Energy also provides and receives collateral in the form of letters of credit which can be offset against net Derivative assets and liabilities as well as Accounts receivable and payable. DTE Energy had issued letters of credit of approximately $7$4 million and $2 million outstanding at December 31, ~~2015~~2017 and ~~2014,~~2016, respectively, which could be used to offset net Derivative liabilities. Letters of credit received from third parties which could be used to offset net Derivative assets were $2$4 million and $5$2 million at December 31, ~~2015~~2017 and ~~2014,~~2016, respectively. Such balances of letters of credit are excluded from the tables below and are not netted with the recognized assets and liabilities in DTE Energy's Consolidated Statements of Financial Position.

For contracts with certain clearing agents, the fair value of derivative instruments is netted against realized positions with the net balance reflected as either 1) a Derivative asset or liability or 2) an Account receivable or payable. Other than certain clearing agents, Accounts receivable and Accounts payable that are subject to netting arrangements have not been offset against the fair value of Derivative assets and liabilities. Certain contracts that have netting arrangements have not been offset in DTE Energy's Consolidated Statements of Financial Position. The impact of netting these derivative instruments and cash collateral related to such contracts is not material. Only the gross amounts for these derivative instruments are included in the table below.

For DTE Energy, the total cash collateral posted, net of cash collateral received, was ~~$37~~$28 million and ~~$61~~$34 million as of December 31, ~~2015~~2017 and ~~2014,~~2016, respectively. ~~There was $2~~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 ~~$36~~$22 million as of December 31, ~~2015. There was no~~2017. DTE Energy had $7 million of cash collateral related to unrealized positions to net against Derivative assets while Derivative liabilities are shown net of cash collateral of ~~$19~~$28 million as of December 31, ~~2014.~~2016. DTE Energy recorded cash collateral paid of $6$18 million and cash collateral received of $3 million not related to unrealized derivative positions as of December 31, ~~2015.~~2017. DTE Energy recorded cash collateral paid of ~~$44~~$18 million and cash collateral received of $2$5 million not related to unrealized derivative positions as of December 31, ~~2014.~~2016. These amounts are included in Accounts receivable and Accounts payable and are recorded net by counterparty.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

The following table presents the netting offsets of Derivative assets and liabilities for DTE Energy at December 31, ~~2015~~2017 and ~~2014:~~2016:


	December 31, 2015									December 31, 2014									December 31, 2017									December 31, 2016
	Gross Amounts of Recognized Assets (Liabilities)			Gross Amounts Offset in the Consolidated Statements of Financial Position			Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position			Gross Amounts of Recognized Assets (Liabilities)			Gross Amounts Offset in the Consolidated Statements of Financial Position			Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position			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)																		(In millions)
Derivative assets:
Commodity Contracts:
Natural Gas	$	387		$	(285	)	$	102		$	787		$	(681	)	$	106		$	357		$	(256	)	$	101		$	348		$	(306	)	$	42
Electricity	307			(232		)	75			342			(280		)	62			285			(241		)	44			193			(157		)	36
Other	5			(2		)	3			45			(42		)	3			9			—			9			2			—			2
Other derivative contracts (a)	12			(9		)	3			4			(3		)	1
Foreign currency exchange contracts																			1			(1		)	—			6			(5		)	1
Total derivative assets	$	711		$	(528	)	$	183		$	1,178		$	(1,006	)	$	172		$	652		$	(498	)	$	154		$	549		$	(468	)	$	81

Derivative liabilities:
Commodity Contracts:
Natural Gas	$	(383	)	$	294		$	(89	)	$	(718	)	$	679		$	(39	)	$	(378	)	$	263		$	(115	)	$	(461	)	$	321		$	(140	)
Electricity	(305		)	253			(52		)	(342		)	298			(44		)	(275		)	246			(29		)	(189		)	163			(26		)
Other	(10		)	8			(2		)	(45		)	45			—			(1		)	1			—			(3		)	2			(1		)
Other derivative contracts (a)	(7		)	7			—			(5		)	3			(2		)
Foreign currency exchange contracts																			(3		)	1			(2		)	(3		)	3			—
Total derivative liabilities	$	(705	)	$	562		$	(143	)	$	(1,110	)	$	1,025		$	(85	)	$	(657	)	$	511		$	(146	)	$	(656	)	$	489		$	(167	)


~~(a)~~	~~Primarily includes foreign currency exchange contracts.~~

The following table presents the netting offsets of Derivative assets and liabilities showing the reconciliation of derivative instruments to DTE Energy's Consolidated Statements of Financial Position at December 31, ~~2015~~2017 and ~~2014:~~2016:


	December 31, 2015												December 31, 2014												December 31, 2017												December 31, 2016
	Derivative Assets						Derivative Liabilities						Derivative Assets						Derivative Liabilities						Derivative Assets						Derivative Liabilities						Derivative Assets						Derivative Liabilities
	Current			Noncurrent			Current			Noncurrent			Current			Noncurrent			Current			Noncurrent			Current			Noncurrent			Current			Noncurrent			Current			Noncurrent			Current			Noncurrent
	(In millions)																								(In millions)
Total fair value of derivatives	$	570		$	141		$	(521	)	$	(184	)	$	1,083		$	95		$	(1,041	)	$	(69	)	$	540		$	112		$	(558	)	$	(99	)	$	447		$	102		$	(493	)	$	(163	)
Counterparty netting	(441		)	(85		)	441			85			(955		)	(51		)	955			51			(437		)	(52		)	437			52			(396		)	(65		)	396			65
Collateral adjustment	—			(2		)	23			13			—			—			9			10			—			(9		)	22			—			(4		)	(3		)	28			—
Total derivatives as reported	$	129		$	54		$	(57	)	$	(86	)	$	128		$	44		$	(77	)	$	(8	)	$	103		$	51		$	(99	)	$	(47	)	$	47		$	34		$	(69	)	$	(98	)

~~100~~

~~DTE Energy Company — DTE Electric Company~~

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

The effect of derivatives not designated as hedging instruments on DTE Energy's Consolidated Statements of Operations for years ended December 31, ~~2015~~2017 and ~~2014~~2016 is as follows:


	Location of Gain (Loss) Recognized in Income on Derivatives		Gain (Loss) Recognized in Income on Derivatives for Years Ended December 31,								Location of Gain (Loss) Recognized in Income on Derivatives		Gain (Loss) Recognized in Income on Derivatives for Years Ended December 31,
Derivatives not Designated as Hedging Instruments		2015				2014					Location of Gain (Loss) Recognized in Income on Derivatives	2017				2016
			(In millions)										(In millions)
Foreign currency exchange contracts	Location of Gain (Loss) Recognized in Income on Derivatives	Operating Revenues — Non-utility operations		$	3			$	(2	)
Commodity Contracts:
Natural Gas	Operating Revenues — Non-utility operations		(34		)		(30		)		Operating Revenues — Non-utility operations		$	(74	)		$	(153	)
Natural Gas	Fuel, purchased power, and gas — non-utility		(44		)		(5		)		Fuel, purchased power, and gas — non-utility		97				(2		)
Electricity	Operating Revenues — Non-utility operations		54				123				Operating Revenues — Non-utility operations		105				43
Other	Operating Revenues — Non-utility operations		(7		)		(7		)		Operating Revenues — Non-utility operations		2				5
Foreign currency exchange contracts											Operating Revenues — Non-utility operations		(2		)		(2		)
Total			$	(28	)		$	79					$	128			$	(109	)

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

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

The following represents the cumulative gross volume of DTE Energy's derivative contracts outstanding as of December 31, ~~2015:~~2017:



Commodity		Number of Units
Natural Gas (MMBtu)		~~1,740,824,930~~1,822,796,301
Electricity (MWh)		~~27,668,865~~
~~Oil (Gallons)~~		~~21,756,000~~29,715,268
Foreign Currency Exchange (Canadian dollars)		~~72,328,008~~108,023,948

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 December 31, ~~2015,~~2017, DTE Energy's contractual obligation to post collateral in the form of cash or letters of credit in the event of a downgrade to below investment grade, under both hard trigger and soft trigger provisions, was approximately ~~$412~~$456 million.

As of December 31, ~~2015,~~2017, DTE Energy had approximately ~~$592~~$535 million of derivatives in net liability positions, for which hard triggers exist. ~~Collateral of approximately $5 million~~There is no collateral that has been posted against such liabilities, including cash and letters of credit. Associated derivative net asset positions for which contractual offset exists were approximately ~~$500~~$468 million. The net remaining amount of approximately ~~$87~~$67 million is derived from the ~~$412~~$456 million noted above.

~~101~~

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

NOTE 1314 — LONG-TERM DEBT

Long-Term Debt

DTE Energy's long-term debt outstanding and weighted average interest rates ~~(a)~~ of debt outstanding at December 31 were:

2015 2014
(In millions)
Mortgage bonds, notes, and other
DTE Energy Debt, Unsecured
4.4% due 2016 to 2033 $ 1,947
$ 1,647
DTE Electric Taxable Debt, Principally Secured
4.4% due 2016 to 2045 5,314
4,824
DTE Electric Tax-Exempt Revenue Bonds (b)
5.2% due 2020 to 2030 310
330
DTE Gas Taxable Debt, Principally Secured
4.9% due 2018 to 2045 1,124
1,099
Other Long-Term Debt, Including Non-Recourse Debt 110
121
DTE Energy Total Long-Term Debt 8,805
8,021
Less amount due within one year for DTE Energy (465 ) (161 )
$ 8,340
$ 7,860
DTE Electric Securitization Bonds
6.6% due 2015 $ —
$ 105
Less amount due within one year —
(105 )
$ —
$ —
DTE Energy Junior Subordinated Debentures
6.5% due 2061 $ 280
$ 280
5.25% due 2062 200
200
$ 480
$ 480

~~DTE Electric's long-term debt outstanding and weighted average interest rates (a) of debt outstanding at December 31 were:~~

2015 2014
(In millions)
Mortgage bonds, notes, and other
DTE Electric Taxable Debt, Principally Secured
4.4% due 2016 to 2045 $ 5,314
$ 4,824
DTE Electric Tax-Exempt Revenue Bonds (b)

5.2% due 2020 to 2030 310
330
DTE Electric Total Long-Term Debt 5,624
5,154
Less amount due within one year for DTE Electric (151 ) (10 )
$ 5,473
$ 5,144
DTE Electric Securitization Bonds
6.6% due 2015 $ —
$ 105
Less amount due within one year —
(105 )
$ —
$ —



	Interest Rate^(a)	Maturity Date	2017			2016
			(In millions)
Mortgage bonds, notes, and other
DTE Energy Debt, Unsecured	3.1%	2019 — 2033	$	3,825		$	3,325
DTE Electric Taxable Debt, Principally Secured	4.3%	2020 — 2047	5,755			5,615
DTE Electric Tax-Exempt Revenue Bonds^(b)	4.3%	2020 — 2030	310			310
DTE Gas Taxable Debt, Principally Secured	4.8%	2018 — 2047	1,330			1,250
Other Long-Term Debt, including Non-Recourse Debt			7			92
			11,227			10,592
Unamortized debt discount and premium, net			(15		)	(10		)
Unamortized debt issuance costs			(69		)	(67		)
Long-term debt due within one year			(104		)	(9		)
			$	11,039		$	10,506
Junior Subordinated Debentures
Subordinated Debentures	5.5%	2062 — 2077	$	1,180		$	780
Unamortized debt issuance costs			(35		)	(24		)
			$	1,145		$	756


(a)	Weighted average interest ~~rates~~rate as of December 31, ~~2015 are shown below the description of each category of debt.~~2017.


(b)	DTE Electric Tax-Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds.

DTE Electric's long-term debt outstanding and weighted average interest rates of debt outstanding at December 31 were:

~~102~~



	Interest Rate^(a)	Maturity Date	2017			2016
			(In millions)
Mortgage bonds, notes, and other
Taxable Debt, Principally Secured	4.3%	2020 — 2047	$	5,755		$	5,615
Tax-Exempt Revenue Bonds^(b)	4.3%	2020 — 2030	310			310
			6,065			5,925
Unamortized debt discount			(10		)	(10		)
Unamortized debt issuance costs			(38		)	(37		)
			$	6,017		$	5,878


(a)	Weighted average interest rate as of December 31, 2017.


(b)	Tax-Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

Debt Issuances

In ~~2015,~~2017, the following debt was issued:


Company	Month	Type	Interest Rate	Maturity	Amount		Month	Type	Interest Rate	Maturity Date	Amount
					(In millions)						(In millions)
DTE Energy							March	Senior Notes^(a)	3.80%	2027	$	500
DTE Electric	March	Mortgage Bonds (a)	3.70%	2045	$	500	August	General and Refunding Mortgage Bonds^(b)	3.75%	2047	440
DTE Energy	June	Senior Notes (b)	3.30%	2022	300
DTE Gas	August	Mortgage Bonds (c)	3.35%	2027	40		September	First Mortgage Bonds^(a)	3.08%	2029	40
DTE Gas	August	Mortgage Bonds (c)	4.21%	2045	125		September	First Mortgage Bonds^(a)	3.75%	2047	40
DTE Energy							November	Junior Subordinated Debentures^(a)	5.25%	2077	400
					$	965					$	1,420


(a)	Proceeds were used for ~~the redemption of long-term debt,~~ repayment of short-term borrowings and general corporate purposes.


(b)	Proceeds were used ~~for general corporate purposes.~~


~~(c)~~	~~Proceeds were used~~to repay $300 million of DTE Electric's 2008 series G 5.60% Senior Notes due on June 15, 2018, for the ~~redemption~~repayment of ~~long-term debt~~short-term borrowings and general corporate purposes.

Debt Redemptions

In ~~2015,~~2017, the following debt was redeemed:


Company	Month	Type	Interest Rate	Maturity	Amount		Month	Type	Interest Rate	Maturity Date	Amount
					(In millions)						(In millions)
DTE Electric	March	Securitization Bonds	6.62%	2015	$	105	August	Senior Notes	5.60%	2018	$	300
DTE Electric	March	Mortgage Bonds	7.904%	2016	10
DTE Gas	September	Senior Notes	5.94%	2015	140
DTE Electric	December	Tax-Exempt Revenue Bonds	5.00%	2015	20
DTE Energy							September	Secured Note^(a)	7.29%	2029	77
DTE Energy	Various	Other Long-Term Debt	Various	2015	11		Various	Other Long-Term Debt	Various	2017	8
					$	286					$	385


(a)	DTE Energy's Gas Storage and Pipelines segment recognized a $16 million net loss on extinguishment of debt associated with early repayment, consisting of $20 million of early redemption premiums and $4 million of unamortized debt premiums. The loss is reflected in Other (Income) and Deductions — Interest Expense on the Consolidated Statements of Operations.

The following table shows the Registrants' scheduled debt maturities, excluding any unamortized discount or premium on debt:


	2016		2017		2018		2019		2020		2021 and Thereafter		Total		2018		2019		2020		2021		2022		2023 and Thereafter		Total
	(In millions)														(In millions)
DTE Energy (a)	$	465	$	9	$	407	$	427	$	688	$	7,304	$	9,300	$	104	$	1,497	$	683	$	462	$	616	$	9,045	$	12,407
DTE Electric	$	151	$	—	$	300	$	—	$	632	$	4,552	$	5,635	$	—	$	—	$	632	$	462	$	316	$	4,655	$	6,065


(a)	Amounts include DTE Electric's scheduled debt maturities.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

Junior Subordinated Debentures

At December 31, ~~2015,~~2017, DTE Energy had ~~$280 million of 6.5%~~the following Junior Subordinated ~~Debentures due 2061 and $200 million of 5.25% Junior Subordinated Debentures due 2062.~~ Debentures:



	Interest Rate	Maturity Date	Amount
			(In millions)
2012 Series C	5.25%	2062	$	200
2016 Series B	5.375%	2076	300
2016 Series F	6.00%	2076	280
2017 Series E	5.25%	2077	400
			$	1,180

DTE Energy has the right to defer interest payments on the debt securities. Should DTE Energy exercise this right, it cannot declare or pay dividends on, or redeem, purchase or acquire, any of its capital stock during the deferral period. Any deferred interest payments will bear additional interest at the rate associated with the related debt issue. As of December 31, ~~2015,~~2017, no interest payments have been deferred on the debt securities.

Cross Default Provisions

Substantially all of the net utility properties of DTE Electric and DTE Gas are subject to the lien of mortgages. Should DTE Electric or DTE Gas fail to timely pay their indebtedness under these mortgages, such failure may create cross defaults in the indebtedness of DTE Energy.

Acquisition Financing

Effective October 1, 2016, DTE Energy closed on the purchase of midstream natural gas assets. The acquisition was financed through the issuance of Equity Units and Senior Notes. See Note 4 to the Consolidated Financial Statements, "Acquisitions and Exit Activities," for more information on the acquisition.

~~103~~In October 2016, DTE issued $675 million of Equity Units. Each Equity Unit has a stated amount of $50, initially in the form of a Corporate Unit, is comprised of (i) a forward purchase contract to buy DTE Energy common stock (stock purchase contract) and (ii) a 1/20 undivided beneficial ownership interest in $1,000 principal amount of DTE Energy’s 2016 Series C 1.5% RSNs due 2024. The RSN debt instruments and the stock purchase contract equity instruments are deemed to be separate instruments as the investor may trade the RSNs separately from the stock purchase contracts and may also settle the stock purchase contracts separately. The Corporate Units are listed on the New York Stock Exchange under the symbol DTV.

The stock purchase contract obligates the holder to purchase from DTE Energy on the settlement date, October 1, 2019, for a price of $50 per stock purchase contract, the following number of shares of DTE Energy’s common stock, subject to anti-dilution adjustments:

if the AMV of DTE Energy’s common stock, which is the average volume-weighted average price of DTE Energy’s common stock for the trading days during the 20 consecutive scheduled trading day period ending on the third scheduled trading day immediately preceding the stock purchase contract settlement date, is equal to or greater than $116.31, 0.4299 shares of common stock;

if the AMV is less than $116.31 but greater than $93.05, a number of shares of common stock equal to $50 divided by the AMV, rounded to the nearest 1/10,000th of a share; and

if the AMV is less than or equal to $93.05, 0.5373 shares of common stock.

The RSNs bear interest at a rate of 1.5% per year, payable quarterly, and mature on October 1, 2024. The RSNs will be remarketed in 2019. If this remarketing is successful, the interest rate on the RSNs will be reset, and thereafter interest will be payable semi-annually at the reset rate. If there is no successful remarketing, the interest rate on the RSNs will not be reset, and the holders of the RSNs will have the right to put the RSNs to DTE Energy at a price equal to 100% of the principal amount, and the proceeds of the put right will be deemed to have been applied against the holders’ obligation under the stock purchase contracts. DTE Energy may also redeem, in whole or in part, the RSNs in the event of a failed final remarketing.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

On January 1, 2017, DTE Energy began paying the stock purchase contract holders quarterly contract adjustment payments at a rate of 5% per year of the stated amount of $50 per Equity Unit, or $2.50 per year. The present value of the future contract adjustment payments of $98 million was recorded as a reduction of shareholders’ equity, offset by the stock purchase contract liability. The stock purchase contract liability is included in Current Liabilities — Other and Other Liabilities — Other on DTE Energy’s Consolidated Statements of Financial Position. Interest payments on the RSNs are recorded as interest expense and stock purchase contract payments are charged against the liability. Accretion of the stock purchase contract liability is recorded as imputed interest expense. The treasury stock method is used to compute diluted EPS for the stock purchase contract. Under the treasury stock method, the stock purchase contract will only have a dilutive effect when the settlement rate is based on the market value of DTE’s common stock that is greater than $116.31 (the threshold appreciation price). At December 31, 2017, the stock purchase price contract was anti-dilutive and, therefore, not included in the computation of diluted earnings per share. If payments for the stock purchase contract are deferred, DTE Energy may not make any cash distributions related to its capital stock, including dividends, redemptions, repurchases, liquidation payments or guarantee payments. Also, during the deferral period, DTE Energy may not make any payments on or redeem or repurchase any debt securities that are equal in right of payment with, or subordinated to, the RSNs.

Until settlement of the stock purchase contracts, the shares of stock underlying each contract are not outstanding. Under the terms of the stock purchase contracts, assuming no anti-dilution or other adjustments, DTE Energy will issue between 5.8 million and 7.3 million shares of its common stock in October 2019. A total of 9 million shares of DTE Energy’s common stock have been reserved for issuance in connection with the stock purchase contracts.

Selected information about DTE Energy’s 2016 Equity Units is presented below:



Issuance Date	Units Issued	Total Net Proceeds		Total Long-Term Debt		RSN Annual Interest Rate	Stock Purchase Contract Annual Rate	Stock Purchase Settlement Date	Stock Purchase Contract Liability^(a)		RSN Maturity Date
(In millions, except interest rates)
10/5/2016	13.5	$	654	$	675	1.5%	5.0%	10/1/2019	$	98	10/1/2024


(a)	Payments of $32 million were made in 2017. The stock purchase contract liability was $66 million and $98 million at December 31, 2017 and 2016, respectively, exclusive of interest.

In October 2016, DTE Energy issued $400 million of 2016 Series D 1.50% Senior Notes due 2019 and $600 million of Series E 2.85% Senior Notes due 2026. The proceeds from the Senior Notes were used for the acquisition and general corporate purposes.

NOTE 1415 — PREFERRED AND PREFERENCE SECURITIES

As of December 31, ~~2015,~~2017, the amount of authorized and unissued stock is as follows:



Company	Type of Stock	Par Value		Shares Authorized
DTE Energy	Preferred	$	—	5,000,000
DTE Electric	Preferred	$	100	6,747,484
DTE Electric	Preference	$	1	30,000,000
DTE Gas	Preferred	$	1	7,000,000
DTE Gas	Preference	$	1	4,000,000

NOTE 1516 — 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 ~~facilities~~revolvers are available at prevailing short-term interest rates. Additionally, DTE Energy has other facilities to support letter of credit issuance.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

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 December 31, ~~2015,~~2017, the total funded debt to total capitalization ratios for DTE Energy, DTE Electric, and DTE Gas were ~~0.51~~0.54 to 1, ~~0.51~~0.50 to 1, and 0.48 to 1, respectively, and ~~are~~were in compliance with this financial covenant.

The availability under the facilities in place at December 31, ~~2015~~2017 is shown in the following table:

DTE Energy DTE Electric DTE Gas Total
(In millions)
Unsecured letter of credit facility, expiring in February 2017 $ 100
$ —
$ —
$ 100
Unsecured letter of credit facility, expiring in September 2017 70
—
—
70
Unsecured revolving credit facility, expiring April 2020 1,200
400
300
1,900
1,370
400
300
2,070
Amounts outstanding at December 31, 2015
Commercial paper issuances 33
272
194
499
Letters of credit 130
—
—
130
163
272
194
629
Net availability at December 31, 2015 $ 1,207
$ 128
$ 106
$ 1,441



	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 December 31, 2017
Commercial paper issuances	83		238		300		621
Letters of credit	124		—		—		124
	207		238		300		745
Net availability at December 31, 2017	$	1,213	$	162	$	—	$	1,375

DTE Energy has approximately $9 million of other outstanding letters of credit which are used for various corporate purposes and are not included in the ~~above~~facilities described ~~facilities totaling approximately $17 million which are used for various corporate purposes.~~above.

The weighted average interest rate for short-term borrowings was ~~0.6%~~1.9% and ~~0.4%~~0.9% at December 31, ~~2015~~2017 and ~~2014,~~2016, respectively, for DTE Energy. The weighted average interest rate for short-term borrowings was ~~0.7%~~1.5% and ~~0.5%~~0.8% at December 31, ~~2015~~2017 and ~~2014,~~2016, respectively, for DTE Electric.

~~104~~

~~DTE Energy Company — DTE Electric Company~~

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

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 December 31, ~~2015, a $25 million letter of credit was in place, raising~~2017, the capacity under this facility ~~to $125~~was $100 million. ~~The $25 million letter of credit is included in the table above.~~ The amount outstanding under this agreement was ~~$103~~$56 million and ~~$37~~$50 million at December 31, ~~2015~~2017 and ~~2014,~~2016, respectively, and was fully offset by the posted collateral.

Dividend Restrictions

Certain of DTE Energy’s credit facilities contain a provision requiring DTE Energy to maintain a total funded debt to capitalization ratio, as defined in the agreements, of no more than 0.65 to 1, which has the effect of limiting the amount of dividends DTE Energy can pay in order to maintain compliance with this provision. At December 31, ~~2015,~~2017, the effect of this provision was to restrict the payment of approximately ~~$920 million~~$1.8 billion of Retained earnings totaling ~~$4.8~~$5.6 billion. There are no other effective limitations with respect to DTE Energy’s ability to pay dividends.

NOTE 1617 — CAPITAL AND OPERATING LEASES

Lessee -— Operating Lease — The Registrants lease various assets under operating leases, including coal railcars, office buildings, a warehouse, computers, vehicles, and other equipment. The lease arrangements expire at various dates through 2046.

~~The Registrants' future minimum lease payments under non-cancelable leases at December 31, 2015 were:~~

DTE Energy DTE Electric
Operating
Leases Operating
Leases
(In millions)
2016 $ 37
$ 24
2017 30
18
2018 25
15
2019 21
14
2020 13
10
Thereafter 71
35
Total minimum lease payments $ 197
$ 116

Rental expense for DTE Energy operating leases was $43 million in 2015, $38 million in 2014, and $34 million in 2013, including rental expense for DTE Electric operating leases of $32 million in 2015, $26 million in 2014, and $28 million in 2013.

~~105~~

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

The Registrants' future minimum lease payments under non-cancelable operating leases at December 31, 2017 were:



	DTE Energy		DTE Electric
	(In millions)
2018	$	40	$	15
2019	34		14
2020	22		9
2021	13		9
2022	9		6
2022 and thereafter	48		38
Total minimum lease payments	$	166	$	91

Rental expense for DTE Energy operating leases was $51 million in 2017 and $43 million in 2016 and 2015, including rental expense for DTE Electric operating leases of $28 million in 2017, $28 million in 2016, and $32 million in 2015.

Lessor-— Capital Lease — DTE Energy leases a portion of its pipeline system to the Vector Pipeline through a capital lease contract that expires in 2020, with renewal options extending for five years. DTE Energy owns a 40% interest in the Vector Pipeline. In addition, DTE Energy has antwo energy services ~~agreement,~~agreements, for which a portion of ~~which is~~are accounted for as a capital ~~lease. The agreement expires~~leases. These agreements were extended during the year and expire in 2019 ~~with a three or five year renewal option.~~ and 2026.

The components of DTE Energy's net investment in capital leases at December 31, ~~2015,~~2017, were as follows:


	DTE Energy			DTE Energy
	Capital Leases			(In millions)
	(In millions)
2016	$	13
2017	13
2018	13			$	13
2019	10			10
2020	9			9
Thereafter	—
2021				—
2022				—
2023 and thereafter				1
Total minimum future lease receipts	58			33
Residual value of leased pipeline	40			40
Less unearned income	(27		)	(15		)
Net investment in capital lease	71			58
Less current portion	(6		)	(7		)
	$	65		$	51

NOTE 1718 — COMMITMENTS AND CONTINGENCIES

Environmental

DTE Electric

Air — DTE Electric is subject to the EPA ozone and fine particulate transport and acid rain regulations that limit power plant emissions of ~~sulfur dioxide~~SO₂ and ~~nitrogen oxides.~~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 ~~nitrogen oxide, sulfur dioxide,~~SO₂, NO_x, mercury, and other emissions. Additional rulemakings ~~are expected~~may occur over the next few years which could require additional controls for ~~sulfur dioxide, nitrogen oxides,~~SO₂, NO_x, and other hazardous air pollutants.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

The Cross State Air Pollution Rule (CSAPR), required further reductions of ~~sulfur dioxide~~SO₂ and ~~nitrogen oxides~~NO_x emissions beginning in January 2015. ~~DTE Electric expects to meet its obligations under CSAPR. In November 2015,~~On September 7, 2016, the EPA ~~proposed~~finalized an update to the CSAPR ozone season program by issuing the CSAPR Update Rule. ~~The proposed~~This rule ~~was subsequently published in the Federal Register in December 2015. Beginning in 2017, this proposal would~~is expected to reduce summertime (May - September) NO_xemissions ~~of oxides of nitrogen (NOX)~~ from power plants in 2322 states in the eastern half of the U.S., including DTE ~~Energy~~Electric facilities. The CSAPR Update Rule is intended to reduce air quality impacts of the interstate transport of air pollution on downwind areas' ability to meet the 2008 ozone ~~standard~~National Ambient Air Quality Standards implementing power sector emission budgets and ~~to respond to the July 2015 remand of certain CSAPR budgets by the U.S. Court of Appeals for the D.C. Circuit. EPA~~NO_x allowance trading programs. DTE Electric expects to ~~promulgate the final rule in the summer of 2016. It is not possible to quantify the impact of this rulemaking at this time.~~

~~106~~

~~DTE Energy Company — DTE Electric Company~~

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

The Mercury and Air Toxics Standards (MATS) rule, formerly known as the Electric Generating Unit Maximum Achievable Control Technology (EGU MACT) Rule was finalized in December 2011. The MATS rule required reductions of mercury and other hazardous air pollutants beginning in April 2015. DTE Electric requested and was granted compliance date extensions for all relevant units to April 2016. DTE Electric has tested several technologies as MATS compliance alternatives to Flue Gas Desulfurization (FGD) systems to determine technological and economic feasibility. Dry Sorbent Injection (DSI) and Activated Carbon Injection (ACI) technologies were deemed feasible and their implementation will allow units that would not have been economical for FGD installations to continue operation in compliance with MATS. In November 2014, the U.S. Supreme Court agreed to review a challenge to the MATS rule based on a narrowly focused question of how the EPA considered costs in regulating air pollutants emitted by electric utilities. In June 2015, the U.S. Supreme Court reversed the decision of the Court of Appeals for the D.C. District and remanded the MATS rule to the Court of Appeals for further consideration based on their decision that the EPA must consider costs prior to deciding to regulatemeet its obligations under ~~the provisions of the Clean Air Act. Subsequently, in December 2015, the Court of Appeals ordered a remand of the MATS rule back to the EPA without staying the rule.~~CSAPR. DTE Electric does not expect this ~~decision~~rule to have a material effect on its compliance ~~plans at this time.~~program.

The EPA proposed revised air quality standards for ground level ozone in November 2014 and specifically requested comments on the form and level of the ozone standards. The standards were finalized in October 2015. The State of Michigan ~~will recommend designations by~~recommended to the EPA in October 2016 ~~and~~which areas of the state are not attaining the new standard. In November 2017, the EPA ~~will finalize~~completed the majority of the United States attainment/unclassifiable area designations. The Registrants expect the EPA to complete the remaining designations, including the non-attainment area designations with the 2015 ozone standards by ~~October 2017.~~the first quarter in 2018. DTE Electric cannot predict the financial impact of the revised ozone standards at this time.

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

In August 2010, the U.S. Department of Justice, at the request of the EPA, brought a civil suit in the U.S. District Court for the Eastern District of Michigan against DTE Energy and DTE Electric, related to the June 2010 NOV/FOV and the outage work performed at Unit 2 of the Monroe Power Plant, but not relating to the July 2009 NOV/FOV. Among other relief, the EPA requested the court to require DTE Electric to install and operate the best available control technology at Unit 2 of the Monroe Power Plant. Further, the EPA requested the court to issue a preliminary injunction to require DTE Electric to (i) begin the process of obtaining the necessary permits for the Monroe Unit 2 modification and (ii) offset the pollution from Monroe Unit 2 through emissions reductions from DTE Electric's fleet of coal-fired power plants until the new control equipment is operating. In August 2011, the U.S. District Court judge granted DTE Energy's motion for summary judgment in the civil case, dismissing the case and entering judgment in favor of DTE Energy and DTE Electric. In October 2011, the EPA ~~caused to be~~ filed a Notice of Appeal to the Court of Appeals for the Sixth Circuit. In March 2013, the Court of Appeals remanded the case to the U.S. District Court for review of the procedural component of the New Source Review notification requirements. In September 2013, the EPA ~~caused to be~~ filed a motion seeking leave to amend their complaint regarding the June 2010 NOV/FOV adding additional claims related to outage work performed at the Trenton Channel and Belle River ~~power plants~~Power Plants as well as additional claims related to work performed at the Monroe Power Plant. In ~~addition, the Sierra Club caused to be filed a motion to add a claim regarding the River Rouge Power Plant. In~~ March 2014, the U.S. District Court judge again granted ~~again~~ DTE Energy's motion for summary judgment dismissing the civil case related to Monroe Unit 2. In April 2014, the U.S. District Court judge granted motions filed by the EPA and the Sierra Club to amend their New Source Review complaint adding additional claims for Monroe Units 1, 2, and 3, Belle River Units 1 and 2, and Trenton Channel Unit 9 and denied the claims related to River Rouge Power Plant that were brought by the Sierra Club. In June 2014, the EPA filed a motion requesting certification for appeal of the March 2014 summary judgment decision.9. In October 2014, the EPA and the U.S. Department of Justice filed ~~the anticipated~~a notice of appeal of the U.S. District Court judge's dismissal of the Monroe Unit 2 case. The amended New Source Review claims ~~are~~were all stayed ~~until~~pending resolution of the appeal ~~is resolved~~ by the Court of Appeals for the Sixth Circuit. ~~Oral arguments~~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 ~~appeal occurred~~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 ~~2015.~~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. The Registrants are in discussion with the EPA regarding this 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.

~~107~~

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

The EPA ~~is implementing~~has implemented regulatory actions under the Clean Air Act to address emissions of GHGs from the utility sector and other sectors of the economy. Among these actions, the EPA ~~has~~ finalized performance standards for emissions of carbon dioxide from new and existing ~~electric generating units (EGUs).~~EGUs. The carbon standards for new sources are not expected to have a material impact on DTE Electric, since DTE Electric has no plans to build new coal-fired generation and any potential new gas generation will be able to comply with the standards. In February 2016, the U.S. Supreme Court granted petitioners' requests for a stay of the carbon rules for existing EGUs (also known as the EPA Clean Power Plan) pending final review by the courts. The Clean Power Plan has no legal effect while the stay is in place. On March 28, 2017, a presidential executive order was issued on "Promoting Energy Independence and Economic Growth." The order instructs the EPA to review, and if appropriate, suspend, revise or rescind the Clean Power Plan rule. Additionally, federal agencies have been directed to conduct a review of all existing regulations that potentially burden the development and use of domestically produced energy resources. Following the issuance of this order, the federal government requested the U.S. Court of Appeals for the D.C. Circuit to hold all legal challenges in abeyance until the review of these regulations is completed. 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 ~~final carbon standards (also known as~~EPA's repeal and possible replacement of the ~~EPA~~ Clean Power ~~Plan)~~Plan on existing sources at this time.

To comply with air pollution requirements, DTE Electric spent approximately ~~$2.3~~$2.4 billion through ~~2015.~~2017. DTE Electric ~~estimates making~~does not anticipate additional capital expenditures ~~of approximately $40 million in 2016.~~through 2024.

Water — In response to an EPA regulation, DTE Electric ~~would be~~was required to examine alternatives for reducing the environmental impacts of the cooling water intake structures at several of its facilities. Based on the results of completed studies and expected future studies, DTE Electric may be required to install technologies to reduce the impacts of the water intake structures. A final rule became effective in October 2015. The final rule requires studies to be completed ~~by April 2018~~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 December 31, ~~2015~~2017 and ~~2014,~~2016, DTE Electric had $8$6 million and ~~$10~~$8 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 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. The rule~~2015, and was revised in October 2016. In September 2017, the EPA indicated that it intends to reconsider certain provisions of the CCR Rule, but the nature and timing of such a reconsideration is ~~based on the continued listing of coal ash as a non-hazardous waste and relies on various self-implementation design and performance standards.~~unknown. DTE Electric owns and operates three permitted engineered coal ash storage facilities to dispose of coal ash from coal-fired power plants and operates a number of smaller impoundments at its power plants. ~~At certain facilities, the rule requires~~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. At other facilities, the rule requires ash laden waters be moved from earthen basins~~plant or as a basin becomes inactive.

DTE Energy Company — DTE Electric Company

Combined Notes to ~~steel and concrete tanks.~~Consolidated Financial Statements — (Continued)

In November 2015, the EPA finalized ~~effluent limitations guidelines~~the ELG Rule for the steam electric power generating industry which may require additional controls to be installed between 2018 and 2023. ~~Certain effluent limitations guidelines~~Compliance schedules for individual facilities and individual waste streams are determined through issuance of new wastewater permits by the State of Michigan. The State of Michigan has issued a National Pollutant Discharge Elimination System permit for the Belle River Power Plant establishing a compliance deadline of December 31, 2021. No new permits have been issued for other facilities, consequently no compliance timelines have been established. Under the current rule, certain ELG requirements ~~will~~would be required to be performed in conjunction with the ~~coal combustion residuals requirements. Costs~~CCR. Over the next six years, to comply with the ELG requirements of the November 2015 rules and for the CRR requirements, costs associated with the building of new facilities ~~over the next seven years to comply with coal combustion residuals requirements and effluent limitations guidelines~~or installation of controls are estimated to be approximately ~~$290~~$295 million. ~~See Note 7~~

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 ~~Consolidated Financial Statements, "Asset Retirement Obligations",~~ELG rule. The final rule was published on September 18, 2017, which extended the earliest compliance deadlines for ~~estimated~~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 ~~closure of old facilities.~~the ELG Rule.

~~108~~

~~DTE Energy Company — DTE Electric Company~~

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

DTE Gas

Contaminated and Other Sites— DTE Gas owns or previously owned, 14 former MGP sites. Investigations have revealed contamination related to the by-products of gas manufacturing at each site. Cleanup of ~~five~~six of the MGP sites is complete and the sites are closed. DTE Gas has also completed partial closure of ~~two~~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 December 31, ~~2015~~2017 and ~~2014,~~2016, DTE Gas had ~~$22~~$41 million and ~~$24~~$43 million accrued for remediation, respectively. Any change in assumptions, such as remediation techniques, nature and extent of contamination, and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect DTE Gas' financial position and cash flows. DTE Gas anticipates the cost amortization methodology approved by the MPSC, which allows for amortization of the MGP costs over a ten-year period beginning with the year subsequent to the year the MGP costs were incurred, will prevent environmental costs from having a material adverse impact on DTE Gas' results of operations.

Non-utility

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

The Michigan coke battery facility received and responded to information requests from the EPA that resulted in the issuance of a NOV in June 2007 alleging potential maximum achievable control technologies and new source review violations. The EPA is in the process of reviewing DTE Energy’s position of demonstrated compliance and has not initiated escalated enforcement. At this time, DTE Energy cannot predict the impact of this issue but expects no further action. Furthermore, the Michigan coke battery facility is the subject of an investigation by the MDEQ concerning visible emissions readings that resulted from DTE Energy self reporting to MDEQ questionable activities by an employee of a contractor hired by DTE Energy to perform the visible emissions readings. At this time, DTE Energy cannot predict the impact of this investigation.

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

The Shenango coke battery received an NOV from the Allegheny County, PA Health Department pertaining to excessive opacity readings from fugitive sources in excess of its standards for the Pennsylvania coke battery facility. Fugitive sources at the plant are in full compliance with the applicable Federal Opacity Standards. DTE Energy agreed to a Consent Order and Agreement with Allegheny County pursuant to which DTE Energy paid a fine of $300,000 and spent $300,000 for a supplemental environmental project. In May 2014, the Group Against Smog & Pollution (GASP) filed a complaint alleging that DTE Energy's coke battery facility in Pennsylvania was in violation of visible emissions limits under the Federal Clean Air Act and/or Article XXI of the Allegheny County, PA Health Department's Rules and Regulations. DTE Energy believed that the GASP suit was without merit and filed a motion to dismiss in July 2014. In March 2015, the U.S. District Court granted DTE Energy's motion for dismissal. In April 2015, GASP filed a notice of appeal. In January 2016, the U.S. Court of Appeals for the Third Circuit affirmed the judgment of dismissal.

Other

In 2010, the EPA finalized a new ~~1-hour sulfur dioxide~~one-hour SO₂ ambient air quality standard that requires states to submit plans and associated timelines for non-attainment areas ~~to be~~that demonstrate attainment with the new SO₂ standard in ~~compliance by 2018.~~ 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 ~~sulfur dioxide~~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~~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.

~~109~~Michigan's Phase 2 non-attainment area includes DTE Electric facilities in St. Clair County. State implementation plans (SIPs) for Phase 2 areas describing the control strategy and timeline for demonstrating compliance with the new SO₂ standard are due to the EPA by April 2018. DTE Energy is currently working with the MDEQ to develop the required SIP. DTE Energy is unable to determine the full impact of the SIP strategy, as it is currently under development.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

~~Nuclear Operations~~

~~Property Insurance~~

DTE Electric maintains property insurance policies specifically for the Fermi 2 plant. These policies cover such items as replacement power and property damage. NEIL is the primary supplier of the insurance policies.

DTE Electric maintains a policy for extra expenses, including replacement power costs necessitated by Fermi 2’s unavailability due to an insured event. This policy has a 12-week waiting period and provides an aggregate $490 million of coverage over a three-year period.

DTE Electric has $1.5 billion in primary coverage and $1.25 billion of excess coverage for stabilization, decontamination, debris removal, repair and/or replacement of property, and decommissioning. The combined coverage limit for total property damage is $2.75 billion. The total limit for property damage for non-nuclear events is $2 billion and an aggregate of $328 million of coverage for extra expenses over a two-year period.

On January 13, 2015, the Terrorism Risk Insurance Program Reauthorization Act of 2015 was signed, extending TRIA through December 31, 2020. For multiple terrorism losses caused by acts of terrorism not covered under the TRIA occurring within one year after the first loss from terrorism, the NEIL policies would make available to all insured entities up to $3.2 billion, plus any amounts recovered from reinsurance, government indemnity, or other sources to cover losses.

Under NEIL policies, DTE Electric could be liable for maximum assessments of up to approximately $45 million per event if the loss associated with any one event at any nuclear plant should exceed the accumulated funds available to NEIL.

~~Public Liability Insurance~~

As required by federal law, DTE Electric maintains $375 million of public liability insurance for a nuclear incident. For liabilities arising from a terrorist act outside the scope of TRIA, the policy is subject to one industry aggregate limit of $300 million. Further, under the Price-Anderson Amendments Act of 2005, deferred premium charges up to $127 million could be levied against each licensed nuclear facility, but not more than $19 million per year per facility. Thus, deferred premium charges could be levied against all owners of licensed nuclear facilities in the event of a nuclear incident at any of these facilities.

~~Nuclear Fuel Disposal Costs~~

In accordance with the Federal Nuclear Waste Policy Act of 1982, DTE Electric has a contract with the DOE for the future storage and disposal of spent nuclear fuel from Fermi 2 that required DTE Electric to pay the DOE a fee of 1 mill per kWh of Fermi 2 electricity generated and sold. The fee was a component of nuclear fuel expense. The DOE's Yucca Mountain Nuclear Waste Repository program for the acceptance and disposal of spent nuclear fuel was terminated in 2011. DTE Electric is a party in the litigation against the DOE for both past and future costs associated with the DOE's failure to accept spent nuclear fuel under the timetable set forth in the Federal Nuclear Waste Policy Act of 1982. In July 2012, DTE Electric executed a settlement agreement with the federal government for costs associated with the DOE's delay in acceptance of spent nuclear fuel from Fermi 2 for permanent storage. The settlement agreement, including extensions, provides for a claims process and payment of delay-related costs experienced by DTE Electric through 2016. DTE Electric's claims are being settled and paid on a timely basis. The settlement proceeds reduce the cost of the dry cask storage facility assets and provide reimbursement for related operating expenses. The 1 mill per kWh DOE fee was reduced to zero effective May 16, 2014.

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

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

~~110~~

~~DTE Energy Company — DTE Electric Company~~

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

Synthetic Fuel Guarantees

DTE Energy discontinued the operations of its synthetic fuel production facilities throughout the United States as of December 31, 2007. DTE Energy provided certain guarantees and indemnities in conjunction with the sales of interests in its synfuel facilities. The guarantees cover potential commercial, environmental, oil price, and tax-related obligations that will survive until 90 days after expiration of all applicable statutes of limitations. DTE Energy estimates that its maximum potential liability under these guarantees at December 31, ~~2015 is~~2017 was approximately ~~$850~~$620 million. Payment under these guarantees is considered remote.

REF Guarantees

DTE Energy has provided certain guarantees and indemnities in conjunction with the sales of interests in or lease of its REF facilities. The guarantees cover potential commercial, environmental, and tax-related obligations that will survive until 90 days after expiration of all applicable statutes of limitations. DTE Energy estimates that its maximum potential liability under these guarantees at December 31, ~~2015 is~~2017 was approximately ~~$268~~$386 million. Payment under these guarantees is considered remote.

NEXUS Guarantees

NEXUS entered into certain 15-year capacity lease agreements for the transportation of natural gas with DTE Gas and Texas Eastern Transmission, LP, an unrelated third party. Pursuant to the terms of those agreements, in December 2016, DTE Energy executed separate guarantee agreements with DTE Gas and Texas Eastern Transmission, LP, with maximum potential payments totaling $80 million and $10 million at December 31, 2017, 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~~$55 million at December 31, ~~2015.~~2017. Payment under these guarantees is considered remote.

DTE Energy is periodically required to obtain performance surety bonds in support of obligations to various governmental entities and other companies in connection with its operations. As of December 31, ~~2015,~~2017, DTE Energy had approximately ~~$55~~$58 million of performance bonds outstanding. In the event that such bonds are called for nonperformance, DTE Energy would be obligated to reimburse the issuer of the performance bond. DTE Energy is released from the performance bonds as the contractual performance is completed and does not believe that a material amount of any currently outstanding performance bonds will be called.

Labor Contracts

There are several bargaining units for DTE ~~Energy's approximately 4,900~~Energy subsidiaries' approximate 5,000 represented employees, including DTE Electric's ~~approximately 2,600~~approximate 2,700 represented employees. The majority of the represented employees are under contracts that expire in ~~2016~~2020 and ~~2017.~~2021.

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

Purchase Commitments

As of December 31, ~~2015,~~2017, the Registrants were party to numerous long-term purchase commitments relating to a variety of goods and services required for their businesses. These agreements primarily consist of fuel supply commitments and renewable energy contracts for the Registrants, as well as energy trading contracts for DTE Energy. The Registrants estimate the following commitments from ~~2016~~2018 through 2051 for DTE Energy, and ~~2016~~2018 through 2033 for DTE Electric, as detailed in the following table:


	DTE Energy		DTE Electric		DTE Energy		DTE Electric
	(In millions)				(In millions)
2016	$	2,038	$	493
2017	1,160		412
2018	611		240		$	2,731	$	930
2019	397		120		1,045		320
2020	353		88		638		192
2021 and thereafter	3,043		992
2021					474		149
2022					371		88
2023 and thereafter					2,277		820
	$	7,602	$	2,345	$	7,536	$	2,499

~~DTE Energy and DTE Electric expect that 2016 annual~~Utility capital expenditures, expenditures for non-utility businesses, and contributions to equity method investees will be approximately ~~$2.7~~$3.6 billion and ~~$1.6~~$1.9 billion in 2018 for DTE Energy and DTE Electric, respectively. The Registrants have made certain commitments in connection with the estimated ~~2016~~2018 annual capital expenditures and contributions to equity method investees.

~~111~~

~~DTE Energy Company — DTE Electric Company~~

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

~~Bankruptcies~~

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

~~Michigan Sales and Use Tax Litigation~~

In 2010, the Michigan Department of Treasury finalized a sales and use tax audit of DTE Electric for the period from January 2003 to September 2006. It determined that DTE Electric’s electric distribution equipment was not eligible for an industrial-processing exemption and therefore was subject to the use tax. DTE Electric paid the tax for the period under audit and filed a claim in the Michigan Court of Claims disputing the tax determination. DTE Electric has continued to apply an appropriate industrial-processing exemption percentage, where applicable, for purchases in the years subsequent to 2006.

The Michigan Court of Claims found in favor of DTE Electric, and that determination was subsequently appealed to the Michigan Supreme Court. In July 2015, the Michigan Supreme Court issued an opinion finding that DTE Electric was eligible for a partial industrial-processing exemption on its electric distribution equipment based on the proportion of exempt use of that equipment. The Supreme Court reversed the lower court decision in part and remanded the case to the Michigan Court of Claims. DTE Electric reached a settlement with the Michigan Department of Treasury in February 2016 and will receive a partial refund of amounts previously paid.

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 89 and 1213 to the Consolidated Financial Statements, "Regulatory Matters" and "Financial and Other Derivative ~~Instruments",~~Instruments," respectively.

NOTE 19 — NUCLEAR OPERATIONS

Property Insurance

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

Under NEIL policies, DTE Electric could be liable for maximum assessments of up to approximately $47 million per event if the loss associated with any one event at any nuclear plant should exceed the accumulated funds available to NEIL.

Public Liability Insurance

As required by federal law, DTE Electric maintains $450 million of public liability insurance for a nuclear incident. For liabilities arising from a terrorist act outside the scope of TRIA, the policy is subject to one industry aggregate limit of $300 million. Further, under the Price-Anderson Amendments Act of 2005, deferred premium charges up to $127 million could be levied against each licensed nuclear facility, but not more than $19 million per year per facility. Thus, deferred premium charges could be levied against all owners of licensed nuclear facilities in the event of a nuclear incident at any of these facilities.

Nuclear Fuel Disposal Costs

The DOE's Yucca Mountain Nuclear Waste Repository program for the acceptance and disposal of spent nuclear fuel was terminated in 2011. DTE Electric is a party in the litigation against the DOE for both past and future costs associated with the DOE's failure to accept spent nuclear fuel under the timetable set forth in the Federal Nuclear Waste Policy Act of 1982. In July 2012, DTE Electric executed a settlement agreement with the federal government for costs associated with the DOE's delay in acceptance of spent nuclear fuel from Fermi 2 for permanent storage. The settlement agreement, including extensions, provides for a claims process and payment of delay-related costs experienced by DTE Electric through 2019. DTE Electric's claims are being settled and paid on a timely basis. The settlement proceeds reduce the cost of the dry cask storage facility assets and provide reimbursement for related operating expenses.

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

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

NOTE 1820 — RETIREMENT BENEFITS AND TRUSTEED ASSETS

DTE Energy's subsidiary, DTE Energy Corporate Services, LLC (LLC), sponsors defined benefit pension plans and other postretirement plans covering substantially all employees of the Registrants.

The table below represents the pension and other postretirement benefit plans which employees of each Registrant participated at December 31, 2017:



	Registrants
	DTE Energy	DTE Electric
Qualified Pension Plans
DTE Energy Company Retirement Plan	X	X
DTE Gas Company Retirement Plan for Employees Covered by Collective Bargaining Agreements	X
Shenango Inc. Pension Plan	X
Nonqualified Pension Plans
DTE Energy Company Supplemental Retirement Plan	X	X
DTE Energy Company Executive Supplemental Retirement Plan^(a)	X	X
DTE Energy Company Supplemental Severance Benefit Plan	X
Other Postretirement Benefit Plans
The DTE Energy Company Comprehensive Non-Health Welfare Plan	X	X
The DTE Energy Company Comprehensive Retiree Group Health Care Plan	X	X
DTE Supplemental Retiree Benefit Plan	X	X
DTE Energy Company Retiree Reimbursement Arrangement Plan	X	X


(a)	Sponsored by the DTE Energy subsidiary, DTE Energy Holding Company.

DTE Electric participates in various plans that provide pension and other postretirement benefits for DTE Energy and its affiliates. The plans are sponsored by the LLC. DTE Electric accounts for its participation in DTE Energy's qualified and 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. Plan participants of all plans are solely DTE Energy and affiliate employees.

Pension Plan Benefits

DTE Energy has qualified defined benefit retirement plans for eligible represented and non-represented employees. The plans are noncontributory and provide traditional retirement benefits based on the ~~employees’~~employee's years of benefit service, average final compensation, and age at retirement. In addition, certain represented and non-represented employees are covered under cash balance provisions that determine benefits on annual employer contributions and interest credits. DTE Energy also maintains supplemental nonqualified, noncontributory, retirement benefit plans for selected management employees. These plans provide for benefits that supplement those provided by DTE Energy’s other retirement plans.

DTE Energy Company — DTE Electric ~~participates in various plans that provide~~Company

Combined Notes to Consolidated Financial Statements — (Continued)

Net pension ~~and other postretirement benefits~~cost for DTE Energy ~~and its affiliates. The plans are sponsored by DTE Energy Corporate Services, LLC (LLC), a subsidiary of DTE Energy. DTE Electric is allocated net periodic benefit costs for its share of~~includes the ~~amounts of the combined plans.~~following components:

Effective January 1, 2012 for the Registrants' non-represented employees, and in June 2011 for certain DTE Energy represented employees and March 2013 for the majority of DTE Electric represented employees, the Registrants discontinued offering a defined benefit retirement plan to newly hired employees. In its place, the Registrants will annually contribute an amount equivalent to 4% (8% for certain DTE Gas represented employees) of an employee's eligible pay to the employee's defined contribution retirement savings plan.



	2017			2016			2015
	(In millions)
Service cost	$	92		$	92		$	100
Interest cost	214			219			210
Expected return on plan assets	(311		)	(309		)	(296		)
Amortization of:
Net actuarial loss	176			164			205
Prior service cost	1			1			—
Other	—			—			2
Net pension cost	$	172		$	167		$	221

~~112~~



	2017			2016
	(In millions)
Other changes in plan assets and benefit obligations recognized in Regulatory assets and Other comprehensive income (loss)
Net actuarial loss	$	27		$	197
Amortization of net actuarial loss	(176		)	(164		)
Prior service cost (credit)	(11		)	7
Amortization of prior service cost	(1		)	(1		)
Total recognized in Regulatory assets and Other comprehensive income (loss)	$	(161	)	$	39
Total recognized in net periodic pension cost, Regulatory assets, and Other comprehensive income (loss)	$	11		$	206
Estimated amounts to be amortized from Regulatory assets and Accumulated other comprehensive income (loss) into net periodic benefit cost during next fiscal year
Net actuarial loss	$	178		$	172
Prior service cost	$	—		$	1

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

The following table reconciles the obligations, assets, and funded status of the plans as well as the amounts recognized as prepaid pension cost or pension liability in DTE Energy's Consolidated Statements of Financial Position at December 31:



	DTE Energy
	2017			2016
	(In millions)
Accumulated benefit obligation, end of year	$	5,149		$	4,753
Change in projected benefit obligation
Projected benefit obligation, beginning of year	$	5,171		$	4,971
Service cost	92			92
Interest cost	214			219
Plan amendments	(11		)	7
Actuarial loss	391			141
Benefits paid	(281		)	(259		)
Projected benefit obligation, end of year	$	5,576		$	5,171
Change in plan assets
Plan assets at fair value, beginning of year	$	4,012		$	3,832
Actual return on plan assets	674			253
Company contributions	231			186
Benefits paid	(281		)	(259		)
Plan assets at fair value, end of year	$	4,636		$	4,012
Funded status	$	(940	)	$	(1,159	)
Amount recorded as:
Current liabilities	$	(16	)	$	(7	)
Noncurrent liabilities	(924		)	(1,152		)
	$	(940	)	$	(1,159	)
Amounts recognized in Accumulated other comprehensive income (loss), pre-tax
Net actuarial loss	$	163		$	163
Prior service cost	6			8
	$	169		$	171
Amounts recognized in Regulatory assets^(a)
Net actuarial loss	$	2,014		$	2,163
Prior service credit	(14		)	(4		)
	$	2,000		$	2,159


(a)	See Note 9 to the Consolidated Financial Statements, "Regulatory Matters."

The Registrants' policy is to fund pension costs by contributing amounts consistent with the provisions of the Pension Protection Act of 2006, and additional amounts when it deems appropriate. ~~DTE Energy contributed $177 million, including $145 million of DTE Electric~~The following table provides cash contributions to the qualified pension plans ~~in 2015.~~ as of December 31:



	2017		2016		2015
	(In millions)
DTE Energy	$	223	$	179	$	177
DTE Electric	185		145		145

At the discretion of management, and depending upon financial market conditions, DTE Energy anticipates making up to ~~$180~~$200 million in contributions, including ~~$145~~$175 million of DTE Electric contributions, to the qualified pension plans in ~~2016.~~2018.

~~Net pension cost for DTE Energy includes the following components:~~

2015 2014 2013
(In millions)
Service cost $ 100
$ 83
$ 94
Interest cost 210
212
192
Expected return on plan assets (296 ) (273 ) (266 )
Amortization of net actuarial loss 205
157
208
Special termination benefits 2
—
—
Net pension cost $ 221
$ 179
$ 228

2015 2014
(In millions)
Other changes in plan assets and benefit obligations recognized in Regulatory assets and Other comprehensive income (loss)
Net actuarial loss $ 19
$ 805
Amortization of net actuarial loss (205 ) (157 )
Prior service credit —
(7 )
Total recognized in Regulatory assets and Other comprehensive income (loss) $ (186 ) $ 641
Total recognized in net periodic pension cost, Regulatory assets, and Other comprehensive income (loss) $ 35
$ 820
Estimated amounts to be amortized from Regulatory assets and Accumulated other comprehensive income (loss) into net periodic benefit cost during next fiscal year
Net actuarial loss $ 162
$ 206

~~Net pension cost for DTE Electric includes the following components:~~

2015 2014 2013
(In millions)
Service cost $ 77
$ 64
$ 73
Interest cost 160
162
146
Expected return on plan assets (210 ) (194 ) (184 )
Amortization of:
Net actuarial loss 147
110
148
Prior service cost 1
2
1
Special termination benefits 1
—
—
Net pension cost $ 176
$ 144
$ 184

~~113~~

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

2015 2014
(In millions)
Other changes in plan assets and benefit obligations recognized in Regulatory assets and Other comprehensive income (loss)
Net actuarial (gain) loss $ (13 ) $ 614
Amortization of net actuarial loss (147 ) (110 )
Prior service credit —
(2 )
Amortization of prior service cost (1 ) (2 )
Total recognized in Regulatory assets and Other comprehensive income (loss) $ (161 ) $ 500
Total recognized in net periodic pension cost, Regulatory assets, and Other comprehensive income (loss) $ 15
$ 644
Estimated amounts to be amortized from Regulatory assets and Accumulated other comprehensive income (loss) into net periodic benefit cost during next fiscal year
Net actuarial loss $ 115
$ 149
Prior service cost $ 1
$ 1

The following table reconciles the obligations, assets, and funded status of the plans as well as the amounts recognized as prepaid pension cost or pension liability in the Registrants' Consolidated Statements of Financial Position at December 31:

DTE Energy DTE Electric
2015 2014 2015 2014
(In millions)
Accumulated benefit obligation, end of year $ 4,569
$ 4,853
$ 3,401
$ 3,712
Change in projected benefit obligation
Projected benefit obligation, beginning of year $ 5,269
$ 4,380
$ 4,018
$ 3,341
Service cost 100
83
75
64
Interest cost 210
212
156
162
Plan amendments —
(7 ) —
(2 )
Actuarial (gain) loss (357 ) 836
(273 ) 634
Transfer due to plan sponsorship change —
—
(99 ) —
Special termination benefits 2
—
—
—
Benefits paid (253 ) (235 ) (192 ) (181 )
Projected benefit obligation, end of year $ 4,971
$ 5,269
$ 3,685
$ 4,018
Change in plan assets
Plan assets at fair value, beginning of year $ 3,981
$ 3,720
$ 2,812
$ 2,632
Actual return on plan assets (79 ) 301
(56 ) 212
Company contributions 183
195
145
149
Benefits paid (253 ) (235 ) (192 ) (181 )
Plan assets at fair value, end of year $ 3,832
$ 3,981
$ 2,709
$ 2,812
Funded status of the plans $ (1,139 ) $ (1,288 ) $ (976 ) $ (1,206 )
Amount recorded as:
Current liabilities $ (6 ) $ (8 ) $ —
$ (6 )
Noncurrent liabilities (1,133 ) (1,280 ) (976 ) (1,200 )
$ (1,139 ) $ (1,288 ) $ (976 ) $ (1,206 )
Amounts recognized in Accumulated other comprehensive income (loss), pre-tax
Net actuarial loss $ 180
$ 194
$ —
$ 44
Prior service credit (1 ) (1 ) —
—
$ 179
$ 193
$ —
$ 44
Amounts recognized in Regulatory assets (see Note 8 - "Regulatory Matters")
Net actuarial loss $ 2,113
$ 2,285
$ 1,588
$ 1,738
Prior service cost (credit) (1 ) (1 ) 4
5
$ 2,112
$ 2,284
$ 1,592
$ 1,743

~~114~~

DTE ~~Energy Company —~~Energy's subsidiaries are responsible for their share of qualified and nonqualified pension benefit costs. DTE ~~Electric Company~~Electric's allocated portion of pension benefit costs included in capital expenditures and operating and maintenance expense were $136 million for the years ended December 31, 2017 and 2016, and $176 million for the year ended December 31, 2015. These amounts include recognized contractual termination benefit charges, curtailment gains, and settlement charges.

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

At December 31, ~~2015,~~2017, the benefits related to ~~the Registrants'~~DTE Energy's qualified and nonqualified pension plans expected to be paid in each of the next five years and in the aggregate for the five fiscal years thereafter are as follows:


	DTE Energy		DTE Electric		(In millions)
	(In millions)
2016	$	274	$	213
2017	285		221
2018	297		231		$	299
2019	306		238		301
2020	314		244		316
2021-2025	1,662		1,279
2021					317
2022					323
2023-2027					1,692
Total	$	3,138	$	2,426	$	3,248

Assumptions used in determining the projected benefit obligation and net pension costs of ~~the Registrants~~DTE Energy are:


	2015	2014	2013	2017	2016	2015
Projected benefit obligation
Discount rate	4.50%	4.12%	4.95%	3.70%	4.25%	4.50%
Rate of compensation increase	4.65%	4.65%	4.20%	4.98%	4.65%	4.65%
Net pension costs
Discount rate	4.12%	4.95%	4.15%	4.25%	4.50%	4.12%
Rate of compensation increase	4.65%	4.20%	4.20%	4.65%	4.65%	4.65%
Expected long-term rate of return on plan assets	7.75%	7.75%	8.25%	7.50%	7.75%	7.75%

~~The Registrants employ~~DTE Energy employs a formal process in determining the long-term rate of return for various asset classes. Management reviews historic financial market risks and returns and long-term historic relationships between the asset classes of equities, fixed income, and other assets, consistent with the widely accepted capital market principle that asset classes with higher volatility generate a greater return over the long-term. Current market factors such as inflation, interest rates, asset class risks, and asset class returns are evaluated and considered before long-term capital market assumptions are determined. The long-term portfolio return is also established employing a consistent formal process, with due consideration of diversification, active investment management, and rebalancing. Peer data is reviewed to check for reasonableness. As a result of this process, the Registrants have long-term rate of return assumptions for the pension plans of ~~7.75%~~7.50% and other postretirement benefit plans of ~~8.00%~~7.75% for ~~2016.~~2018. The Registrants believe these rates are a reasonable assumption for the long-term rate of return on plan assets for ~~2016~~2018 given the current investment strategy.

~~The Registrants employ~~DTE Energy employs a total return investment approach whereby a mix of equities, fixed income, and other investments are used to maximize the long-term return on plan assets consistent with prudent levels of risk, with consideration given to the liquidity needs of the plan. Risk tolerance is established through consideration of future plan cash flows, plan funded status, and corporate financial considerations. The investment portfolio contains a diversified blend of equity, fixed income, and other investments. Furthermore, equity investments are diversified across U.S. and non-U.S. stocks, growth and value stocks, and large and small market capitalizations. Fixed income securities generally include market duration bonds of companies from diversified industries, mortgage-backed securities, non-U.S. securities, bank loans, and U.S. Treasuries. Pension assets include long duration U.S. government and diversified corporate bonds intended to partially mitigate liability volatility caused by changes in discount rates. Other assets, such as private markets and hedge funds, are used to enhance long-term returns while improving portfolio diversification. Derivatives may be utilized in a risk controlled manner, to potentially increase the portfolio beyond the market value of invested assets and/or reduce portfolio investment risk. Investment risk is measured and monitored on an ongoing basis through annual liability measurements, periodic asset/liability studies, and quarterly investment portfolio reviews.

~~115~~

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

Target allocations for ~~the Registrants'~~DTE Energy's pension plan assets as of December 31, ~~2015~~2017 are listed below:



U.S. Large Capitalization (Cap) Equity Securities	2218	%
U.S. Small Cap and Mid Cap Equity Securities	5
Non-U.S. Equity Securities	2017
Fixed Income Securities	2532
Hedge Funds and Similar Investments	20
Private Equity and Other	8
	100	%

~~116~~

~~DTE Energy Company — DTE Electric Company~~

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

The following tables provide the fair value measurement amounts for ~~the Registrants'~~DTE Energy's pension plan assets at December 31, ~~2015~~2017 and ~~2014~~ 2016^(a):


	December 31, 2015											December 31, 2014											December 31, 2017											December 31, 2016
	Level 1			Level 2			Level 3		Total			Level 1			Level 2			Level 3		Total			Level 1			Level 2			Other^(b)		Total			Level 1			Level 2			Other^(b)		Total
	(In millions)																						(In millions)
DTE Energy asset category:
Short-term Investments ~~(b)~~(c)	$	23		$	—		$	—	$	23		$	46		$	—		$	—	$	46		$	—		$	114		$	—	$	114		$	—		$	22		$	—	$	22
Equity Securities
U.S. Large Cap ~~(c)~~(d)	842			—			—		842			899			—			—		899			821			5			—		826			875			5			—		880
U.S. Small Cap and Mid Cap ~~(d)~~(e)	219			—			—		219			225			—			—		225			229			5			—		234			229			3			—		232
Non-U.S. ~~(e)~~(f)	510			251			—		761			526			219			—		745			529			13			280		822			479			18			269		766
Fixed Income Securities ~~(f)~~(g)	5			1,024			—		1,029			7			1,113			—		1,120			1			1,453			—		1,454			1			1,037			52		1,090
Hedge Funds and Similar Investments ~~(g)~~(h)	220			96			452		768			226			95			438		759			265			—			593		858			231			—			578		809
Private Equity and Other ~~(h)~~(i)	—			—			190		190			—			—			187		187			—			—			328		328			—			—			213		213
Securities Lending ~~(i)~~(j)	(129		)	(25		)	—		(154		)	(189		)	(50		)	—		(239		)	(53		)	(13		)	—		(66		)	(53		)	(25		)	—		(78		)
Securities Lending Collateral ~~(i)~~(j)	129			25			—		154			189			50			—		239			53			13			—		66			53			25			—		78
DTE Energy Total	$	1,819		$	1,371		$	642	$	3,832		$	1,929		$	1,427		$	625	$	3,981		$	1,845		$	1,590		$	1,201	$	4,636		$	1,815		$	1,085		$	1,112	$	4,012

DTE Electric asset category:
Short-term Investments (b)	$	16		$	—		$	—	$	16		$	33		$	—		$	—	$	33
Equity Securities
U.S. Large Cap (c)	599			—			—		599			638			—			—		638
U.S. Small Cap and Mid Cap (d)	157			—			—		157			162			—			—		162
Non-U.S. (e)	367			178			—		545			378			157			—		535
Fixed Income Securities (f)	4			699			—		703			5			758			—		763
Hedge Funds and Similar Investments (g)	158			69			325		552			163			68			315		546
Private Equity and Other (h)	—			—			137		137			—			—			135		135
Securities Lending (i)	(93		)	(18		)	—		(111		)	(136		)	(36		)	—		(172		)
Securities Lending Collateral (i)	93			18			—		111			136			36			—		172
DTE Electric Total	$	1,301		$	946		$	462	$	2,709		$	1,379		$	983		$	450	$	2,812


(a)	For a description of levels within the fair value hierarchy, see Note 1112 to the Consolidated Financial Statements, "Fair ~~Value".~~Value."


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


(c)	This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category are obtained from quoted prices in actively traded markets or valuations from brokers or pricing services.


~~(c)~~(d)	This category ~~comprises both actively and not actively managed~~represents portfolios ~~that track the S&P 500 low cost equity index funds.~~of large capitalization domestic equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. ~~Exchange-traded securities held in a commingled fund are classified as Level 2 assets.~~


~~(d)~~(e)	This category represents portfolios of small and medium capitalization domestic equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. ~~Exchange-traded securities held in a commingled fund are classified as Level 2 assets.~~


~~(e)~~(f)	This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as ~~Level 2~~NAV assets.


~~(f)~~(g)	This category includes corporate bonds from diversified industries, U.S. Treasuries, and mortgage-backed securities. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. Non-exchange traded securities and exchange-traded securities held in commingled funds are classified as ~~Level 2~~NAV assets.

~~(g)~~(h)

This category utilizes a diversified group of strategies that attempt to capture financial market inefficiencies and includes publicly traded ~~debt and equity, publicly traded~~ mutual funds, commingled funds and limited partnership ~~funds, and non-exchange traded securities.~~funds. Pricing for ~~Level 1 and Level 2 assets~~mutual funds in this category is obtained from quoted prices in actively traded ~~markets and quoted prices from broker~~markets. Commingled funds or ~~pricing services. Non-exchange traded securities held in commingled~~limited partnership funds are classified as ~~Level 2~~NAV assets. ~~Valuations for some Level 3 assets in this category may be based on limited observable inputs as there may be little, if any, publicly available pricing.~~

~~(h)~~(i)

This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in timber and private mezzanine debt. ~~Pricing~~All pricing for investments in this category ~~is based on limited observable inputs~~are classified as there is little, if any, publicly available pricing. Valuations for assets in this category may be based on discounted cash flow analyses, relevant publicly-traded comparables, and comparable transactions.NAV assets.


~~(i)~~(j)	~~In 2014, the Registrants began~~DTE Energy has a securities lending program with a third-party agent. The program allows the agent to lend certain securities from ~~the Registrants'~~DTE Energy's pension trusts to selected entities against receipt of collateral (in the form of cash) as provided for and determined in accordance with their securities lending agency agreements.

~~117~~

DTE Energy Company — DTE Electric Company

Combined Notes to Consolidated Financial Statements — (Continued)

The pension trust holds debt and equity securities directly and indirectly through commingled funds and institutional mutual funds. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. The commingled funds and institutional mutual funds hold exchange-traded equity or debt securities and are valued based on stated NAVs. Non-exchange traded fixed income securities are valued by the trustee based upon quotations available from brokers or pricing services. A primary price source is identified by asset type, class, or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustee challenges an assigned price and determines that another price source is considered ~~to be~~ preferable. ~~The Registrants have~~DTE Energy has obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices. Additionally, ~~the Registrants~~DTE Energy selectively ~~corroborate~~corroborates the fair ~~values~~value of securities by comparison of market-based price sources.

The following table provides a reconciliation of beginning and ending balances of DTE Energy's pension plan assets measured at fair value on a recurring basis where the determination of fair value includes significant unobservable inputs (Level 3):

Year Ended December 31, 2015 Year Ended December 31, 2014
Hedge Funds
and Similar
Investments Private Equity
and Other Total Hedge Funds
and Similar
Investments Private Equity
and Other Total
(In millions)
Beginning Balance at January 1 $ 438
$ 187
$ 625
$ 395
$ 170
$ 565
Total realized/unrealized gains (losses) 10
10
20
22
16
38
Purchases, sales, and settlements:
Purchases 4
32
36
22
31
53
Sales —
(39 ) (39 ) (1 ) (30 ) (31 )
Ending Balance at December 31 $ 452
$ 190
$ 642
$ 438
$ 187
$ 625
The amount of total gains for the period attributable to the change in unrealized gains or losses related to assets still held at the end of the period $ 10
$ (3 ) $ 7
$ 21
$ 11
$ 32

The following table provides a reconciliation of beginning and ending balances of DTE Electric's pension plan assets measured at fair value on a recurring basis where the determination of fair value includes significant unobservable inputs (Level 3):

Year Ended December 31, 2015 Year Ended December 31, 2014
Hedge Funds
and Similar
Investments Private Equity
and Other Total Hedge Funds
and Similar
Investments Private Equity
and Other Total
(In millions)
Beginning Balance at January 1 $ 315
$ 135
$ 450
$ 285
$ 122
407
Total realized/unrealized gains (losses) 7
7
14
15
12
27
Purchases, sales, and settlements:
Purchases 3
23
26
16
22
38
Sales —
(28 ) (28 ) (1 ) (21 ) (22 )
Ending Balance at December 31 $ 325
$ 137
$ 462
$ 315
$ 135
$ 450
The amount of total gains for the period attributable to the change in unrealized gains or losses related to assets still held at the end of the period $ 7
$ (2 ) $ 5
$ 15
$ 8
$ 23

There ~~were no transfers from or into Level 3 and there~~ were no significant transfers between Level 2 and Level 1 in the years ended December 31, ~~2015~~2017 and ~~2014~~2016 for ~~either of the Registrants.~~

~~118~~

DTE ~~Energy Company — DTE Electric Company~~Energy.

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



						Dividends Paid per Share
Year	Quarter	High		Low		Dividends Paid per Share
2015
	First	$	92.27	$	76.84	$	0.6900
	Second	$	84.27	$	73.23	$	0.6900
	Third	$	85.12	$	74.53	$	0.7300
	Fourth	$	85.36	$	77.35	$	0.7300
2014
	First	$	74.61	$	64.84	$	0.6550
	Second	$	79.45	$	72.76	$	0.6550
	Third	$	78.89	$	71.60	$	0.6900
	Fourth	$	90.77	$	75.76	$	0.6900



	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
10/01/2015 — 10/31/2015	1,576	$	79.43	—	—	—
11/01/2015 — 11/30/2015	2,436	$	78.53	—	—	—
12/01/2015 — 12/31/2015	1,900	$	78.42	—	—	—
Total	5,912			—



	Changes in Accumulated Other Comprehensive Income (Loss) by Component (a)
	Net Unrealized Gain on Investments		Benefit Obligations (b)			Total
	(In millions)
Balance, December 31, 2013	$	1	$	(17	)	$	(16	)
Other comprehensive loss before reclassifications	—		(12		)	(12		)
Amounts reclassified from Accumulated other comprehensive income	—		2			2
Net current-period Other comprehensive loss	—		(10		)	(10		)
Balance, December 31, 2014	$	1	$	(27	)	$	(26	)
Other comprehensive income before reclassifications	1		—			1
Transfer of amounts from Accumulated other comprehensive income to affiliate	—		27			27
Amounts reclassified from Accumulated other comprehensive income	—		—			—
Net current-period Other comprehensive income	1		27			28
Balance, December 31, 2015	$	2	$	—		$	2



	DTE Energy		DTE Electric
	Operating Leases		Operating Leases
	(In millions)
2016	$	37	$	24
2017	30		18
2018	25		15
2019	21		14
2020	13		10
Thereafter	71		35
Total minimum lease payments	$	197	$	116



	Year Ended December 31, 2015								Year Ended December 31, 2014
	Hedge Funds and Similar Investments		Private Equity and Other			Total			Hedge Funds and Similar Investments			Private Equity and Other			Total
	(In millions)
Beginning Balance at January 1	$	438	$	187		$	625		$	395		$	170		$	565
Total realized/unrealized gains (losses)	10		10			20			22			16			38
Purchases, sales, and settlements:
Purchases	4		32			36			22			31			53
Sales	—		(39		)	(39		)	(1		)	(30		)	(31		)
Ending Balance at December 31	$	452	$	190		$	642		$	438		$	187		$	625
The amount of total gains for the period attributable to the change in unrealized gains or losses related to assets still held at the end of the period	$	10	$	(3	)	$	7		$	21		$	11		$	32



U.S. Large Cap Equity Securities	1716	%
U.S. Small Cap and Mid Cap Equity Securities	4
Non-U.S. Equity Securities	20
Fixed Income Securities	2526
Hedge Funds and Similar Investments	20
Private Equity and Other	14
	100	%


~~(i)~~(j)	~~In 2014, the~~The Registrants ~~began~~have a securities lending program with a third-party agent. The program allows the agent to lend certain securities from the Registrants' VEBA trust to selected entities against receipt of collateral (in the form of cash) as provided for and determined in accordance with their securities lending agency agreements.



Date	Number of Shares	Price per Share	Amount
			(In millions)
February 17, 2015	1,427,835	$81.91	$	117
			$	117



	Number of Options		Weighted Average Exercise Price		Aggregate Intrinsic Value (In millions)
Options outstanding at December 31, 2014	444,278		$	43.56
Exercised	(178,017	)	$	45.07
Forfeited or expired	(3,979	)	$	44.72
Options outstanding and exercisable at December 31, 2015	262,282		$	42.52	$	10


Range of Exercise Prices	Range of Exercise Prices				Number of Options	Weighted Average Exercise Price		Weighted Average Remaining Contractual Life (Years)	Range of Exercise Prices				Number of Options	Weighted Average Exercise Price		Weighted Average Remaining Contractual Life (Years)
$	27.00	—	$	38.00	22,083	$	27.70	3.16	27.00	—	$	38.00	6,194	$	27.70	1.16
$	38.01	—	$	42.00	80,434	$	41.79	2.16	38.01	—	$	42.00	2,300	$	41.79	0.15
$	42.01	—	$	45.00	116,665	$	43.90	3.79	42.01	—	$	45.00	97,500	$	43.95	2.15
$	45.01	—	$	50.00	43,100	$	47.75	1.15
					262,282	$	42.52	2.80					105,994	$	42.95	2.05


	Restricted Stock		Weighted Average Grant Date Fair Value		Restricted Stock		Weighted Average Grant Date Fair Value
Balance at December 31, 2014	416,318		$	62.82
Balance at December 31, 2016					385,285		$	80.10
Grants	144,300		$	83.43	136,825		$	99.53
Forfeitures	(12,721	)	$	74.78	(11,745	)	$	90.24
Vested and issued	(165,453	)	$	55.73	(144,601	)	$	72.08
Balance at December 31, 2015	382,444		$	73.26
Balance at December 31, 2017					365,764		$	90.26


(a)	Sum of cash and stock settlements approximates the intrinsic value of the awards.


	Performance Shares		Weighted Average Grant Date Fair Value		Performance Shares		Weighted Average Grant Date Fair Value
Balance at December 31, 2014	1,554,697		$	69.32
Balance at December 31, 2016					1,392,512		$	79.97
Grants	467,288		$	83.85	494,688		$	98.47
Forfeitures	(47,067	)	$	76.22	(49,547	)	$	87.12
Payouts	(532,700	)	$	—	(513,252	)	$	70.60
Balance at December 31, 2015	1,442,218		$	75.85
Balance at December 31, 2017					1,324,401		$	90.31


	Unrecognized Compensation Cost		Weighted Average to be Recognized	Unrecognized Compensation Cost		Weighted Average to be Recognized
	(In millions)		(In years)	(In millions)		(In years)
Stock awards	$	11	1.11	$	13	1.12
Performance shares	37		0.97	51		1.11
	$	48	1.00	$	64	1.11


(a)	Includes Income Tax Expense (Benefit) of $(5) million, $(115) million, $(21) million, $2 million, and $34 million for Electric — non-utility, Gas Storage and Pipelines, Power and Industrial Projects, Energy Trading, and Corporate and Other, respectively, related to the enactment of the TCJA.



Note		Title
4		~~Acquisitions and Exit Activities~~
1820		Retirement Benefits and Trusteed Assets
1921		Stock-Based Compensation


	First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Year		First Quarter		Second Quarter		Third Quarter		Fourth Quarter		Year
	(In millions, except per share amounts)										(In millions, except per share amounts)
2015
2017
Operating Revenues											$	3,236	$	2,855	$	3,245	$	3,271	$	12,607
Operating Income											$	569	$	303	$	418	$	356	$	1,646
Net Income Attributable to DTE Energy Company^(a)											$	400	$	177	$	270	$	287	$	1,134
Basic Earnings per Share											$	2.23	$	0.99	$	1.51	$	1.60	$	6.32
Diluted Earnings per Share											$	2.23	$	0.99	$	1.51	$	1.60	$	6.32
2016
Operating Revenues	$	2,984	$	2,268	$	2,598	$	2,487	$	10,337	$	2,566	$	2,262	$	2,928	$	2,874	$	10,630
Operating Income	$	461	$	204	$	440	$	134	$	1,239	$	381	$	256	$	507	$	301	$	1,445
Net Income Attributable to DTE Energy Company	$	273	$	109	$	265	$	80	$	727	$	247	$	152	$	338	$	131	$	868
Basic Earnings per Share	$	1.53	$	0.61	$	1.47	$	0.45	$	4.05	$	1.38	$	0.84	$	1.88	$	0.73	$	4.84
Diluted Earnings per Share	$	1.53	$	0.61	$	1.47	$	0.45	$	4.05	$	1.37	$	0.84	$	1.88	$	0.73	$	4.83
2014
Operating Revenues	$	3,930	$	2,698	$	2,595	$	3,078	$	12,301
Operating Income	$	560	$	249	$	239	$	542	$	1,590
Net Income Attributable to DTE Energy Company	$	326	$	124	$	156	$	299	$	905
Basic Earnings per Share	$	1.84	$	0.70	$	0.88	$	1.68	$	5.11
Diluted Earnings per Share	$	1.84	$	0.70	$	0.88	$	1.68	$	5.10


(a)	Includes a net Income Tax Benefit of $(105) million related to the enactment of the TCJA in the fourth quarter.



	2015		2014
Audit fees (a)	$	1,329,245	$	1,337,674
Audit-related fees (b)	12,000		11,000
Total	$	1,341,245	$	1,348,674



	2017		2016
Audit fees^(a)	$	1,428,500	$	1,330,268
Audit-related fees^(b)	12,000		12,000
Total	$	1,440,500	$	1,342,268


(a)	Represents the aggregate fees for the audits of DTE Electric’s annual financial statements included in the Annual Reports on Form 10-K and for the reviews of the financial statements included in the Quarterly Reports on Form 10-Q.


(b)	Represents the aggregate fees billed for audit-related services for various attest services.


A.	The following documents are filed as part of this Annual Report on Form 10-K.


(1)	Consolidated Financial Statements. See “Item 8 — Financial Statements and Supplementary Data.”


(2)	Financial statement schedule. See “Item 8 — Financial Statements and Supplementary Data.”



Exhibit Number	Description	DTE Energy	DTE Electric

	(i) Exhibits filed herewith:

~~10.96~~	~~Third Amendment to the DTE Energy Company Executive Supplemental Retirement Plan (Amended and Restated Effective January 1, 2005) dated as of February 3, 2016~~	X

~~10.97~~	~~First Amendment to DTE Energy Company Executive Performance Plan Effective May 7, 2015, dated as of February 3, 2016~~	X

~~10.98~~	~~First Amendment to DTE Energy Company Executive Deferred Compensation Plan as Amended and Restated, effective as of January 1, 2005, dated as of February 4, 2016~~	X

~~10.99~~	~~First Amendment to DTE Energy Company Long-Term Incentive Plan Amended and Restated Effective May 1, 2014, dated as of February 4, 2016~~	X

~~12.65~~ 12.81	Computation of Ratio of Earnings to Fixed Charges	X

~~12.66~~ 12.82	Computation of Ratio of Earnings to Fixed Charges		X

~~21.11~~ 21.13	Subsidiaries of DTE Energy	X

~~23.30~~ 23.34	Consent of PricewaterhouseCoopers LLP	X

~~23.31~~ 23.35	Consent of PricewaterhouseCoopers LLP		X

~~31.109~~ 31.141	Chief Executive Officer Section 302 Form 10-K Certification of Periodic Report	X

~~31.110~~ 31.142	Chief Financial Officer Section 302 Form 10-K Certification of Periodic Report	X

~~31.111~~ 31.143	Chief Executive Officer Section 302 Form 10-K Certification of Periodic Report		X

~~31.112~~ 31.144	Chief Financial Officer Section 302 Form 10-K Certification of Periodic Report		X

101.INS	XBRL Instance Document	X	X

101.SCH	XBRL Taxonomy Extension Schema	X	X

101.CAL	XBRL Taxonomy Extension Calculation Linkbase	X	X

101.DEF	XBRL Taxonomy Extension Definition Database	X	X

101.LAB	XBRL Taxonomy Extension Label Linkbase	X	X

101.PRE	XBRL Taxonomy Extension Presentation Linkbase	X	X

	(ii) Exhibits furnished herewith:

~~32.109~~ 32.141	Chief Executive Officer Section 906 Form 10-K Certification of Periodic Report	X

~~32.110~~ 32.142	Chief Financial Officer Section 906 Form 10-K Certification of Periodic Report	X

~~32.111~~ 32.143	Chief Executive Officer Section 906 Form 10-K Certification of Periodic Report		X

~~32.112~~ 32.144	Chief Financial Officer Section 906 Form 10-K Certification of Periodic Report		X



	(iii) Exhibits incorporated by reference:

Certain exhibits listed below refer to "The Detroit Edison Company" and "Michigan Consolidated Gas Company" and were effective prior to the change to DTE Electric Company and DTE Gas Company, respectively, effective January 1, 2013.

3(a)	Amended Bylaws of DTE Energy Company, as amended through September 17, 2015 (Exhibit 3.1 to DTE Energy’s Form 8-K dated September 17, 2015).	X

3(b)	Amended and Restated Articles of Incorporation of DTE Energy Company, dated December 13, 1995 and as amended from time to time (Exhibit 3-1 to DTE Energy’s Form 8-K dated May 6, 2010).	X




Supplemental Indenture, dated as of March 1, 1950, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit B-22 to Detroit Edison's Registration Statement on Form S-1 (File No. 2-8290)). (amendment) (P)	X	X

Supplemental Indenture, dated as of November 15, 1951, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit B-23 to Detroit Edison's Registration Statement on Form S-1 (File No. 2-9226)). (amendment) (P)	X	X

Supplemental Indenture, dated as of August 15, 1957, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 3-B-30 to Detroit Edison's Form 8-K dated September 11, 1957). (amendment) (P)	X	X

Supplemental Indenture, dated as of December 1, 1966, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 2-B-32 to Detroit Edison's Registration Statement on Form S-9 (File No. 2-25664)). (amendment) (P)	X	X

Supplemental Indenture, dated as of February 15, 1990, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4-212 to Detroit Edison's Form 10-K for the year ended December 31, 2000). (1990 Series B)	X	X

Supplemental Indenture, dated as of May 1, 1991, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4-178 to Detroit Edison's Form 10-K for the year ended December 31, 1996). (1991 Series CP)	X	X

Supplemental Indenture, dated as of May 15, 1991, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4-179 to Detroit Edison's Form 10-K for the year ended December 31, 1996). (1991 Series DP)	X	X

Supplemental Indenture, dated as of February 29, 1992, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4-187 to Detroit Edison's Form 10-Q for the quarter ended March 31, 1998). (1992 Series AP)	X	X

Supplemental Indenture, dated as of April 26, 1993, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4-215 to Detroit Edison's Form 10-K for the year ended December 31, 2000). (amendment)	X	X



Supplemental Indenture, dated as of September 30, 2005, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between Detroit Edison and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4-248 to Detroit Edison's Form 10-Q for the quarter ended September 30, 2005). (2005 Series E)	X	X

Supplemental Indenture, dated as of May 15, 2006, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4-250 to Detroit Edison's Form 10-Q for the quarter ended June 30, 2006). (2006 Series A)	X	X

Supplemental Indenture, dated as of December 1, 2007, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and J.P. Morgan Trust Company, National Association, as successor trustee (Exhibit 4.2 to Detroit Edison's Form 8-K dated December 18, 2007). (2007 Series A)	X	X

Supplemental Indenture, dated as of May 1, 2008 to Mortgage and Deed of Trust, dated as of October 1, 1924 between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4-253 to Detroit Edison's Form 10-Q for the quarter ended June 30, 2008). (2008 Series ET)	X	X

Supplemental Indenture, dated as of June 1, 2008 to Mortgage and Deed of Trust, dated as of October 1, 1924 between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4-255 to Detroit Edison's Form 10-Q for the quarter ended June 30, 2008). (2008 Series G)	X	X

Supplemental Indenture, dated as of July 1, 2008 to Mortgage and Deed of Trust, dated as of October 1, 1924 between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4-257 to Detroit Edison's Form 10-Q for the quarter ended June 30, 2008). (2008 Series KT)	X	X

Supplemental Indenture, dated as of August 1, 2010, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4-269 to Detroit Edison's Form 10-Q for the quarter ended September 30, 2010). (2010 Series B)	X	X

Supplemental Indenture, dated as of September 1, 2010, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4-271 to Detroit Edison's Form 10-Q for the quarter ended September 30, 2010). (2010 Series A)	X	X

Supplemental Indenture, dated as of May 15, 2011, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A. as successor trustee (Exhibit 4-275 to Detroit Edison's Form 10-Q for the quarter ended June 30, 2011). (2011 Series B)	X	X

Supplemental Indenture, dated as of August 1, 2011, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A. as successor trustee (Exhibit 4-276 to Detroit Edison's Form 10-Q for the quarter ended September 30, 2011). (2011 Series GT)	X	X



	Twenty-fourth Supplemental Indenture, dated as of May 1, 2008 to the Collateral Trust Indenture, dated as of June 30, 1993 between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A. as successor trustee (Exhibit 4-254 to Detroit Edison's Form 10-Q for the quarter ended June 30, 2008). (2008 Series ET Variable Rate Senior Notes due 2029)	X	X

	Twenty-fifth Supplemental Indenture, dated as of June 1, 2008 to the Collateral Trust Indenture, dated as of June 30, 1993 between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4-256 to Detroit Edison's Form 10-Q for the quarter ended June 30, 2008). (2008 Series G 5.60% Senior Notes due 2018)	X	X

	Twenty-sixth Supplemental Indenture, dated as of July 1, 2008 to the Collateral Trust Indenture, dated as of June 30, 1993 between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4-258 to Detroit Edison's Form 10-Q for the quarter ended June 30, 2008). (2008 Series KT Variable Rate Senior Notes due 2020)	X	X

	Thirty-first Supplemental Indenture, dated as of August 1, 2010 to the Collateral Trust Indenture, dated as of June 1, 1993 between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4-270 to Detroit Edison's Form 10-Q for the quarter ended September 30, 2010). (2010 Series B 3.45% Senior Notes due 2020)	X	X

	Thirty-second Supplemental Indenture, dated as of September 1, 2010, between The Detroit Edison Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (Exhibit 4-272 to Detroit Edison's Form 10-Q for the quarter ended September 30, 2010). (2010 Series A 4.89% Senior Notes due 2020)	X	X

4(d)	Indenture dated as of June 1, 1998 between Michigan Consolidated Gas Company and Citibank, N.A., as trustee, related to Senior Debt Securities (Exhibit 4-1 to Michigan Consolidated Gas Company Registration Statement on Form S-3 (File No. 333-63370)) and indentures supplemental thereto, dated as of dates indicated below, and filed as exhibits to the filings set forth below:	X

Estimated Useful Lives in Years

Generation

Distribution

DTE Electric