10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

___________________________________

FORM 10-Q

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the Quarterly Period ended September 30, 2013

Commission file number 1-11607

DTE ENERGY COMPANY

(Exact name of registrant as specified in its charter)

Michigan	38-3217752
(State or other jurisdiction of	(I.R.S. Employer
incorporation or organization)	Identification No.)
One Energy Plaza, Detroit, Michigan	48226-1279
(Address of principal executive offices)	(Zip Code)

313-235-4000

(Registrant’s telephone number, including area code)

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.

YesxNoo

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).

YesxNoo

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

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

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

YesoNox

At September 30, 2013, 176,797,248 shares of DTE Energy’s common stock were outstanding, substantially all of which were held by non-affiliates.

DTE Energy Company

Quarterly Report on Form 10-Q

Quarter Ended September 30, 2013

TABLE OF CONTENTS

	Page
Definitions	1
Forward-Looking Statements	3
PART I - FINANCIAL INFORMATION
Item 1. Financial Statements	4
Consolidated Statements of Operations (Unaudited)	4
Consolidated Statements of Comprehensive Income (Unaudited)	5
Consolidated Statements of Financial Position (Unaudited)	6
Consolidated Statements of Cash Flows (Unaudited)	8
Consolidated Statement of Changes in Equity (Unaudited)	9
Notes to Consolidated Financial Statements (Unaudited)	10
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	39
Item 3. Quantitative and Qualitative Disclosures About Market Risk	51
Item 4. Controls and Procedures	54
PART II — OTHER INFORMATION
Item 1. Legal Proceedings	55
Item 1A. Risk Factors	55
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	56
Item 6. Exhibits	56
SIGNATURE	58
EX-10-87
EX-12-55
EX-31-85
EX-31-86
EX-32-85
EX-32-86
EX-101.INS XBRL INSTANCE DOCUMENT
EX-101.SCH XBRL TAXONOMY EXTENSION SCHEMA
EX-101.CAL XBRL TAXONOMY EXTENSION CALCULATION LINKBASE
EX-101.DEF XBRL TAXONOMY EXTENSION DEFINITION DATABASE
EX-101.LAB XBRL TAXONOMY EXTENSION LABEL LINKBASE
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DEFINITIONS

ASC	Accounting Standards Codification
ASU	Accounting Standards Update
Citizens	Citizens Fuel Gas Company, which distributes natural gas in Adrian, Michigan
Company	DTE Energy Company and any subsidiary companies
Customer Choice	Michigan legislation giving customers the option to choose alternative suppliers for electricity and natural gas.
DTE Electric	DTE Electric Company (a direct wholly owned subsidiary of DTE Energy Company) and subsidiary companies. Formerly known as The Detroit Edison Company.
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. Formerly known as Michigan Consolidated Gas Company.
EPA	United States Environmental Protection Agency
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
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.
MCIT	Michigan Corporate Income Tax
MDEQ	Michigan Department of Environmental Quality
MISO	Midwest Independent System Operator is an Independent System Operator and the Regional Transmission Organization serving the Midwest United States and Manitoba, Canada.
MPSC	Michigan Public Service Commission
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.
NRC	United States Nuclear Regulatory Commission
Production tax credits	Tax credits as authorized under Sections 45K and 45 of the Internal Revenue Code that are designed to stimulate investment in and development of alternate fuel sources. The amount of a production tax credit can vary each year as determined by the Internal Revenue Service.
PSCR	A Power Supply Cost Recovery mechanism authorized by the MPSC that allows DTE Electric to recover through rates its fuel, fuel-related and purchased power costs.
RDM	A Revenue Decoupling Mechanism authorized by the MPSC that is designed to minimize the impact on revenues of changes in average customer usage.
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.
Subsidiaries	The direct and indirect subsidiaries of DTE Energy Company
VIE	Variable Interest Entity

1

Units of Measurement
Bcf	Billion cubic feet of natural gas
Bcfe	Conversion metric using a standard ratio of one barrel of oil and/or natural gas liquids to 6 Mcf of natural gas equivalents.
BTU	Heat value (energy content) of fuel
dth/d	Decatherms per day
kWh	Kilowatthour of electricity
Mcf	Thousand cubic feet of natural gas
MMcf	Million cubic feet of natural gas
MW	Megawatt of electricity
MWh	Megawatthour of electricity

2

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 business of DTE Energy. Words such as “anticipate,” “believe,” “expect,” “projected” 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 including, but not limited to, the following:

• impact of regulation by the FERC, MPSC, NRC and 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;

• impact of electric and natural gas utility restructuring in Michigan, including legislative amendments and Customer Choice programs;

• economic conditions and population changes in our geographic area resulting in changes in demand, customer conservation, thefts of electricity and natural gas and high levels of uncollectible accounts receivable;

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

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

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

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

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

• 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 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 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;

• binding arbitration, litigation and related appeals; and

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

New factors emerge from time to time. We cannot predict what factors may arise or how such factors may cause our 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. We 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.

3

Part I — Financial Information

Item 1. Financial Statements

DTE Energy Company

Consolidated Statements of Operations (Unaudited)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
	(In millions, except per share amounts)
Operating Revenues	$	2,387		$	2,190		$	7,128		$	6,442
Operating Expenses
Fuel, purchased power and gas	967			761			2,931			2,347
Operation and maintenance	728			687			2,168			2,111
Depreciation, depletion and amortization	284			259			811			730
Taxes other than income	84			78			262			252
Asset (gains) and losses, reserves and impairments, net	(5		)	(1		)	(6		)	(10		)
	2,058			1,784			6,166			5,430
Operating Income	329			406			962			1,012
Other (Income) and Deductions
Interest expense	106			109			327			331
Interest income	(2		)	(2		)	(7		)	(7		)
Other income	(58		)	(47		)	(148		)	(125		)
Other expenses	7			9			23			27
	53			69			195			226
Income Before Income Taxes	276			337			767			786
Income Tax Expense	76			108			225			251
Income from Continuing Operations	200			229			542			535
Net Income from Discontinued Operations, net of tax	—			1			—			—
Net Income	200			230			542			535
Less: Net Income Attributable to Noncontrolling Interest	2			3			5			6
Net Income Attributable to DTE Energy Company	$	198		$	227		$	537		$	529
Basic Earnings per Common Share
Income from continuing operations	$	1.13		$	1.31		$	3.07		$	3.09
Income from discontinued operations, net of tax	—			0.01			—			—
Total	$	1.13		$	1.32		$	3.07		$	3.09
Diluted Earnings per Common Share
Income from continuing operations	$	1.13		$	1.30		$	3.07		$	3.08
Income from discontinued operations, net of tax	—			0.01			—			—
Total	$	1.13		$	1.31		$	3.07		$	3.08
Weighted Average Common Shares Outstanding
Basic	175			172			174			171
Diluted	176			172			175			171
Dividends Declared per Common Share	$	0.66		$	0.62		$	1.93		$	1.80

See Notes to Consolidated Financial Statements (Unaudited)

4

DTE Energy Company

Consolidated Statements of Comprehensive Income (Unaudited)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2013		2012		2013			2012
	(In millions)
Net income	$	200	$	230	$	542		$	535
Other comprehensive income (loss), net of tax:
Benefit obligations, net of taxes of $2, $1, $4 and $4	2		3		7			9
Net unrealized gains on investments during the period, net of taxes of $1, $—, $1 and $—	1		—		1			1
Foreign currency translation, net of taxes of $—, $1, $(1) and $1	1		1		(1		)	1
Other comprehensive income	4		4		7			11
Comprehensive income	204		234		549			546
Less comprehensive income attributable to noncontrolling interests	2		3		5			6
Comprehensive income attributable to DTE Energy Company	$	202	$	231	$	544		$	540

See Notes to Consolidated Financial Statements (Unaudited)

5

DTE Energy Company

Consolidated Statements of Financial Position (Unaudited)

	September 30,			December 31,
	2013			2012
	(In millions)
ASSETS
Current Assets
Cash and cash equivalents	$	71		$	65
Restricted cash, principally Securitization	64			122
Accounts receivable (less allowance for doubtful accounts of $67 and $62, respectively)
Customer	1,239			1,336
Other	81			126
Inventories
Fuel and gas	467			527
Materials and supplies	258			234
Deferred income taxes	—			21
Derivative assets	72			108
Regulatory assets	49			182
Other	248			194
	2,549			2,915
Investments
Nuclear decommissioning trust funds	1,139			1,037
Other	584			554
	1,723			1,591
Property
Property, plant and equipment	24,795			23,631
Less accumulated depreciation, depletion and amortization	(9,284		)	(8,947		)
	15,511			14,684
Other Assets
Goodwill	2,018			2,018
Regulatory assets	3,700			4,235
Securitized regulatory assets	280			413
Intangible assets	122			135
Notes receivable	104			112
Derivative assets	26			39
Other	198			197
	6,448			7,149
Total Assets	$	26,231		$	26,339

See Notes to Consolidated Financial Statements (Unaudited)

6

DTE Energy Company

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

	September 30,			December 31,
	2013			2012
	(In millions, except shares)
LIABILITIES AND EQUITY
Current Liabilities
Accounts payable	$	866		$	848
Accrued interest	114			93
Dividends payable	116			107
Short-term borrowings	271			240
Current portion long-term debt, including capital leases	896			817
Derivative liabilities	58			125
Regulatory liabilities	230			89
Other	457			449
	3,008			2,768
Long-Term Debt (net of current portion)
Mortgage bonds, notes and other	6,253			6,220
Securitization bonds	105			302
Junior subordinated debentures	480			480
Capital lease obligations	8			12
	6,846			7,014
Other Liabilities
Deferred income taxes	3,290			3,191
Regulatory liabilities	907			1,031
Asset retirement obligations	1,800			1,719
Unamortized investment tax credit	49			56
Derivative liabilities	21			26
Accrued pension liability	1,254			1,498
Accrued postretirement liability	684			1,160
Nuclear decommissioning	172			159
Other	290			306
	8,467			9,146
Commitments and Contingencies (Notes 7 and 12)
Equity
Common stock, without par value, 400,000,000 shares authorized, 176,797,248 and 172,351,680 shares issued and outstanding, respectively	3,885			3,587
Retained earnings	4,142			3,944
Accumulated other comprehensive loss	(151		)	(158		)
Total DTE Energy Company Equity	7,876			7,373
Noncontrolling interests	34			38
Total Equity	7,910			7,411
Total Liabilities and Equity	$	26,231		$	26,339

See Notes to Consolidated Financial Statements (Unaudited)

7

DTE Energy Company

Consolidated Statements of Cash Flows (Unaudited)

	Nine Months Ended September 30,
	2013			2012
	(In millions)
Operating Activities
Net income	$	542		$	535
Adjustments to reconcile net income to net cash from operating activities:
Depreciation, depletion and amortization	811			747
Nuclear fuel amortization	25			25
Allowance for equity funds used during construction	(10		)	(10		)
Deferred income taxes	162			96
Asset (gains) and losses, reserves and impairments, net	(5		)	(7		)
Changes in assets and liabilities:
Accounts receivable, net	177			237
Inventories	35			5
Accounts payable	(16		)	(35		)
Derivative assets and liabilities	(23		)	38
Accrued pension obligation	(44		)	(3		)
Accrued postretirement obligation	(191		)	(143		)
Regulatory assets and liabilities	327			286
Other assets	(62		)	(2		)
Other liabilities	(13		)	(40		)
Net cash from operating activities	1,715			1,729
Investing Activities
Plant and equipment expenditures — utility	(1,101		)	(1,008		)
Plant and equipment expenditures — non-utility	(270		)	(214		)
Proceeds from sale of assets	20			20
Restricted cash for debt redemption, principally Securitization	58			55
Proceeds from sale of nuclear decommissioning trust fund assets	40			48
Investment in nuclear decommissioning trust funds	(52		)	(61		)
Other	(32		)	(24		)
Net cash used for investing activities	(1,337		)	(1,184		)
Financing Activities
Issuance of long-term debt	768			495
Redemption of long-term debt	(855		)	(447		)
Short-term borrowings, net	31			(321		)
Issuance of common stock	29			29
Dividends on common stock	(329		)	(300		)
Other	(16		)	(10		)
Net cash used for financing activities	(372		)	(554		)
Net Increase (Decrease) in Cash and Cash Equivalents	6			(9		)
Cash and Cash Equivalents at Beginning of Period	65			68
Cash and Cash Equivalents at End of Period	$	71		$	59
Supplemental Disclosure of Non-Cash Investing and Financing Activities
Common stock issued for employee benefit and compensation plans	$	279		$	143
Plant and equipment expenditures in accounts payable	$	263		$	184

See Notes to Consolidated Financial Statements (Unaudited)

8

DTE Energy Company

Consolidated Statements of Changes in Equity (Unaudited)

							Accumulated Other Comprehensive Loss			Non-Controlling Interest
	Common Stock			Retained Earnings
	Shares	Amount											Total
	(Dollars in millions, shares in thousands)
Balance, December 31, 2012	172,352	$	3,587	$	3,944		$	(158	)	$	38		$	7,411
Net income	—	—		537			—			5			542
Dividends declared on common stock	—	—		(339		)	—			—			(339		)
Issuance of common stock	439	29		—			—			—			29
Contribution of common stock to pension plan	3,026	200		—			—			—			200
Foreign currency translation, net of tax	—	—		—			(1		)	—			(1		)
Benefit obligations, net of tax	—	—		—			7			—			7
Net change in unrealized losses on investments, net of tax	—	—		—			1			—			1
Stock-based compensation, distributions to noncontrolling interests and other	980	69		—			—			(9		)	60
Balance, September 30, 2013	176,797	$	3,885	$	4,142		$	(151	)	$	34		$	7,910

See Notes to Consolidated Financial Statements (Unaudited)

9

DTE Energy Company

Notes to Consolidated Financial Statements (Unaudited)

NOTE 1 — ORGANIZATION AND BASIS OF PRESENTATION

Corporate Structure

DTE Energy owns the following businesses:

• DTE Electric, an electric utility engaged in the generation, purchase, distribution and sale of electricity to approximately 2.1 million customers in southeastern Michigan;

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

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

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

References in this Report to “Company” or “DTE” are to DTE Energy and its subsidiaries, collectively.

Basis of Presentation

These Consolidated Financial Statements should be read in conjunction with the Notes to Consolidated Financial Statements included in the 2012 Annual Report on Form 10-K.

The accompanying Consolidated Financial Statements 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 Company’s estimates.

The Consolidated Financial Statements are unaudited, but in the Company's opinion include all adjustments necessary to present a fair statement of the results for the interim periods. All adjustments are of a normal recurring nature, except as otherwise disclosed in these Consolidated Financial Statements and Notes to Consolidated Financial Statements. Financial results for this interim period are not necessarily indicative of results that may be expected for any other interim period or for the fiscal year ending December 31, 2013.

Certain prior year balances were reclassified to match the current year's financial statement presentation.

Principles of Consolidation

The Company consolidates all majority-owned subsidiaries and investments in entities in which it has controlling influence. Non-majority owned investments are accounted for using the equity method when the Company is able to influence the operating policies of the investee. When the Company does not influence the operating policies of an investee, the cost method is used. These consolidated financial statements also reflect the Company's proportionate interests in certain jointly owned utility plants. The Company eliminates all intercompany balances and transactions.

The Company evaluates whether an entity is a VIE whenever reconsideration events occur. The Company consolidates VIEs for which it is the primary beneficiary. If the Company 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, the Company 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 Company performs ongoing reassessments of all VIEs to determine if the primary beneficiary status has changed.

10

DTE Energy Company

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

Legal entities within the Company'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 the Company retaining operational and customer default risk. These entities generally are VIEs and consolidated when the Company is the primary beneficiary. In addition, we have interests in certain VIEs that we share control of all significant activities for those entities with our partners, and therefore are accounted for under the equity method.

The Company has variable interests in VIEs through certain of its long-term purchase contracts. As of September 30, 2013, the carrying amount of assets and liabilities in the Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase contracts are predominately related to working capital accounts and generally represent the amounts owed by the Company for the deliveries associated with the current billing cycle under the contracts. The Company has not provided any form of financial support associated with these long-term contracts. There is no significant potential exposure to loss as a result of its variable interests through these long-term purchase contracts.

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 performs servicing activities including billing and collecting surcharge revenue for Securitization. This entity is a VIE and is consolidated by the Company.

The maximum risk exposure for consolidated VIEs is reflected on the Company's Consolidated Statements of Financial Position. For non-consolidated VIEs, the maximum risk exposure is generally limited to its investment and amounts which it has guaranteed.

The following table summarizes the major balance sheet items for consolidated VIEs as of September 30, 2013 and December 31, 2012. All assets and liabilities of a consolidated VIE are presented where it has been determined that aconsolidated VIE has either (1) assets that can be used only to settle obligations of the VIE or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary. VIEs, in which the Company 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.

	September 30, 2013						December 31, 2012
	Securitization		Other		Total		Securitization		Other		Total
	(In millions)
ASSETS
Cash and cash equivalents	$	—	$	10	$	10	$	—	$	10	$	10
Restricted cash	44		7		51		102		7		109
Accounts receivable	39		17		56		34		7		41
Inventories	—		112		112		—		141		141
Other current assets	—		1		1		—		1		1
Property, plant and equipment	—		100		100		—		93		93
Securitized regulatory assets	280		—		280		413		—		413
Other assets	5		9		14		7		11		18
	$	368	$	256	$	624	$	556	$	270	$	826
LIABILITIES
Accounts payable and accrued current liabilities	$	2	$	35	$	37	$	11	$	14	$	25
Current portion long-term debt, including capital leases	196		9		205		177		8		185
Current regulatory liabilities	48		—		48		50		—		50
Other current liabilities	—		3		3		—		4		4
Mortgage bonds, notes and other	—		22		22		—		25		25
Securitization bonds	105		—		105		302		—		302
Capital lease obligations	—		7		7		—		11		11
Other long-term liabilities	8		3		11		7		2		9
	$	359	$	79	$	438	$	547	$	64	$	611

11

DTE Energy Company

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

Amounts for non-consolidated VIEs as of September 30, 2013 and December 31, 2012 are as follows:

	September 30, 2013		December 31, 2012
	(In millions)
Other investments	$	138	$	130
Notes receivable	$	3	$	6

NOTE 2 — SIGNIFICANT ACCOUNTING POLICIES

Comprehensive Income

Comprehensive income is the change in common shareholders’ equity during a period from transactions and events from non-owner sources, including net income. As shown in the following tables, amounts recorded to accumulated other comprehensive loss for the three and nine months ended September 30, 2013 include unrealized gains and losses from derivatives accounted for as cash flow hedges, unrealized gains and losses on available-for-sale securities and the Company’s interest in other comprehensive income of equity investees, which comprise the net unrealized gains and losses on investments, changes in benefit obligations, consisting of deferred actuarial losses, prior service costs and transition amounts related to pension and other postretirement benefit plans, and foreign currency translation adjustments.

	Changes in Accumulated Other Comprehensive Loss by Component (a)
	For The Three Months Ended September 30, 2013
	Net Unrealized Gain/(Loss) on Derivatives			Net Unrealized Gain/(Loss) on Investments			Benefit Obligations (b)			Foreign Currency Translation		Total
	(In millions)
Beginning balance, June 30, 2013	$	(4	)	$	(8	)	$	(143	)	$	—	$	(155	)
Other comprehensive income before reclassifications	—			1			—			1		2
Amounts reclassified from accumulated other comprehensive income	—			—			2			—		2
Net current-period other comprehensive income	—			1			2			1		4
Ending balance, September 30, 2013	$	(4	)	$	(7	)	$	(141	)	$	1	$	(151	)

	Changes in Accumulated Other Comprehensive Loss by Component (a)
	For The Nine Months Ended September 30, 2013
	Net Unrealized Gain/(Loss) on Derivatives			Net Unrealized Gain/(Loss) on Investments			Benefit Obligations (b)			Foreign Currency Translation			Total
	(In millions)
Beginning balance, December 31, 2012	$	(4	)	$	(8	)	$	(148	)	$	2		$	(158	)
Other comprehensive income before reclassifications	—			1			—			(1		)	—
Amounts reclassified from accumulated other comprehensive income	—			—			7			—			7
Net current-period other comprehensive income (loss)	—			1			7			(1		)	7
Ending balance, September 30, 2013	$	(4	)	$	(7	)	$	(141	)	$	1		$	(151	)

______________________________________

(a) All amounts are net of tax.

(b) The amounts reclassified from accumulated other comprehensive income are included in the computation of the net periodic pension cost (see Retirement Benefits and Trusteed Assets Note 13).

12

DTE Energy Company

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

Intangible Assets

The Company has certain intangible assets relating to emission allowances, renewable energy credits and non-utility contracts as shown below:

	September 30,		December 31,
	2013		2012
	(In millions)
Emission allowances	$	3	$	6
Renewable energy credits	48		44
Contract intangible assets	126		139
	177		189
Less accumulated amortization	41		34
Intangible assets, net	136		155
Less current intangible assets	14		20
	$	122	$	135

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 Company amortizes contract intangible assets on a straight-line basis over the expected period of benefit, ranging from 3 to 30 years.

Income Taxes

The Company's effective tax rate from continuing operations for the three months ended September 30, 2013 was 28 percent as compared to 32 percent for the three months ended September 30, 2012. The Company's effective tax rate from continuing operations for the nine months ended September 30, 2013 was 29 percent as compared to 32 percent for the nine months ended September 30, 2012. The decrease in the effective tax rate in 2013 is due primarily to higher production tax credits.

The Company had $3 million of unrecognized tax benefits at September 30, 2013, that, if recognized, would favorably impact its effective tax rate. The Company believes that it is possible that there will be a decrease in the unrecognized tax benefits of up to $1 million in the next twelve months.

13

DTE Energy Company

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

NOTE 3 — 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 Company makes certain assumptions it believes 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 Company and its counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at September 30, 2013 and December 31, 2012. The Company believes it uses valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.

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

14

DTE Energy Company

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

The following table presents assets and liabilities measured and recorded at fair value on a recurring basis as of September 30, 2013 and December 31, 2012:

	September 30, 2013															December 31, 2012
	Level 1			Level 2			Level 3			Netting (a)			Net Balance			Level 1			Level 2			Level 3			Netting (a)			Net Balance
	(In millions)
Assets:
Cash equivalents (b)	$	—		$	68		$	—		$	—		$	68		$	—		$	123		$	—		$	—		$	123
Nuclear decommissioning trusts	757			382			—			—			1,139			694			343			—			—			1,037
Other investments (c) (d)	76			48			—			—			124			66			44			—			—			110
Derivative assets:
Commodity Contracts:
Natural Gas	388			61			34			(474		)	9			555			66			24			(605		)	40
Electricity	—			210			88			(216		)	82			—			226			134			(258		)	102
Other	48			9			5			(55		)	7			6			3			2			(6		)	5
Total derivative assets	436			280			127			(745		)	98			561			295			160			(869		)	147
Total	$	1,269		$	778		$	127		$	(745	)	$	1,429		$	1,321		$	805		$	160		$	(869	)	$	1,417
Liabilities:
Derivative liabilities:
Interest rate contracts	$	—		$	—		$	—		$	—		$	—		$	—		$	(1	)	$	—		$	—		$	(1	)
Commodity Contracts:
Natural Gas	(374		)	(49		)	(48		)	445			(26		)	(526		)	(73		)	(62		)	605			(56		)
Electricity	—			(204		)	(83		)	236			(51		)	—			(240		)	(111		)	258			(93		)
Other	(52		)	(5		)	—			55			(2		)	(6		)	(1		)	—			6			(1		)
Total derivative liabilities	(426		)	(258		)	(131		)	736			(79		)	(532		)	(315		)	(173		)	869			(151		)
Total	$	(426	)	$	(258	)	$	(131	)	$	736		$	(79	)	$	(532	)	$	(315	)	$	(173	)	$	869		$	(151	)
Net Assets (Liabilities) at the end of the period	$	843		$	520		$	(4	)	$	(9	)	$	1,350		$	789		$	490		$	(13	)	$	—		$	1,266
Assets:
Current	$	400		$	285		$	94		$	(639	)	$	140		$	493		$	372		$	120		$	(754	)	$	231
Noncurrent (e)	869			493			33			(106		)	1,289			828			433			40			(115		)	1,186
Total Assets	$	1,269		$	778		$	127		$	(745	)	$	1,429		$	1,321		$	805		$	160		$	(869	)	$	1,417
Liabilities:
Current	$	(379	)	$	(189	)	$	(100	)	$	610		$	(58	)	$	(466	)	$	(269	)	$	(144	)	$	754		$	(125	)
Noncurrent	(47		)	(69		)	(31		)	126			(21		)	(66		)	(46		)	(29		)	115			(26		)
Total Liabilities	$	(426	)	$	(258	)	$	(131	)	$	736		$	(79	)	$	(532	)	$	(315	)	$	(173	)	$	869		$	(151	)
Net Assets (Liabilities) at the end of the period	$	843		$	520		$	(4	)	$	(9	)	$	1,350		$	789		$	490		$	(13	)	$	—		$	1,266

_______________________________________

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

(b) At September 30, 2013, available-for-sale securities of $68 million included $51 million and $17 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position. At December 31, 2012, available-for-sale securities of $123 million, included $109 million and $14 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position.

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

(d) Available-for-sale equity securities of $6 million at September 30, 2013 and $5 million at December 31, 2012, are included in Other investments on the Consolidated Statements of Financial Position.

(e) Includes $124 million and $110 million at September 30, 2013 and December 31, 2012, respectively, of Other investments that are included in the Consolidated Statements of Financial Position in Other investments.

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. The fair values of the shares in these investments are based upon observable market prices for similar securities and, therefore, have been categorized as Level 2 in the fair value hierarchy.

15

DTE Energy Company

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

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. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. The institutional mutual funds which hold exchange-traded equity or debt securities are valued based on the underlying securities, using quoted prices in actively traded markets. Non-exchange-traded fixed income securities are valued 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 determines that another price source is considered to be preferable. 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, DTE Energy selectively corroborates the fair value of securities by comparison of market-based price sources. Investment policies and procedures are determined by the Company's Trust Investments Department which reports to the Company's Vice President and Treasurer.

Derivative Assets and Liabilities

Derivative assets and liabilities are comprised of physical and financial derivative contracts, including futures, forwards, options and swaps that are both exchange-traded and over-the-counter traded contracts. Various inputs are used to value derivatives depending on the type of contract and availability of market data. Exchange-traded derivative contracts are valued using quoted prices in active markets. DTE Energy considers 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. DTE Energy monitors 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. DTE Energy has obtained an understanding of how these prices are derived. Additionally, DTE Energy selectively corroborates the fair value of its 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 Company has 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 our forward price curves has been assigned to our Risk Management Department, which is separate and distinct from the trading functions within the Company.

The following tables present the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for the three months and nine months ended September 30, 2013 and 2012:

	Three Months Ended September 30, 2013											Three Months Ended September 30, 2012
	Natural Gas			Electricity			Other		Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of June 30	$	(30	)	$	12		$	2	$	(16	)	$	2		$	50		$	5		$	57
Transfers into Level 3	—			—			—		—			—			—			—			—
Transfers out of Level 3	—			(1		)	—		(1		)	—			—			—			—
Total gains (losses):
Included in earnings	8			17			—		25			(43		)	12			1			(30		)
Recorded in regulatory assets/liabilities	—			—			3		3			—			—			7			7
Purchases, issuances and settlements:
Settlements	8			(23		)	—		(15		)	(3		)	(38		)	(7		)	(48		)
Net Assets (Liabilities) as of September 30	$	(14	)	$	5		$	5	$	(4	)	$	(44	)	$	24		$	6		$	(14	)
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 September 30, 2013 and 2012 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations	$	(8	)	$	8		$	—	$	—		$	(43	)	$	5		$	1		$	(37	)

16

DTE Energy Company

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

	Nine Months Ended September 30, 2013												Nine Months Ended September 30, 2012
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of December 31	$	(38	)	$	23		$	2		$	(13	)	$	6		$	32		$	6		$	44
Transfers into Level 3	—			—			—			—			1			28			—			29
Transfers out of Level 3	(2		)	—			—			(2		)	(2		)	—			—			(2		)
Total gains (losses):
Included in earnings	(1		)	44			—			43			(38		)	53			—			15
Recorded in regulatory assets/liabilities	—			—			7			7			—			—			12			12
Purchases, issuances and settlements:
Purchases	—			(1		)	—			(1		)	—			1			—			1
Settlements	27			(61		)	(4		)	(38		)	(11		)	(90		)	(12		)	(113		)
Net Assets (Liabilities) as of September 30	$	(14	)	$	5		$	5		$	(4	)	$	(44	)	$	24		$	6		$	(14	)
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 September 30, 2013 and 2012 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations	$	(14	)	$	36		$	—		$	22		$	(39	)	$	43		$	—		$	4

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. The following table shows transfers between the levels of the fair value hierarchy for the three months and nine months ended September 30, 2013 and 2012:

	Three Months Ended September 30, 2013					Three Months Ended September 30, 2012
	Level 1	Level 2		Level 3		Level 1	Level 2		Level 3
	(In millions)
Transfers into Level 1 from	$ N/A	$	—	$	—	$ N/A	$	—	$	—
Transfers into Level 2 from	—	N/A		1		—	N/A		—
Transfers into Level 3 from	—	—		N/A		—	—		N/A

	Nine Months Ended September 30, 2013					Nine Months Ended September 30, 2012
	Level 1	Level 2		Level 3		Level 1	Level 2		Level 3
	(In millions)
Transfers into Level 1 from	$ N/A	$	—	$	—	$ N/A	$	—	$	—
Transfers into Level 2 from	—	N/A		2		—	N/A		2
Transfers into Level 3 from	—	—		N/A		—	29		N/A

The following table presents the unobservable inputs related to Level 3 assets and liabilities as of September 30, 2013:

	September 30, 2013
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	34	$	(48	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.10	)	—	$	4.22	/MMBtu	$	0.10	/MMBtu
Electricity	$	88	$	(83	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(8	)	—	$	15	/MWh	$	2	/MWh

17

DTE Energy Company

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

The following table presents the unobservable inputs related to Level 3 assets and liabilities as of December 31, 2012:

	December 31, 2012
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	24	$	(62	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(0.63	)	—	$	1.95	/MMBtu	$	0.03	/MMBtu
Electricity	$	134	$	(111	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(2	)	—	$	16	/MWh	$	3	/MWh

The unobservable inputs used in the fair value measurement of the electricity and natural gas commodity types consist of inputs that are less observable due in part to lack of available broker quotes, supported by little, if any, market activity at the measurement date or are based on internally developed models. Certain basis prices (i.e. the difference in pricing between two locations) included in the valuation of natural gas and electricity contracts were deemed unobservable.

The inputs listed above would have a direct impact on the fair values of the above security types if they were adjusted. A significant increase (decrease) in the basis price would result in a higher (lower) fair value for long positions, with offsetting impacts to short positions.

Fair Value of Financial Instruments

The fair value of financial instruments included in the table below is determined by using quoted market prices when available. When quoted prices are not available, pricing services may be used to determine the fair value with reference to observable interest rate indexes. DTE Energy has obtained an understanding of how the fair values are derived. DTE Energy also selectively corroborates the fair value of its transactions by comparison of market-based price sources. Discounted cash flow analyses based upon estimated current borrowing rates are also used to determine fair value when quoted market prices are not available. The fair values of notes receivable, excluding capital leases, are 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 are determined by DTE Energy's Treasury Department which reports to the Company's Vice President and Treasurer.

The following table presents the carrying amount and fair value of financial instruments as of September 30, 2013 and December 31, 2012:

	September 30, 2013								December 31, 2012
	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	$	37	$	—	$	—	$	37	$	39	$	—	$	—	$	39
Dividends payable	$	116	$	116	$	—	$	—	$	107	$	107	$	—	$	—
Short-term borrowings	$	271	$	—	$	271	$	—	$	240	$	—	$	240	$	—
Long-term debt	$	7,729	$	436	$	7,067	$	738	$	7,813	$	507	$	7,453	$	933

See Note 4 for further fair value information on financial and derivative instruments.

Nuclear Decommissioning Trust Funds

DTE Electric has a legal obligation to decommission its nuclear power plants following the expiration of their operating licenses. This obligation is reflected as an asset retirement obligation on the 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.

18

DTE Energy Company

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

The following table summarizes the fair value of the nuclear decommissioning trust fund assets:

	September 30, 2013		December 31, 2012
	(In millions)
Fermi 2	$	1,120	$	1,021
Fermi 1	3		3
Low level radioactive waste	16		13
Total	$	1,139	$	1,037

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

	Three Months Ended September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
	(In millions)
Realized gains	$	11		$	7		$	30		$	21
Realized losses	$	(11	)	$	(6	)	$	(25	)	$	(17	)
Proceeds from sales of securities	$	13		$	12		$	40		$	48

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. The following table sets forth the fair value and unrealized gains for the nuclear decommissioning trust funds:

	September 30, 2013				December 31, 2012
	Fair Value		Unrealized Gains		Fair Value		Unrealized Gains
	(In millions)
Equity securities	$	732	$	195	$	631	$	122
Debt securities	395		17		399		27
Cash and cash equivalents	12		—		7		—
	$	1,139	$	212	$	1,037	$	149

The debt securities at September 30, 2013 and December 31, 2012 had an average maturity of approximately 7 and 6 years, respectively. Securities held in the nuclear decommissioning trust funds are classified as available-for-sale. As DTE Electric does not have the ability to hold impaired investments for a period of time sufficient to allow for the anticipated recovery of market value, all unrealized losses are considered to be other-than-temporary impairments.

Unrealized losses incurred by the Fermi 2 trust are recognized as a Regulatory asset. DTE Electric recognized $38 million and $44 million of unrealized losses as Regulatory assets at September 30, 2013 and December 31, 2012, respectively. Since the decommissioning of Fermi 1 is funded by DTE Electric rather than through a regulatory recovery mechanism, there is no corresponding regulatory asset treatment. Therefore, unrealized losses incurred by the Fermi 1 trust are recognized in earnings immediately. There were no unrealized losses recognized in the three and nine months ended September 30, 2013 and September 30, 2012 for Fermi 1.

Other Securities

At September 30, 2013 and December 31, 2012, the securities were comprised primarily of money market and equity securities. During the three and nine months ended September 30, 2013 and September 30, 2012, no amounts of unrealized losses on available-for-sale securities were reclassified out of other comprehensive income and realized into net income for the periods. Gains related to trading securities held at September 30, 2013 and September 30, 2012 were $14 million and $11 million, respectively.

19

DTE Energy Company

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

NOTE 4 — FINANCIAL AND OTHER DERIVATIVE INSTRUMENTS

The Company recognizes all derivatives at their fair value as Derivative Assets or Liabilities on the 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 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 Company’s primary market risk exposure is associated with commodity prices, credit, and interest rates. The Company has risk management policies to monitor and manage market risks. The Company uses derivative instruments to manage some of the exposure. The Company uses derivative instruments for trading purposes in its Energy Trading segment. Contracts classified as derivative instruments include power, natural gas, oil and certain coal forwards, futures, options and 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.

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 sales exemption and are therefore accounted for under the accrual method. Other derivative contracts are recoverable through the PSCR mechanism when settled. This results in the deferral of unrealized gains and losses as Regulatory assets or liabilities until realized.

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 2016. Substantially all of these contracts meet the normal purchases and sales exemption and are therefore accounted for under the accrual method. DTE Gas may also sell forward transportation and storage capacity contracts. Forward transportation and storage contracts are generally not derivatives and are therefore accounted for under the accrual method.

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

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

Energy Trading — Commodity Price Risk — Energy Trading markets and trades electricity, coal, 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. The Company 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.

20

DTE Energy Company

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

Corporate and Other — Interest Rate Risk — The Company uses interest rate swaps, treasury locks and other derivatives to hedge the risk associated with interest rate market volatility. In 2004 and 2000, the Company entered into a series of interest rate derivatives to limit its sensitivity to market interest rate risk associated with the issuance of long-term debt. Such instruments were designated as cash flow hedges. The Company subsequently issued long-term debt and terminated these hedges at a cost that is included in Other comprehensive loss. Amounts recorded in Other comprehensive loss will be reclassified to interest expense through 2033. In 2013, the Company estimates reclassifying less than $1 million of losses to earnings.

Credit Risk — The utility and non-utility businesses are exposed to credit risk if customers or counterparties do not comply with their contractual obligations. The Company maintains credit policies that significantly minimize overall credit risk. These policies include an evaluation of potential customers’ and counterparties’ financial condition, credit rating, collateral requirements or other credit enhancements such as letters of credit or guarantees. The Company generally uses standardized agreements that allow the netting of positive and negative transactions associated with a single counterparty. The Company maintains a provision for credit losses based on factors surrounding the credit risk of its customers, historical trends, and other information. Based on the Company’s credit policies and its September 30, 2013 provision for credit losses, the Company’s exposure to counterparty nonperformance is not expected to have a material adverse effect on the Company’s financial statements.

Derivative Activities

The Company manages its mark-to-market (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.

21

DTE Energy Company

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

The following tables present the fair value of derivative instruments as of September 30, 2013 and December 31, 2012:

	September 30, 2013					December 31, 2012
	Derivative Assets		Derivative Liabilities			Derivative Assets		Derivative Liabilities
	(In millions)
Derivatives designated as hedging instruments:
Interest rate contracts	$	—	$	—		$	—	$	(1	)
Derivatives not designated as hedging instruments:
Commodity Contracts:
Natural Gas	$	483	$	(471	)	$	645	$	(661	)
Electricity	298		(287		)	360		(351		)
Other	62		(57		)	11		(7		)
Total derivatives not designated as hedging instruments:	$	843	$	(815	)	$	1,016	$	(1,019	)
Total derivatives:
Current	$	711	$	(668	)	$	862	$	(879	)
Noncurrent	132		(147		)	154		(141		)
Total derivatives	$	843	$	(815	)	$	1,016	$	(1,020	)

Certain of the Company'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, the Company offsets the fair value of derivative instruments with cash collateral received or paid for those contracts executed with the same counterparty, which reduces the Company's total assets and liabilities. Cash collateral is allocated between the fair value of derivative instruments and customer accounts receivable and payable with the same counterparty on a pro rata basis to the extent there is exposure. Any cash collateral remaining, after the exposure is netted to zero, is reflected in accounts receivable and accounts payable as collateral paid or received, respectively.

The Company 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. The Company had issued letters of credit of approximately $21 million and $63 million at September 30, 2013 and December 31, 2012, respectively, which could be used to offset our net derivative liabilities. Letters of credit received from third parties which could be used to offset our net derivative assets were not material for the periods presented. Such balances of letters of credit are excluded from the tables below and are not netted with the recognized assets and liabilities in the 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 the 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.

As of September 30, 2013, the total cash collateral received, net of cash collateral posted, was $30 million. As of December 31, 2012, the total cash collateral received, net of cash collateral posted, was $20 million. As of September 30, 2013, derivative assets and derivative liabilities are shown net of cash collateral of $29 million and $20 million, respectively. There was no cash collateral related to unrealized positions to net against derivative assets and liabilities as of December 31, 2012. The Company recorded cash collateral paid of $3 million and cash collateral received of $24 million not related to unrealized derivative positions as of September 30, 2013. The Company recorded cash collateral paid of $4 million and cash collateral received of $24 million not related to unrealized derivative positions as of December 31, 2012. These amounts are included in accounts receivable and accounts payable and are recorded net by counterparty.

22

DTE Energy Company

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

The following table presents the netting offsets of derivative assets and liabilities at September 30, 2013 and December 31, 2012:

	September 30, 2013									December 31, 2012
	Gross Amounts of Recognized Assets (Liabilities)			Gross Amounts Offset in the Consolidated Statements of Financial Position			Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position			Gross Amounts of Recognized Assets (Liabilities)			Gross Amounts Offset in the Consolidated Statements of Financial Position			Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position
	(In millions)
Derivative assets:
Commodity Contracts:
Natural Gas	$	483		$	(474	)	$	9		$	645		$	(605	)	$	40
Electricity	298			(216		)	82			360			(258		)	102
Other	62			(55		)	7			11			(6		)	5
Total derivative assets	$	843		$	(745	)	$	98		$	1,016		$	(869	)	$	147
Derivative liabilities:
Interest rate contracts	$	—		$	—		$	—		$	(1	)	$	—		$	(1	)
Commodity Contracts:
Natural Gas	(471		)	445			(26		)	(661		)	605			(56		)
Electricity	(287		)	236			(51		)	(351		)	258			(93		)
Other	(57		)	55			(2		)	(7		)	6			(1		)
Total derivative liabilities	$	(815	)	$	736		$	(79	)	$	(1,020	)	$	869		$	(151	)

The following table presents the netting offsets of derivative assets and liabilities at September 30, 2013 and December 31, 2012:

	September 30, 2013												December 31, 2012
	Derivative Assets						Derivative Liabilities						Derivative Assets						Derivative Liabilities
	Current			Noncurrent			Current			Noncurrent			Current			Noncurrent			Current			Noncurrent
	(In millions)
Reconciliation of derivative instruments to Consolidated Statements of Financial Position:
Total fair value of derivatives	$	711		$	132		$	(668	)	$	(147	)	$	862		$	154		$	(879	)	$	(141	)
Counterparty netting	(610		)	(106		)	610			106			(754		)	(115		)	754			115
Collateral adjustment	(29		)	—			—			20			—			—			—			—
Total derivatives as reported	$	72		$	26		$	(58	)	$	(21	)	$	108		$	39		$	(125	)	$	(26	)

23

DTE Energy Company

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

The effect of derivatives not designated as hedging instruments on the Consolidated Statements of Operations for the three and nine months ended September 30, 2013 and 2012 is as follows:

	Location of Gain (Loss) Recognized in Income on Derivatives	Gain (Loss) Recognized in Income on Derivatives for the Three Months Ended September 30,						Gain (Loss) Recognized in Income on Derivatives for the Nine Months Ended September 30,
Derivatives not Designated as Hedging Instruments		2013			2012			2013			2012
		(In millions)
Foreign currency exchange contracts	Operating Revenue	$	—		$	(2	)	$	(1	)	$	(1	)
Commodity Contracts:
Natural Gas	Operating Revenue	1			(54		)	37			(51		)
Natural Gas	Fuel, purchased power and gas	(1		)	50			(33		)	45
Electricity	Operating Revenue	22			17			52			52
Other	Operating Revenue	1			1			1			12
Total		$	23		$	12		$	56		$	57

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

The effects of derivative instruments recoverable through the PSCR mechanism when realized on the Consolidated Statements of Financial Position were $3 million and $7 million in unrealized gains related to FTRs recognized in Regulatory liabilities for the three and nine months ended September 30, 2013, respectively.

The following represents the cumulative gross volume of derivative contracts outstanding as of September 30, 2013:

Commodity	Number of Units
Natural Gas (MMBtu)	683,113,433
Electricity (MWh)	59,672,654
Foreign Currency Exchange ($ CAD)	48,741,288
FTR (MWh)	13,005,024

Various subsidiaries of the Company have entered into contracts which contain ratings triggers and are guaranteed by DTE Energy. These contracts contain provisions which allow the counterparties to request that the Company 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 the Company can be asked 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 the Company 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 September 30, 2013, DTE Energy's contractual obligation to post collateral in the form of cash or letter of credit in the event of a downgrade to below investment grade, under both hard trigger and soft trigger provisions, was approximately $327 million.

24

DTE Energy Company

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

NOTE 5 — DISCONTINUED OPERATIONS

Sale of Unconventional Gas Production Business

In December 2012, the Company sold its 100% equity interest in its Unconventional Gas Production business which consisted of gas and oil production assets in the western Barnett and Marble Falls shale areas of Texas. The activity of the discontinued business for the three and nine months ended September 30, 2012 is shown below. The amounts exclude general corporate overhead costs, and the related tax effects, and no portion of corporate interest costs were allocated to discontinued operations.

	Three Months Ended		Nine Months Ended
	September 30, 2012		September 30, 2012
	(In millions)
Operating Revenues	$	16	$	38
Operation and Maintenance	6		16
Depreciation, Depletion and Amortization	6		17
Taxes Other Than Income	1		2
Operating Income	3		3
Other (Income) and Deductions	1		4
Income Tax Expense (Benefit)	1		(1		)
Net Income Attributable to DTE Energy Company	$	1	$	—

NOTE 6 — ASSET RETIREMENT OBLIGATIONS

A reconciliation of the asset retirement obligations for the nine months ended September 30, 2013 follows:

	(In millions)
Asset retirement obligations at December 31, 2012	$	1,719
Accretion	79
Liabilities incurred	1
Liabilities settled	(12		)
Revision in estimated cash flows	13
Asset retirement obligations at September 30, 2013	$	1,800

NOTE 7 — REGULATORY MATTERS

Transition of the City of Detroit's Public Lighting Department's (PLD) Customers to DTE Electric's Distribution System

Accounting Authority

On June 28, 2013, DTE Electric filed an application for accounting authority to defer certain costs associated with the transition of the City of Detroit's PLD customers to the DTE Electric distribution system over a five to seven year system conversion period. The Company requested authority to defer as a regulatory asset, all net incremental revenue requirement associated with the transition. The net incremental revenue requirement includes costs to install meters and attach customers; system and customer facility upgrades and repairs; and the difference between DTE Electric's tariff rates and any transitional rates approved in the future. On July 11, 2013, the MPSC approved DTE Electric's request to defer, for accounting purposes, the net incremental revenue requirement.

The approval excludes the request to defer the difference between DTE Electric's tariff rates and any transitional rates that might be approved by the MPSC in the future. The MPSC will address proposed rates and recovery matters in a future contested proceeding. As the accounting order did not provide a regulatory recovery mechanism, a regulatory asset will not be recognized until a regulatory recovery mechanism is put into place and the recovery of the regulatory asset becomes probable.

25

DTE Energy Company

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

Transitional Reconciliation Mechanism (TRM)

On July 19, 2013, DTE Electric filed its TRM application proposing a transitional tariff option for certain former PLD customers and a modified line extension provision. The application also proposes a recovery mechanism for the deferred incremental revenue requirement described above. The application further discusses that DTE Electric will be requesting recovery, in subsequent PSCR cases, of PLD transmission delivery service costs incurred while DTE Electric is temporarily relying upon PLD to operate and maintain PLD's system during the system conversion period. If the MPSC determines that the transmission costs are not recoverable in the PSCR, the Company requested recovery as part of the TRM.

2009 Electric Rate Case Filing - Court of Appeals Remand to MPSC

In April 2012, the Michigan Court of Appeals (COA) issued a decision relating to an appeal of the January 2010 MPSC rate order in DTE Electric's January 2009 rate case filing. The COA found that the record of evidence in the January 2010 rate order was insufficient to support the MPSC's authorization to recover costs for the advanced metering infrastructure (AMI) program and remanded this matter to the MPSC. On October 17, 2013, the MPSC issued an order affirming the approximately $8 million rate increase authorized in the MPSC's January 2010 rate order for the AMI program and further concluded that the evidence presented after remand supports the authorized cost recovery.

2010 Electric Rate Case Filing - Court of Appeals Decision

In July 2013, the COA issued a decision relating to an appeal of the October 2011 MPSC order in DTE Electric's October 2010 rate case filing. The COA found that the record of evidence in the 2010 rate case order was insufficient to support the MPSC's authorization to recover costs for the AMI program and remanded this matter to the MPSC. The MPSC had approved $55 million of the average rate base related to the AMI program in the October 2011 order. DTE Electric is currently operating its AMI program pursuant to the MPSC's approval set forth in the October 2011 order. On August 29, 2013, the MPSC reopened the 2010 electric rate case for the limited purpose of addressing the COA's opinion on AMI. The Company is unable to predict the outcome of this matter or the timing of its resolution.

Power Supply Cost Recovery 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 and sulfur dioxide emission allowances costs, urea costs, transmission costs and MISO costs. The MPSC reviews these costs, policies and practices for prudence in annual plan and reconciliation filings.

2012 PSCR Year - In March 2013, DTE Electric filed the 2012 PSCR reconciliation calculating a net under-recovery of approximately $87 million that includes an under-recovery of approximately $148 million for the 2011 PSCR year. The reconciliation includes approximately $30 million of purchased power costs related to the manual shutdown of our 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 July 30, 2012 which restored production to nominal 68% of full capacity. In September 2013, the repair to the plant was completed and production was returned to full capacity. We were able to purchase sufficient power from MISO to continue to provide uninterrupted service to our customers. Certain intervenors in the reconciliation case have challenged the recovery of some or all of the Fermi-related purchased power costs. Resolution of this matter is expected in 2014.

Low Income Energy Assistance Fund (LIEAF)

On July 1, 2013, Michigan Public Act 95 was signed into law and created the LIEAF. The legislation allows the use of a LIEAF funding factor to be determined by the MPSC and assessed on all customer classes of Michigan electric utilities to fund the LIEAF. On July 29, 2013, the MPSC adopted a funding factor of $0.99 per meter per month for all Michigan electric utilities that are participating in the program, including DTE Electric, effective with the September 2013 billing month. The surcharge billed by DTE Electric is remitted to the State of Michigan for subsequent distribution through a grant process to social service agencies and utilities to assist low income customers.

DTE Gas Uncollectible Expense True-Up Mechanism (UETM)

In March 2013, DTE Gas filed an application with the MPSC for approval of its UETM reconciliation for 2012 requesting authority to refund approximately $20 million. On September 10, 2013, the MPSC approved a settlement agreement approving the requested 2012 UETM refund over a twelve-month period beginning in October 2013.

26

DTE Energy Company

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

NOTE 8 — COMMON STOCK

During 2013, the Company contributed the following amounts of DTE Energy Common stock to the DTE Energy Company Affiliates Employee Benefit Plans Master Trust:

Date	Number of Shares	Price Per Share		Amount
				(In millions)
March 12, 2013	750,075	$	66.66	$	50
June 12, 2013	753,579	$	66.35	50
September 12, 2013	1,522,301	$	65.69	100
				$	200

The shares for all the contributions were valued at the closing market price of DTE Energy common stock on the contribution dates in accordance with fair value measurement and accounting requirements.

NOTE 9 — EARNINGS PER SHARE

The Company reports both basic and diluted earnings per share. The calculation of diluted earnings per share assumes the issuance of potentially dilutive common shares outstanding during the period from the exercise of stock options. A reconciliation of both calculations is presented in the following table for the three months and nine months ended September 30:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2013		2012		2013		2012
	(In millions, except per share amounts)
Basic Earnings per Share
Net income attributable to DTE Energy Company	$	198	$	227	$	537	$	529
Average number of common shares outstanding	175		172		174		171
Weighted average net restricted shares outstanding	—		1		1		1
Dividends declared — common shares	$	115	$	106	$	337	$	307
Dividends declared — net restricted shares	1		1		1		2
Total distributed earnings	$	116	$	107	$	338	$	309
Net income less distributed earnings	$	82	$	120	$	199	$	220
Distributed (dividends per common share)	$	0.66	$	0.62	$	1.93	$	1.80
Undistributed	0.47		0.70		1.14		1.29
Total Basic Earnings per Common Share	$	1.13	$	1.32	$	3.07	$	3.09
Diluted Earnings per Share
Net income attributable to DTE Energy Company	$	198	$	227	$	537	$	529
Average number of common shares outstanding	176		172		175		171
Average incremental shares from assumed exercise of options	—		—		—		—
Common shares for dilutive calculation	176		172		175		171
Weighted average net restricted shares outstanding	—		1		1		1
Dividends declared — common shares	$	115	$	106	$	337	$	307
Dividends declared — net restricted shares	1		1		1		2
Total distributed earnings	$	116	$	107	$	338	$	309
Net income less distributed earnings	$	82	$	120	$	199	$	220
Distributed (dividends per common share)	$	0.66	$	0.62	$	1.93	$	1.80
Undistributed	0.47		0.69		1.14		1.28
Total Diluted Earnings per Common Share	$	1.13	$	1.31	$	3.07	$	3.08

27

DTE Energy Company

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

NOTE 10 — LONG-TERM DEBT

Debt Issuances

In 2013, the following debt was issued:

Company	Month Issued	Type	Interest Rate		Maturity	Amount
						(In millions)
DTE Electric	March	Mortgage Bonds (a)	4.00	%	2043	$	375
DTE Electric	August	Mortgage Bonds (a)	3.65	%	2024	400
						$	775

_______________________________________

(a) Proceeds were used for the redemption of DTE Electric long-term debt, for the repayment of short-term borrowings, and for general corporate purposes.

In September 2013, DTE Gas agreed to issue $50 million of 3.64%, 10-year mortgage bonds, $70 million of 3.74%, 12-year mortgage bonds, and $50 million of 3.94%, 15-year mortgage bonds to a group of institutional investors in a private placement transaction. The bonds are expected to close and fund in December 2013. The aggregate proceeds are planned to be used for general corporate purposes.

Debt Redemptions

In 2013, the following debt was redeemed:

Company	Month	Type	Interest Rate		Maturity	Amount
						(In millions)
DTE Electric	March	Securitization Bonds	6.42	%	2013	$	88
DTE Electric	March	Tax Exempt Revenue Bonds (a)	5.30	%	2030	51
DTE Electric	April	Other Long-Term Debt	Various		2013	13
DTE Gas	April	Senior Notes	5.26	%	2013	60
DTE Energy	Various	Other Long-Term Debt	Various		2013	4
DTE Energy	June	Senior Notes	Variable		2013	300
DTE Electric	September	Securitization Bonds	6.62	%	2015	89
DTE Electric	September	Senior Notes	6.40	%	2013	250
						$	855

_______________________________________

(a) 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.

NOTE 11 — SHORT-TERM CREDIT ARRANGEMENTS AND BORROWINGS

DTE Energy and its wholly owned subsidiaries, DTE Electric and DTE Gas, have unsecured revolving credit agreements with a syndicate of 19 banks that can be used for general corporate borrowings, but are intended to provide liquidity support for each of the companies’ commercial paper programs. No one bank provides more than 8.7% of the commitment in any facility. Borrowings under the facilities are available at prevailing short-term interest rates. Additionally, DTE Energy has other facilities to support letter of credit issuance.

The agreements require the Company 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 the Company and its 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 stockholders’ equity of the Company and its 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 September 30, 2013, the total funded debt to total capitalization ratios for DTE Energy, DTE Electric and DTE Gas are 0.48 to 1, 0.53 to 1 and 0.44 to 1, respectively, and are in compliance with this financial covenant. The availability under the facilities in place at September 30, 2013 is shown in the following table:

28

DTE Energy Company

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

	DTE Energy		DTE Electric		DTE Gas		Total
	(In millions)
Unsecured letter of credit facility, expiring in May 2014	$	50	$	—	$	—	$	50
Unsecured letter of credit facility, expiring in August 2015	125		—		—		125
Unsecured revolving credit facility, expiring April 2018	1,200		300		300		1,800
Total credit facilities at September 30, 2013	1,375		300		300		1,975
Amounts outstanding at September 30, 2013:
Commercial paper issuances	44		11		216		271
Letters of credit	235		—		—		235
	279		11		216		506
Net availability at September 30, 2013	$	1,096	$	289	$	84	$	1,469

The Company has other outstanding letters of credit which are not included in the above described facilities totaling approximately $47 million which are used for various corporate purposes.

In conjunction with maintaining certain exchange traded risk management positions, the Company may be required to post cash collateral with its clearing agent. The Company 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 the Company posts a letter of credit for the incremental amount. At September 30, 2013, a $40 million letter of credit was in place, raising the capacity under this facility to $140 million. The $40 million letter of credit is included in the table above. The amount outstanding under this agreement was $75 million and $65 million at September 30, 2013 and December 31, 2012, respectively.

NOTE 12 — COMMITMENTS AND CONTINGENCIES

Environmental

Electric

Air - DTE Electric is subject to the EPA ozone and fine particulate transport and acid rain regulations that limit power plant emissions of sulfur dioxide and nitrogen oxides. Since 2005, the EPA and the State of Michigan have issued additional emission reduction regulations relating to ozone, fine particulate, regional haze, mercury, and other air pollution. These rules have led to additional controls on fossil-fueled power plants to reduce nitrogen oxide, sulfur dioxide, mercury and other emissions. To comply with these requirements, DTE Electric spent approximately $1.9 billion through 2012. The Company estimates DTE Electric will make capital expenditures of approximately $190 million in 2013 and up to approximately $1.8 billion of additional capital expenditures through 2021 based on current regulations. Further, additional rulemakings are expected over the next few years which could require additional controls for sulfur dioxide, nitrogen oxides and hazardous air pollutants. The Cross State Air Pollution Rule (CSAPR), finalized in July 2011, required further reductions of sulfur dioxide and nitrogen oxides emissions beginning in 2012. On December 30, 2011, the U.S. Court of Appeals for the District of Columbia (D.C.) Circuit granted the motions to stay the rule, leaving DTE Electric temporarily subject to the previously existing Clean Air Interstate Rule (CAIR). On August 21, 2012, the Court issued its decision, vacating CSAPR and leaving CAIR in place. The EPA's petition seeking a rehearing of the U.S. Court of Appeals' decision regarding the CSAPR was denied on January 24, 2013. On June 24, 2013, the U.S. Supreme Court granted EPA's petition asking the Court to review the D.C. Circuit Court's decision on CSAPR. A ruling by the Supreme Court is not expected before 2014. Notwithstanding the appeal filed with the Supreme Court, the EPA and a number of states have started working on the framework of revised CSAPR regulations which we anticipate to be proposed in the next few years.

The Mercury and Air Toxics Standard (MATS) rule, formerly known as the Electric Generating Unit Maximum Achievable Control Technology (EGU MACT) Rule was finalized on December 16, 2011. The MATS rule requires reductions of mercury and other hazardous air pollutants beginning in April 2015, with a potential extension to April 2016. DTE Electric has requested and been granted compliance date extensions for some units to April 2016. DTE Electric has tested technologies to determine technological and economic feasibility as MATS compliance alternatives to Flue Gas Desulfurization (FGD) systems. Implementation of Dry Sorbent Injection (DSI) and Activated Carbon Injection (ACI) technologies will allow several units that would not have been economical for FGD installations to continue operation in compliance with MATS.

29

DTE Energy Company

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

In July 2009, DTE Energy received a Notice of Violation/Finding of Violation (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. On August 23, 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. On October 20, 2011, the EPA caused to be filed a Notice of Appeal to the U.S. Court of Appeals for the Sixth Circuit. On March 28, 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. On September 3, 2013, the EPA caused to be filed a motion seeking leave to amend their complaint regarding the June 2010 NOV/FOV adding additional claims related to outage work performed at the Trenton Channel and Belle River power plants as well as additional claims related to work performed at the Monroe Power Plant. In addition, the Sierra Club caused to be filed a motion to add a claim regarding the River Rouge Power Plant. The EPA and Sierra Club motions are currently pending with the U. S. District Court Judge.

DTE Energy and DTE Electric believe that the plants identified by the EPA, including Unit 2 of the Monroe Power Plant, have complied with all applicable federal environmental regulations. Depending upon the outcome of discussions with the EPA regarding the two NOVs/FOVs, DTE Electric could be required to install additional pollution control equipment at some or all of the power plants in question, implement early retirement of facilities where control equipment is not economical, engage in supplemental environmental programs, and/or pay fines. The Company cannot predict the financial impact or outcome of this matter, or the timing of its resolution.

On March 13, 2013, the Sierra Club filed suit against DTE Energy and DTE Electric alleging violations of the Clean Air Act at four of DTE Electric's coal-fired power plants. The plaintiffs allege 1,4996-minute periods of excess opacity of air emissions from 2007-2012 at those facilities. The suit asks that the court enjoin DTE Energy and DTE Electric from operating the power plants except in complete compliance with applicable laws and permit requirements, pay civil penalties, conduct beneficial environmental mitigation projects, pay attorney fees and require the installation of any necessary pollution controls or to convert and/or operate the plants' boilers on natural gas to avoid additional violations and to off-set historic unlawful emissions. The resolution of this matter is not expected to have a material effect on the Company's operations or financial statements.

Water — In response to an EPA regulation, DTE Electric would be 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. The initial rule published in 2004 was subsequently remanded and a proposed rule published in 2011. The proposed rule specified an eight year compliance timeline. In July 2012, the EPA announced that a notice of its final action on the rule will be issued in June 2013. On June 27, 2013, the EPA announced an agreement to extend the deadline for issuance of the final rule until November 4, 2013. On April 19, 2013, the EPA proposed revised steam electric effluent guidelines regulating wastewater streams from coal-fired power plants including multiple possible options for compliance. The rules are expected to be finalized by May 2014. DTE Electric has provided comments to the EPA. However, it is not possible at this time to quantify the impacts of these developing requirements.

30

DTE Energy Company

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

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 manufactured gas plant (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 site. In addition to the MGP sites, the Company 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 September 30, 2013 and December 31, 2012, the Company had $9 million accrued for remediation. Any change in assumptions, such as remediation techniques, nature and extent of contamination and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect the Company’s financial position and cash flows. The Company believes that the likelihood of a materially greater liability than the accrued amount is remote based on current knowledge of the conditions at each site.

DTE Electric owns and operates a permitted engineered ash storage facility at the Monroe Power Plant to dispose of fly ash from the coal fired power plant. The EPA has published proposed rules to regulate coal ash under the authority of the Resources Conservation and Recovery Act (RCRA). The proposed rule published in June 2010 contains two primary regulatory options to regulate coal ash residue. The EPA is currently considering either designating coal ash as a “Hazardous Waste” as defined by RCRA or regulating coal ash as non-hazardous waste under RCRA. Agencies and legislatures have urged the EPA to regulate coal ash as a non-hazardous waste. If the EPA designates coal ash as a hazardous waste, the agency could apply some, or all, of the disposal and reuse standards that have been applied to other existing hazardous wastes to disposal and reuse of coal ash. Some of the regulatory actions currently being contemplated could have a significant impact on our operations and financial position and the rates we charge our customers. It is not possible to quantify the impact of those expected rulemakings at this time.

Gas

Contaminated Sites — Gas segment, owns or previously owned, 15 former MGP sites. Investigations have revealed contamination related to the by-products of gas manufacturing at each site. In addition to the MGP sites, the Company is also in the process of cleaning up other contaminated sites. Cleanup activities associated with these sites will be conducted 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. Accordingly, Gas segment recognizes a liability and corresponding Regulatory asset for estimated investigation and remediation costs at former MGP sites. As of September 30, 2013 and December 31, 2012, the Company had $29 million accrued for remediation. Any change in assumptions, such as remediation techniques, nature and extent of contamination and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect the Company’s financial position and cash flows. The Company 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 and the cost deferral and rate recovery mechanism for Citizens Fuel Gas approved by the City of Adrian, will prevent environmental costs from having a material adverse impact on the Company’s results of operations.

Non-utility

The Company’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 the Company’s position of demonstrated compliance and has not initiated escalated enforcement. At this time, the Company cannot predict the impact of this issue. Furthermore, the Michigan coke battery facility is the subject of an investigation by the MDEQ concerning visible emissions readings that resulted from the Company self reporting to MDEQ questionable activities by an employee of a contractor hired by the Company to perform the visible emissions readings. At this time, the Company cannot predict the impact of this investigation.

31

DTE Energy Company

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

The Company 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. The Company has implemented best management practices to address this issue. The Company recently received a permit to upgrade its existing waste water treatment system and is currently seeking a permit from the PADEP to upgrade its wastewater treatment technology to a biological treatment facility. The Company expects to spend less than $7 million on the existing waste water treatment system to comply with existing water discharge requirements and to upgrade its coal pile storm water runoff management program.

The Company believes that its non-utility businesses are substantially in compliance with all environmental requirements, other than as noted above.

Other

In March 2011, the EPA finalized a new set of regulations regarding the identification of non-hazardous secondary materials that are considered solid waste, industrial boiler and process heater maximum achievable control technologies (IBMACT) for major and area sources, and commercial/industrial solid waste incinerator new source performance standard and emission guidelines (CISWI). The effective dates of the major source IBMACT and CISWI regulations were stayed anda re-proposal was issued by the EPA in December 2011. Final IBMACT and CISWI were issued by the EPA in December 2012. The Company is developing compliance plans to upgrade or convert existing industrial boilers to natural gas and to perform required energy assessments in compliance with the applicable new standards. Capital costs for the boiler conversions and the expenses for the one-time energy assessments are not expected to be material.

In 2010, the EPA finalized a new 1-hour sulfur dioxide ambient air quality standard that requires states to submit plans for non-attainment areas to be in compliance by 2017. Michigan's non-attainment area includes DTE Energy facilities in southwest Detroit and areas of Wayne County. Preliminary modeling runs by the MDEQ suggest that emission reductions may be required by significant sources of sulfur dioxide emissions in these areas, including DTE Electric power plants and our Michigan coke battery. The state implementation plan process is in the information gathering stage and any required emission reductions for DTE Energy sources to meet the standard cannot be estimated currently.

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. The Nuclear Electric Insurance Limited (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 $500 million in primary coverage and $2.25 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, subject to a $1 million deductible. As of April 1, 2013, the total limit for property damage for non-nuclear events is $1.8 billion and an aggregate of $327 million of coverage for extra expenses over a two-year period.

In 2007, the Terrorism Risk Insurance Extension Act of 2005 (TRIA) was extended through December 31, 2014. A major change in the extension is the inclusion of “domestic” acts of terrorism in the definition of covered or “certified” acts. 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 the NEIL policies, DTE Electric could be liable for maximum assessments of up to approximately $34 million per event if the loss associated with any one event at any insured nuclear plant should exceed the accumulated funds available to NEIL.

32

DTE Energy Company

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

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 $127.3 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 U.S. Department of Energy (DOE) for the future storage and disposal of spent nuclear fuel from Fermi 2. DTE Electric is obligated to pay the DOE a fee of 1 mill per kWh of Fermi 2 electricity generated and sold. The fee is 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 currently employs a spent nuclear fuel storage strategy utilizing a fuel pool. The Company continues to develop its on-site dry cask storage facility and anticipates initial offload from the spent fuel pool in 2014. 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.

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 provided for a payment of approximately $48 million, received in August 2012, for delay-related costs experienced by DTE Electric through 2010, and a claims process for submittal of delay-related costs from 2011 through 2013. DTE Electric has begun the claims process and all claims submitted have been accepted. The settlement proceeds reduced the cost of the dry cask storage facility assets. In February 2013, the U.S. Court of Appeals for the District of Columbia granted a motion to reopen the fee adequacy litigation to review the DOE's latest fee adequacy report which was released in January 2013. DTE Electric will continue to pay fees to the U.S. government's nuclear waste fund pending further action by the D.C. Circuit. The federal government continues to maintain its legal obligation to accept spent nuclear fuel from Fermi 2 for permanent storage. Issues relating to long-term waste disposal policy and to the disposition of funds contributed by DTE Electric ratepayers to the federal waste fund await future governmental action.

Synthetic Fuel Guarantees

The Company discontinued the operations of its synthetic fuel production facilities throughout the United States as of December 31, 2007. The Company 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 and will survive until 90 days after expiration of all applicable statutes of limitations. The Company estimates that its maximum potential liability under these guarantees at September 30, 2013 is approximately $1.2 billion. Payment under these guarantees is considered remote.

Reduced Emissions Fuel Guarantees

The Company has provided certain guarantees and indemnities in conjunction with the sales of interests in its reduced emissions fuel facilities. The guarantees cover potential commercial, environmental, and tax-related obligations and will survive until 90 days after expiration of all applicable statutes of limitations. The Company estimates that its maximum potential liability under these guarantees at September 30, 2013 is approximately $125 million. Payment under these guarantees is considered remote.

Other Guarantees

In certain limited circumstances, the Company enters into contractual guarantees. The Company may guarantee another entity’s obligation in the event it fails to perform. The Company may provide guarantees in certain indemnification agreements. Finally, the Company may provide indirect guarantees for the indebtedness of others. The Company’s guarantees are not individually material with maximum potential payments totaling $60 million at September 30, 2013. Payment under these guarantees is considered remote.

33

DTE Energy Company

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

The Company 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 September 30, 2013, the Company had approximately $41 million of performance bonds outstanding. In the event that such bonds are called for nonperformance, the Company would be obligated to reimburse the issuer of the performance bond. The Company 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

Our contracts with several bargaining units for the majority of our represented employees were due to expire in June 2013, October 2013 and June 2014. Early negotiations resulted in new contracts that became effective in March 2013. The new contracts will expire in March, June and October 2017.

Purchase Commitments

As of September 30, 2013, the Company was party to numerous long-term purchase commitments relating to a variety of goods and services required for the Company’s business. These agreements primarily consist of fuel supply commitments, renewable energy contracts and energy trading contracts. The Company estimates that these commitments will be approximately $6.2 billion from 2013 through 2052.

The Company also estimates that 2013 capital expenditures will be approximately $2.1 billion. The Company has made certain commitments in connection with expected capital expenditures.

Bankruptcies

The Company purchases and sells electricity, natural gas, coal, coke and other energy products from and to governmental entities and numerous companies operating in the steel, automotive, energy, retail, financial and other industries. Certain of its customers have filed for bankruptcy protection under the U.S. Bankruptcy Code. The Company regularly reviews contingent matters relating to these customers and its purchase and sale contracts and records provisions for amounts considered at risk of probable loss. The Company believes its accrued amounts are adequate for probable loss.

The Company's utilities provide services to the city of Detroit, Michigan (Detroit). Detroit filed for Chapter 9 bankruptcy protection on July 18, 2013. The Company had pre-petition accounts receivable of approximately $20 million outstanding as of the bankruptcy filing date. Detroit has been paying amounts owed in a timely manner and its accounts are substantially current. The Company does not expect Detroit's bankruptcy filing to have a material impact on its financial results.

Other Contingencies

The Company is 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 Company cannot predict the final disposition of such proceedings. The Company regularly reviews legal matters and records provisions for claims that it can estimate and are considered probable of loss. The resolution of these pending proceedings is not expected to have a material effect on the Company’s operations or financial statements in the periods they are resolved.

See Notes 4 and 7 for a discussion of contingencies related to derivatives and regulatory matters.

34

DTE Energy Company

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

NOTE 13 — RETIREMENT BENEFITS AND TRUSTEED ASSETS

The following table details the components of net periodic benefit costs for pension benefits and other postretirement benefits:

	Pension Benefits						Other Postretirement Benefits
	2013			2012			2013			2012
Three Months Ended September 30	(In millions)
Service cost	$	22		$	20		$	9		$	15
Interest cost	49			51			21			29
Expected return on plan assets	(67		)	(61		)	(28		)	(23		)
Amortization of:
Net actuarial loss	55			48			16			21
Prior service credit	—			—			(36		)	(6		)
Net periodic benefit cost (credit)	$	59		$	58		$	(18	)	$	36

	Pension Benefits						Other Postretirement Benefits
	2013			2012			2013			2012
Nine Months Ended September 30	(In millions)
Service cost	$	71		$	61		$	37		$	51
Interest cost	144			153			66			90
Expected return on plan assets	(200		)	(183		)	(82		)	(69		)
Amortization of:
Net actuarial loss	156			133			48			60
Prior service credit	—			—			(95		)	(20		)
Net transition liability	—			—			—			1
Settlements	—			2			—			—
Net periodic benefit cost (credit)	$	171		$	166		$	(26	)	$	113

Pension and Other Postretirement Contributions

During the first nine months of 2013, the Company contributed $250 million to its pension plans, including contributions of DTE Energy common stock of $200 million. See Note 8. At the discretion of management, and depending upon financial market conditions, the Company may make up to an additional $25 million contribution to its pension plans in 2013.

In January 2013, the Company contributed $145 million to its other postretirement benefit plans. At the discretion of management, the Company may make up to an additional $120 million contribution to its other postretirement benefit plans in 2013.

Re-Measurement of Other Postretirement Benefit Obligation

In March 2013, the Company reached agreements on new four-year labor contracts with certain represented employees under several bargaining units. As a term of the agreements, the Company replaced sponsored retiree medical, prescription drug and dental coverage for future Medicare eligible retirees with a Retiree Health Care Allowance (RHCA) account of $3,250 per year. The modification in retiree health coverage will reduce future postretirement benefit costs.

35

DTE Energy Company

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

Based on the impact of such benefit cost savings on the financial statements, the Company re-measured its retiree health plan as of March 31, 2013. In performing the re-measurement, the Company updated its significant actuarial assumptions, including an adjustment to the discount rate from 4.15% at December 31, 2012 to 4.30% at March 31, 2013. Plan assets were also updated to reflect fair value as of the re-measurement date. As a result of the re-measurement, the accumulated postretirement benefit obligation (APBO) was reduced by $258 million. The Company's Accrued postretirement benefit liability at March 31, 2013 was $721 million as compared to $1.2 billion at December 31, 2012, a reduction of $439 million. The reduction reflects the impact of the re-measurement of the plan, January 2013 plan contributions and recognition of first quarter 2013 postretirement benefit costs and benefit payments.

Beginning April 2013, net postretirement benefit costs were recorded based on the updated actuarial assumptions and benefit changes resulting from the new labor contracts. As a result of the re-measurement, fiscal year 2013 postretirement benefit costs are expected to decrease by approximately $69 million to an annual net benefit of approximately $40 million.

NOTE 14 — STOCK-BASED COMPENSATION

The following table summarizes the components of stock-based compensation:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2013		2012		2013		2012
	(In millions)
Stock-based compensation expense	$	18	$	21	$	81	$	61
Tax benefit	$	7	$	8	$	31	$	23
Stock-based compensation cost capitalized in property, plant and equipment	$	1	$	1	$	5	$	3

Stock Options

The following table summarizes our stock option activity for the nine months ended September 30, 2013:

	Number of Options		Weighted Average Exercise Price		Aggregate Intrinsic Value (In millions)
Options outstanding at December 31, 2012	1,192,670		$	41.86
Exercised	(399,139	)	$	40.54
Forfeited or expired	(10,370	)	$	41.46
Options outstanding at September 30, 2013	783,161		$	42.54	$	20
Options exercisable at September 30, 2013	783,161		$	42.54	$	20

As of September 30, 2013, the weighted average remaining contractual life for the exercisable shares is 4.17 years. During the nine months ended September 30, 2013, 200,844 options vested. As of September 30, 2013, all options were vested.

The intrinsic value of options exercised for the nine months ended September 30, 2013 and 2012 was $11 million and $21 million, respectively. No option expense was recognized for the nine months ended September 30, 2013 and $0.5 million of option expense was recognized for the nine months ended September 30, 2012.

The Company includes both historical and implied share-price volatility in option volatility. Implied volatility is derived from exchange traded options on DTE Energy common stock. The Company’s expected option life estimate is based on historical data.

36

DTE Energy Company

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

Restricted Stock Awards

The following table summarizes the Company’s restricted stock awards activity for the nine months ended September 30, 2013:

	Restricted Stock		Weighted Average Grant Date Fair Value
Balance at December 31, 2012	597,648		$	48.33
Grants	127,785		$	64.72
Forfeitures	(5,621	)	$	53.53
Vested and issued	(218,600	)	$	45.39
Balance at September 30, 2013	501,212		$	53.71

Performance Share Awards

The following table summarizes the Company’s performance share activity for the nine months ended September 30, 2013:

	Performance Shares
Balance at December 31, 2012	1,634,364
Grants	549,360
Forfeitures	(36,168	)
Payouts	(548,624	)
Balance at September 30, 2013	1,598,932

Unrecognized Compensation Costs

As of September 30, 2013, there was $72 million of total unrecognized compensation cost related to non-vested stock incentive plan arrangements. That cost is expected to be recognized over a weighted-average period of 1.18 years.

NOTE 15 — SEGMENT AND RELATED INFORMATION

The Company sets strategic goals, allocates resources and evaluates performance based on the following structure:

Electric segment consists principally of DTE Electric, which is engaged in the generation, purchase, distribution and sale of electricity to approximately 2.1 million residential, commercial and industrial customers in southeastern Michigan.

Gas segment consists of DTE Gas and Citizens.  DTE Gas is engaged in the purchase, storage, transportation, distribution and sale of natural gas to approximately 1.2 million residential, commercial and industrial customers throughout Michigan and the sale of storage and transportation capacity. Citizens distributes natural gas in Adrian, Michigan to approximately 17,000 customers.

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

Power and Industrial Projects is comprised primarily of projects that deliver energy and utility-type products and services to industrial, commercial and institutional customers; produce reduced emissions fuel (REF) and sell electricity from biomass-fired energy projects.

Energy Trading consists of energy marketing and trading operations.

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

37

DTE Energy Company

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

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

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

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
	(In millions)
Inter-segment Revenues
Electric	$	6		$	7		$	19		$	22
Gas	2			1			4			3
Gas Storage and Pipelines	(2		)	1			2			5
Power and Industrial Projects	231			225			621			608
Energy Trading	13			10			36			34
Corporate and Other	(8		)	(11		)	(23		)	(28		)
Discontinued Operations	—			1			—			1
	$	242		$	234		$	659		$	645

Financial data of the business segments follows:

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
	(In millions)
Operating Revenues
Electric	$	1,458		$	1,543		$	3,942		$	4,031
Gas	161			160			1,013			883
Gas Storage and Pipelines	34			21			92			73
Power and Industrial Projects	512			477			1,431			1,375
Energy Trading	463			223			1,307			723
Corporate & Other	1			—			2			2
Reconciliation & Eliminations	(242		)	(234		)	(659		)	(645		)
Total	$	2,387		$	2,190		$	7,128		$	6,442

Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	179		$	194		$	383		$	417
Gas	(13		)	4			91			60
Gas Storage and Pipelines	16			14			49			48
Power and Industrial Projects	27			22			46			40
Energy Trading	(6		)	1			(1		)	3
Corporate & Other	(5		)	(9		)	(31		)	(39		)
Discontinued operations	—			1			—			—
Net Income Attributable to DTE Energy	$	198		$	227		$	537		$	529

38

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

OVERVIEW

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

Net income attributable to DTE Energy in the third quarter of 2013 was $198 million, or $1.13 per diluted share, compared to net income attributable to DTE Energy of $227 million, or $1.31 per diluted share, in the third quarter of 2012. Net income attributable to DTE Energy in the nine months ended September 30, 2013 was $537 million, or $3.07 per diluted share, compared to net income attributable to DTE Energy of $529 million, or $3.08 per diluted share, in the comparable period of 2012. The decrease in net income in the third quarter is primarily due to lower earnings in the Electric, Gas and Energy Trading segments, partially offset by higher earnings in the Power and Industrial Projects segment. The increase in net income for the nine months ended September 30, 2013 is primarily due to higher earnings in the Gas and Power and Industrial projects segments, partially offset by lower earnings in the Electric and Energy Trading segments.

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

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

Our utilities' growth will be driven by environmental and renewable investments in addition to base infrastructure investments. We are focused on executing plans to achieve operational excellence and customer satisfaction with a focus on customer affordability. We operate in a constructive regulatory environment and have solid relationships with our regulators.

We have significant investments in our non-utility businesses. We employ disciplined investment criteria when assessing meaningful, low-risk growth opportunities that leverage our assets, skills and expertise and provide diversity in earnings and geography. Specifically, we invest in targeted energy markets with attractive competitive dynamics where meaningful scale is in alignment with our risk profile. We expect 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, issuance of debt and issuance of equity through our dividend reinvestment plan and pension and other employee benefit plans. We have an enterprise risk management program that, among other things, is designed to monitor and manage our exposure to earnings and cash flow volatility related to commodity price changes, interest rates and counterparty credit risk.

CAPITAL INVESTMENTS

Our utility businesses require significant base capital investments each year in order to maintain and improve the reliability of asset bases, including power generation plants, distribution systems, storage fields and other facilities and fleets. DTE Electric's capital investments over the 2013-2017 period are estimated at $5.0 billion for base infrastructure, $900 million for environmental compliance requirements and $500 million for renewable energy and energy efficiency expenditures. 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's capital investments over the 2013-2017 period are estimated at $680 million for base infrastructure and $400 million for gas main renewal and meter move out and pipeline integrity programs. In April 2013, the MPSC issued an order approving an infrastructure recovery mechanism (IRM) and authorized the recovery of the cost of service related to $77 million of annual investment in its gas main renewal and meter move out and pipeline integrity programs. DTE Gas plans to seek regulatory approval in general rate case filings for base infrastructure capital expenditures consistent with prior ratemaking treatment.

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ENVIRONMENTAL MATTERS

We 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. We expect to continue recovering environmental costs related to utility operations through rates charged to our customers.

DTE Electric is subject to the EPA ozone and fine particulate transport and acid rain regulations that limit power plant emissions of sulfur dioxide and nitrogen oxides. Since 2005, the EPA and the State of Michigan have issued additional emission reduction regulations relating to ozone, fine particulate, regional haze and mercury air pollution. These rules will lead to additional emission controls on fossil-fueled power plants to reduce nitrogen oxide, sulfur dioxide and mercury emissions. To comply with these requirements, DTE Electric spent approximately $1.9 billion through 2012. It is estimated that DTE Electric will make capital expenditures of approximately $190 million in 2013 and up to approximately $1.8 billion of additional capital expenditures through 2021 based on current regulations.

Climate regulation and/or legislation has been proposed and discussed within the U.S. Congress and the EPA. The EPA is implementing regulatory actions under the Clean Air Act to address emissions of greenhouse gases (GHGs). EPA regulation of GHGs requires the best available control technology (BACT) for new major sources or modifications to existing major sources that cause significant increases in GHG emissions. In June 2012, the EPA proposed new source performance standards for carbon dioxide emissions from new fossil-fueled power plants. These new source performance standards were re-proposed on September 20, 2013, under a presidential directive issued on June 25, 2013. Under the same presidential directive, the EPA is expected to propose performance standards for carbon dioxide emissions from existing and modified plants by June 1, 2014 and issue final standards by June 1, 2015. DTE Energy will be an active participant in working with the EPA and other stakeholders to shape the final performance standards for new and existing power plants. The standards for new sources are not expected to have a material impact on the Company. It is not possible to determine the potential impact of future regulations on existing sources at this time. Pending or future legislation or other regulatory actions could have a material impact on our operations and financial position and the rates we charge our customers. Impacts include expenditures for environmental equipment beyond what is currently planned, financing costs related to additional capital expenditures, the purchase of emission offsets from market sources and the retirement of facilities where control equipment is not economical. We would seek to recover these incremental costs through increased rates charged to our utility customers. Increased costs for energy produced from traditional sources could also increase the economic viability of energy produced from renewable and/or nuclear sources and energy efficiency initiatives and the development of market-based trading of carbon offsets providing business opportunities for our utility and non-utility segments. It is not possible to quantify these impacts on DTE Energy or its customers at this time.

See Note 12 of the Notes to the Consolidated Financial Statements.

OUTLOOK

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

Looking forward, we will focus on several areas that we expect will improve future performance:

• improving Electric and Gas customer satisfaction;

• effectively managing rate competitiveness and affordability;

• continuing to pursue regulatory stability and investment recovery for our utilities;

• managing the growth of our utility asset base;

• continuing to improve employee engagement;

• optimizing our cost structure across all business segments;

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

• investing in businesses that integrate our assets and leverage our skills and expertise.

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We will continue to pursue opportunities to grow our businesses in a disciplined manner if we can secure opportunities that meet our strategic, financial and risk criteria.

RESULTS OF OPERATIONS

The following sections provide a detailed discussion of the operating performance and future outlook of our segments.

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
	(In millions)
Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	179		$	194		$	383		$	417
Gas	(13		)	4			91			60
Gas Storage and Pipelines	16			14			49			48
Power and Industrial Projects	27			22			46			40
Energy Trading	(6		)	1			(1		)	3
Corporate and Other	(5		)	(9		)	(31		)	(39		)
Income From Continuing Operations Attributable to DTE Energy Company	198			226			537			529
Discontinued Operations	—			1			—			—
Net Income Attributable to DTE Energy Company	$	198		$	227		$	537		$	529

ELECTRIC

Our Electric segment consists principally of DTE Electric.

Electric results are discussed below:

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
	(In millions)
Operating Revenues	$	1,458		$	1,543		$	3,942		$	4,031
Fuel and Purchased Power	487			543			1,294			1,348
Gross Margin	971			1,000			2,648			2,683
Operation and Maintenance	336			338			1,010			1,027
Depreciation and Amortization	236			220			671			611
Taxes Other Than Income	66			65			200			193
Asset (Gains) and Losses, Reserves and Impairments, Net	(3		)	—			(3		)	(1		)
Operating Income	336			377			770			853
Other (Income) and Deductions	61			68			183			190
Income Tax Expense	96			115			204			246
Net Income Attributable to DTE Energy Company	$	179		$	194		$	383		$	417
Operating Income as a Percent of Operating Revenues	23		%	24		%	20		%	21		%

Gross margin decreased $29 million and $35 million in the three and nine months ended September 30, 2013, respectively. Revenues associated with certain tracking mechanisms and surcharges are offset by related expenses elsewhere in the Consolidated Statement of Operations.

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

	Three Months			Nine Months
	(In millions)
Base sales, inclusive of weather effect	$	(46	)	$	(59	)
Securitization bond and tax surcharge	5			29
Renewable energy program	12			20
Low income energy assistance surcharge	—			(20		)
Regulatory mechanisms and other	—			(5		)
Decrease in gross margin	$	(29	)	$	(35	)

	Three Months Ended		Nine Months Ended
	September 30,		September 30,
	2013	2012	2013	2012
	(In thousands of MWh)
Electric Sales
Residential	4,401	4,894	11,600	12,180
Commercial	4,504	4,602	12,585	12,734
Industrial	2,635	2,707	7,746	7,645
Other	233	238	701	717
	11,773	12,441	32,632	33,276
Interconnection sales (a)	711	441	2,276	1,827
Total Electric Sales	12,484	12,882	34,908	35,103
Electric Deliveries
Retail and Wholesale	11,773	12,441	32,632	33,276
Electric Customer Choice, including self generators (b)	1,393	1,372	3,940	3,938
Total Electric Sales and Deliveries	13,166	13,813	36,572	37,214

______________________________

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

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

Operation and maintenance expense decreased $2 million and $17 million in the three and nine months ended September 30, 2013, respectively. The decrease in the third quarter was due primarily to lower employee benefit expenses of $21 million and lower distribution operations expenses of $4 million, partially offset by higher corporate administrative expenses of $11 million, higher restoration and line clearance expenses of $4 million, increased energy optimization and renewable energy expenses of $4 million, increased uncollectible expenses of $2 million and increased low income energy assistance expenses of $2 million. The decrease in the nine-month period was primarily due to lower employee benefit expenses of $52 million, decreased low income energy assistance expenses of $18 million and lower power plant generation expenses of $2 million, partially offset by higher corporate administrative expenses of $22 million, higher energy optimization and renewable energy expenses of $12 million, increased uncollectible expenses of $11 million, higher restoration and line clearance expenses of $7 million and increased distribution operations expenses of $4 million.

Depreciation and amortization expense increased $16 million and $60 million in the three and nine months ended September 30, 2013, respectively. The increase in the third quarter was due to higher amortization of regulatory assets of $11 million and $5 million of increased expense due to a higher depreciable base. The increase in the nine-month period was due to $45 million of higher amortization of regulatory assets and $15 million of increased expense due to a higher depreciable base.

Income tax expense decreased $19 million and $42 million in the three and nine months ended September 30, 2013, respectively, due to lower pre-tax income and a decrease in the effective income tax rate primarily due to higher production tax credits.

Outlook— We continue to move forward in our efforts to achieve operational excellence, sustained strong cash flows and earn our authorized return on equity. We expect that our planned significant environmental and renewable expenditures will result in earnings growth. Looking forward, additional factors may impact earnings such as weather, the outcome of regulatory proceedings, benefit plan design changes, investment returns and changes in discount rate assumptions in benefit plans and health care costs, and uncertainty of legislative or regulatory actions regarding climate change and electric choice. We expect to continue our efforts to improve productivity and decrease our costs while improving customer satisfaction with consideration of customer rate affordability.

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In June 2013, the City of Detroit announced a transition of its Public Lighting Department's customers to the DTE Electric distribution system over a five to seven year system conversion period. See Note 7 of the Notes to Consolidated Financial Statements.

GAS

Our Gas segment consists of DTE Gas and Citizens.

Gas results are discussed below:

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
	(In millions)
Operating Revenues	$	161		$	160		$	1,013		$	883
Cost of Gas	29			21			408			359
Gross Margin	132			139			605			524
Operation and Maintenance	105			89			316			286
Depreciation and Amortization	24			23			71			69
Taxes Other Than Income	12			10			43			42
Operating Income (Loss)	(9		)	17			175			127
Other (Income) and Deductions	11			11			34			35
Income Tax Expense (Benefit)	(7		)	2			50			32
Net Income (Loss) Attributable to DTE Energy Company	$	(13	)	$	4		$	91		$	60
Operating Income (Loss) as a Percent of Operating Revenues	(6		)%	11		%	17		%	14		%

Gross margin decreased $7 million and increased $81 million in the three and nine months ended September 30, 2013, respectively. Revenues associated with certain tracking mechanisms and surcharges are offset by related expenses elsewhere in the Consolidated Statement of Operations.

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

	Three Months			Nine Months
	(In millions)
Weather	$	—		$	51
2012 rate order	—			14
Lost and stolen gas	(4		)	9
Energy optimization revenue	(2		)	4
Uncollectible tracking mechanism	1			22
Revenue decoupling mechanism	(3		)	(14		)
Other	1			(5		)
Increase (decrease) in gross margin	$	(7	)	$	81

	Three Months Ended		Nine Months Ended
	September 30,		September 30,
	2013	2012	2013	2012
Gas Markets (in Bcf)
Gas sales	10	7	86	68
End user transportation	24	33	111	115
	34	40	197	183
Intermediate transportation	81	42	233	186
	115	82	430	369

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Operation and maintenance expense increased $16 million and $30 million in the three and nine months ended September 30, 2013, respectively. The increase in the third quarter was primarily due to higher maintenance and repair costs of $7 million, higher gas operations expenses of $6 million, higher transmission expenses of $3 million and increased uncollectible expenses of $2 million, partially offset by lower employee benefit expenses of $4 million and lower energy optimization expenses of $2 million. The increase in the nine-month period was primarily due to higher maintenance and repair costs of $12 million, higher gas operations expenses of $10 million, higher transmission expenses of $9 million, higher uncollectible expenses of $5 million and increased energy optimization expenses of $4 million, partially offset by lower employee benefit expenses of $13 million.

Outlook — We continue to move forward in our efforts to achieve operational excellence, sustained strong cash flows and earn our authorized return on equity. We expect that our planned significant infrastructure capital expenditures 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. We expect to continue our efforts to improve productivity and decrease our costs while improving customer satisfaction with consideration of customer rate affordability.

GAS STORAGE AND PIPELINES

Our Gas Storage and Pipelines segment consists of our non-utility gas pipelines and storage businesses.

Gas Storage and Pipelines results are discussed below:

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
	(In millions)
Operating Revenues	$	34		$	21		$	92		$	73
Operation and Maintenance	7			5			19			15
Depreciation and Amortization	6			1			14			5
Taxes Other Than Income	1			1			3			3
Operating Income	20			14			56			50
Other (Income) and Deductions	(7		)	(10		)	(26		)	(30		)
Income Tax Expense	10			9			31			30
Net Income	17			15			51			50
Noncontrolling interest	1			1			2			2
Net Income Attributable to DTE Energy	$	16		$	14		$	49		$	48

Net income attributable to DTE Energy increased $2 million and increased $1 million in the three and nine months ended September 30, 2013, respectively. The increases were primarily driven by higher net income from the Bluestone and Susquehanna projects and higher earnings from equity investments, offset by lower gas storage revenue.

Outlook — Our Gas Storage and Pipelines business expects to maintain its steady growth by developing an asset portfolio with multiple growth platforms through investment in new projects and expansions. Millennium Pipeline has secured customers for its Phase One and Phase Two expansions, which are scheduled to be in service in 2013 and 2014, respectively. Millennium's total capacity with the Phase One and Two expansions will increase from 525,000 dth/d to over 800,000 dth/d. Additionally, Bluestone, a 44-mile lateral pipeline in Susquehanna County, Pennsylvania and Broome County, New York designed to initially flow over 600,000 dth/d to Millennium Pipeline and Tennessee Pipeline, is in service and volumes are increasing. Through our agreement with Southwestern Energy, Bluestone lateral and Susquehanna gathering system are strategically positioned for future growth of the Marcellus shale.

POWER AND INDUSTRIAL PROJECTS

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 (REF) and sell electricity from biomass-fired energy projects.

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Power and Industrial Projects results are discussed below:

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
	(In millions)
Operating Revenues	$	512		$	477		$	1,431		$	1,375
Operation and Maintenance	499			455			1,402			1,338
Depreciation and Amortization	18			14			53			43
Taxes other than Income	4			3			12			12
Asset (Gains) and Losses, Reserves and Impairments, Net	(3		)	(2		)	(2		)	(9		)
Operating Income (Loss)	(6		)	7			(34		)	(9		)
Other (Income) and Deductions	(29		)	(13		)	(54		)	(28		)
Income Taxes
Expense	7			7			6			6
Production Tax Credits	(12		)	(11		)	(35		)	(31		)
	(5		)	(4		)	(29		)	(25		)
Net Income	28			24			49			44
Noncontrolling interest	1			2			3			4
Net Income Attributable to DTE Energy Company	$	27		$	22		$	46		$	40

Operating revenues increased $35 million and $56 million in the three and nine months ended September 30, 2013, respectively. The increase in the third quarter of 2013 was primarily due to a $52 million increase associated with higher volumes from REF projects, of which $9 million represent affiliate transactions, and a $33 million increase primarily due to newly acquired on-site projects, offset by a $30 million decrease from lower volumes associated with coal transportation and marketing activities due to the sale of our coal transloading terminal in December 2012, and a $20 million decrease from lower prices and volumes associated with the steel business. The increase in the nine-month period was primarily due to a $103 million increase from newly acquired on-site projects, a $68 million increase associated with higher volumes from REF projects, of which $18 million represent affiliate transactions, partially offset by a $62 million decrease due to lower volumes associated with coal transportation and marketing activities, and a $53 million decrease from lower prices and volumes associated with the steel business.

Operation and maintenance expense increased $44 million and $64 million in the three and nine months ended September 30, 2013, respectively. The increase in the third quarter of 2013 was primarily due to a $53 million increase associated with higher volumes from REF projects, of which $9 million represent affiliate transactions, a $27 million increase primarily due to newly acquired on-site projects, and a $3 million increase associated with the mobilization and start-up of a biomass-fired power project, offset by a $25 million decrease from lower volumes associated with coal transportation and marketing activities, and a $15 million decrease from lower prices and volumes associated with the steel business. The increase in the nine-month period was primarily due to a $91 million increase from newly acquired on-site projects, a $72 million increase associated with higher volumes from REF projects, of which $18 million represent affiliate transactions, partially offset by a $55 million decrease due to lower volumes associated with coal transportation and marketing activities, and a $44 million decrease in prices and volumes associated with the steel business.

Asset (gains) losses, reserves and impairments,net decreased by $7 million in the nine months ended September 30, 2013, due primarily to a $6 million asset impairment at an on-site facility.

Other (income) and deductions increased by $16 million and $26 million in the three and nine months ended September 30, 2013, respectively. The increase in the third quarter was due primarily to a $8 million increase in gains recognized in connection with sales of a membership interests in REF facilities (treated as sales of tax credits for financial reporting purposes), and a $2 million increase related to higher equity earnings at various projects. The year to date increase was due primarily to a $14 million increase in gains recognized in connection with sales of membership interests in REF facilities (treated as sales of tax credits for financial reporting purposes), and a $7 million increase related to higher equity earnings at various projects.

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Outlook - The Company has constructed and placed in service nine REF facilities including four facilities located at third party owned coal-fired power plants. The Company has sold membership interests in four of the facilities. We continue to optimize these facilities by seeking investors for facilities operating at DTE Electric and other utility sites. Additionally, we intend to relocate two underutilized facilities, located at DTE Electric sites, to alternative coal-fired power plants which may provide increased production and emission reduction opportunities in 2014 and future years. The proceeds from executed and planned sales of membership interests in the REF facilities are expected to be received by the Company on an installment basis, and the Company will recognize the related gains (treated as sales of tax credits for financial reporting purposes) as production tax credits are generated by the respective facilities.

We expect sustained production levels of metallurgical coke and pulverized coal supplied to steel industry customers for 2014. Substantially all of the metallurgical coke margin is maintained under long-term contracts. We have four biomass-fired power generation facilities in operation, and we are converting an additional facility to be placed in service in 2013. Our on-site energy services will continue to be delivered in accordance with the terms of long-term contracts. We will begin construction on a new natural gas-fired cogeneration facility and two landfill gas to energy projects during the year which will be completed in 2014. We will continue to look for additional investment opportunities and other energy projects at favorable prices.

Power and Industrial Projects will continue to leverage its extensive energy-related operating experience and project management capability to develop additional energy projects to serve energy intensive industrial customers.

ENERGY TRADING

Energy Trading focuses on physical and financial power, natural gas and coal marketing and trading, structured transactions, enhancement of returns from DTE Energy’s asset portfolio, and optimization of contracted natural gas pipeline transportation and storage, and generating capacity positions. Energy Trading also provides natural gas, power and related services, which may include the management of associated storage and transportation contracts on the customers’ behalf, and the supply or purchase of renewable energy credits to various customers.

Energy Trading results are discussed below:

	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2013			2012		2013			2012
	(In millions)
Operating Revenues	$	463		$	223	$	1,307		$	723
Fuel, Purchased Power and Gas	453			202		1,242			658
Gross Margin	10			21		65			65
Operation and Maintenance	17			17		57			52
Depreciation and Amortization	—			1		1			1
Taxes Other Than Income	1			—		3			2
Operating Income (Loss)	(8		)	3		4			10
Other (Income) and Deductions	2			2		6			6
Income Tax Expense (Benefit)	(4		)	—		(1		)	1
Net Income (Loss) Attributable to DTE Energy Company	$	(6	)	$	1	$	(1	)	$	3

Gross margin decreased $11 million and was consistent with 2012 for the three and nine months ended September 30, 2013, respectively. The overall decrease in gross margin for the third quarter was primarily due to timing related losses in the gas structured strategy.

The third quarter decrease of $11 million represents a $13 million decrease in unrealized margins and a $2 million increase in realized margins. The $13 million decrease in unrealized margins is due to $30 million of unfavorable results, primarily due to timing related losses in our gas structured strategy, and unfavorable results in our power full requirements strategy, partially offset by $17 million of favorable results, primarily in our gas full requirements and gas trading strategies. The $2 million increase in realized margins is due to $11 million of favorable results, primarily in our power and gas trading strategies, partially offset by $9 million of unfavorable results, primarily in our gas transportation, gas storage and power origination strategies.

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The nine months ended September 30, 2013 represents a $10 million increase in realized margins and $10 million decrease in unrealized margins. The $10 million increase in realized margins is due to $27 million of favorable results, primarily in our gas trading, gas full requirements, and gas storage strategies, partially offset by $17 million of unfavorable results, primarily in our gas transportation, power trading and power origination strategies. The $10 million decrease in unrealized margins is due to $19 million of unfavorable results, primarily in our gas trading and gas structured strategies, partially offset by $9 million of favorable results, primarily in our gas full requirements, gas storage, and power trading strategies.

Outlook - In the near-term, we expect market conditions to remain challenging and the profitability of this segment may be impacted by the volatility or lack thereof in commodity prices in the markets we participate in and the uncertainty of impacts associated with financial reform, regulatory changes and changes in operating rules of regional transmission organizations.

The Energy Trading portfolio includes financial instruments, physical commodity contracts and natural gas inventory, as well as contracted natural gas pipeline transportation and storage, and generation capacity 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 under FERC Asset Management Arrangements, and the supply or purchase of renewable energy credits to various customers. 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, we will experience earnings volatility as derivatives are marked-to-market without revaluing the underlying non-derivative contracts and assets. Our strategy is to economically manage the price risk of these underlying non-derivative contracts and assets with futures, forwards, swaps and options. This results in gains and losses that are recognized in different interim and annual accounting periods.

See Notes 3 and 4 of the Notes to Consolidated Financial Statements.

CORPORATE AND OTHER

Corporate and Other includes various holding company activities and holds certain non-utility debt and energy-related investments. Net losses of $5 million and $31 million in the three and nine months ended September 30, 2013, respectively, were improvements of $4 million and $8 million, respectively, from the losses in the comparable 2012 periods.

DISCONTINUED OPERATIONS

Unconventional Gas Production

In December 2012, the Company sold its 100% equity interest in its Unconventional Gas Production business which consisted of gas and oil production assets in the western Barnett and Marble Falls shale areas of Texas. See Note 5 of the Notes to Consolidated Financial Statements.

CAPITAL RESOURCES AND LIQUIDITY

Cash Requirements

We use cash to maintain and expand our electric and natural gas utilities and to grow our non-utility businesses, retire and pay interest on long-term debt and pay dividends. We believe that we will have sufficient internal and external capital resources to fund anticipated capital and operating requirements. In 2013, we expect that cash from operations will be approximately $1.9 billion. We anticipate base level utility capital investments, environmental, renewable and energy optimization expenditures and expenditures for non-utility businesses in 2013 of approximately $2.1 billion. We plan to seek regulatory approval to include utility capital expenditures in our 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 our strict risk-return and value creation criteria.

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	Nine Months Ended September 30,
	2013			2012
	(In millions)
Cash and Cash Equivalents
Cash Flow From (Used For)
Operating activities:
Net income	$	542		$	535
Depreciation, depletion and amortization	811			747
Nuclear fuel amortization	25			25
Allowance for equity funds used during construction	(10		)	(10		)
Deferred income taxes	162			96
Asset (gains) and losses, reserves and impairments, net	(5		)	(7		)
Working capital and other	190			343
	1,715			1,729
Investing activities:
Plant and equipment expenditures — utility	(1,101		)	(1,008		)
Plant and equipment expenditures — non-utility	(270		)	(214		)
Proceeds from sale of assets	20			20
Other	14			18
	(1,337		)	(1,184		)
Financing activities:
Issuance of long-term debt	768			495
Redemption of long-term debt	(855		)	(447		)
Short-term borrowings, net	31			(321		)
Issuance of common stock	29			29
Dividends on common stock and other	(345		)	(310		)
	(372		)	(554		)
Net Increase (Decrease) in Cash and Cash Equivalents	$	6		$	(9	)

Cash from Operating Activities

A majority of our operating cash flow is provided by our electric and natural gas utilities, which are significantly influenced by factors such as weather, electric Customer Choice, regulatory deferrals, regulatory outcomes, economic conditions and operating costs.

Cash from operations in the nine months ended September 30, 2013 was $14 million lower than the comparable 2012 period. The operating cash flow comparison reflects lower cash generated from working capital items partially offset by higher net income after adjusting for non-cash and non-operating items (primarily depreciation, depletion and amortization, and deferred income taxes).

Cash from Investing Activities

Cash inflows associated with investing activities are primarily generated from the sale of assets, while cash outflows are the result of plant and equipment expenditures. In any given year, we will look 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 our electric generation and electric and natural gas distribution infrastructure and to comply with environmental regulations and renewable energy requirements.

Capital spending within our non-utility businesses is primarily for ongoing maintenance, expansion and growth. We look 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. We have been disciplined in how we deploy capital and will not make investments unless they meet our criteria. For new business lines, we initially invest based on research and analysis. We start with a limited investment, we evaluate results and either expand or exit the business based on those results. In any given year, the amount of growth capital will be determined by the underlying cash flows of the Company with a clear understanding of any potential impact on our credit ratings.

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Net cash used for investing activities was higher by $153 million in 2013 due primarily to increased capital expenditures by our utility and non-utility businesses.

Cash from Financing Activities

We rely on both short-term borrowing and long-term financing as a source of funding for our capital requirements not satisfied by our operations.

Our strategy is to have a targeted debt portfolio blend of fixed and variable interest rates and maturity. We continually evaluate our leverage target, which is currently 50 percent to 52 percent, to ensure it is consistent with our objective to have a strong investment grade debt rating.

Net cash used for financing activities was lower by $182 million in 2013 due primarily to increased short-term borrowings and issuances of long-term debt, partially offset by increased redemption of long-term debt and higher dividends on common stock.

Outlook

We expect cash flow from operations to increase over the long-term primarily as a result of growth from our utilities and non-utility businesses. We expect growth in our utilities to be driven primarily by capital spending to maintain and improve our 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. Our non-utility growth is expected from additional investments primarily in our Gas Storage and Pipelines and Power and Industrial Projects segments.

We 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. We are continuing our efforts to identify opportunities to improve cash flow through working capital initiatives and maintaining flexibility in the timing and extent of our long-term capital projects.

We have approximately $900 million in long-term debt maturing in the next twelve months. The repayment of the principal amount of the Securitization debt is funded through a surcharge payable by DTE Electric’s customers. The repayment of the other debt is expected to be paid through internally generated funds or the issuance of long-term debt.

DTE Energy has approximately $1.5 billion of available liquidity at September 30, 2013, consisting of cash and amounts available under unsecured revolving credit agreements.

During the first nine months of 2013, the Company contributed $250 million to its pension plans, including a contribution of DTE Energy common stock of $200 million. At the discretion of management, and depending upon financial market condition, the Company may make up to an additional $25 million contribution to its pension plans in 2013. In January 2013, the Company contributed $145 million to its other postretirement benefit plans. At the discretion of management, the Company may make up to an additional $120 million contribution to its other postretirement benefit plans in 2013.

Various subsidiaries of the Company have entered into contracts which contain ratings triggers and are guaranteed by DTE Energy. These contracts contain provisions which allow the counterparties to request that the Company post cash or letters of credit as collateral in the event that DTE Energy’s credit rating is downgraded below investment grade. As of September 30, 2013, the value of the transactions for which the Company would have been exposed to collateral requests had DTE Energy’s credit rating been below investment grade on such date was approximately $327 million. In circumstances where an entity is downgraded below investment grade and collateral requests are made as a result, the requesting parties often agree to accept less than the full amount of their exposure to the downgraded entity. In addition, the Company maintains adequate credit facilities to meet this obligation should such an occurrence arise.

We believe we have sufficient operating flexibility, cash resources and funding sources to maintain adequate amounts of liquidity and to meet our future operating cash and capital expenditure needs. However, virtually all of our 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 7, 8, 10, 11 and 13 of the Notes to Consolidated Financial Statements.

49

FAIR VALUE

Derivatives are generally recorded at fair value and shown as Derivative Assets or Liabilities. Contracts we typically classify as derivative instruments include power, natural gas, oil and certain coal forwards, futures, options and swaps, and foreign currency exchange contracts. Items we do not generally account for as derivatives include natural gas inventory, pipeline transportation, renewable energy credits and storage assets. See Notes 3 and 4 of the Notes to Consolidated Financial Statements.

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 DTE Energy’s 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 Company manages its mark-to-market (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 Company has 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 3 of the Notes to Consolidated Financial Statements.

The following tables provide details on changes in our MTM net asset (or liability) position for the nine months ended September 30, 2013:

	Total
	(In millions)
MTM at December 31, 2012	$	(4	)
Reclassify to realized upon settlement	(49		)
Changes in fair value recorded to income	56
Amounts recorded to unrealized income	7
Changes in fair value recorded in regulatory liabilities	7
Amounts recorded in other comprehensive income, pretax	1
Change in collateral held by (for) others	(9		)
Option premiums paid and other	17
MTM at September 30, 2013	$	19

The table below shows the maturity of our MTM positions:

Source of Fair Value	2013			2014			2015			2016  and  Beyond		Total Fair Value
	(In millions)
Level 1	$	27		$	(12	)	$	(5	)	$	—	$	10
Level 2	24			(1		)	(1		)	—		22
Level 3	(17		)	9			2			2		(4		)
MTM before collateral adjustments	$	34		$	(4	)	$	(4	)	$	2	28
Collateral adjustments												(9		)
MTM at September 30, 2013												$	19

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Item 3. Quantitative and Qualitative Disclosures About Market Risk

Market Price Risk

DTE Energy has commodity price risk in both utility and non-utility businesses arising from market price fluctuations.

The Electric and Gas business segments have risks in conjunction with the anticipated purchases of coal, natural gas, uranium, electricity, and base metals to meet their service obligations. However, the Company does 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 revenue and uncollectible expenses at the Gas segment. Gas segment manages its market price risk related to storage sales revenue primarily through the sale of long-term storage contracts. The Company is exposed to short-term cash flow or liquidity risk as a result of the time differential between actual cash settlements and regulatory rate recovery.

Our Gas Storage and Pipelines business segment has exposure to natural gas price fluctuations which impact the pricing for natural gas storage and transportation. The Company manages its exposure through the use of short, medium and long-term storage and transportation contracts.

Our Power and Industrial Projects business segment is subject to electricity and natural gas product price risk. The Company manages its exposures to commodity price risk through the use of long-term contracts.

Our 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 our 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

The Company purchases and sells electricity, natural gas, coal, coke and other energy products from and to governmental entities and numerous companies operating in the steel, automotive, energy, retail, financial and other industries. Certain of its customers have filed for bankruptcy protection under the U.S. Bankruptcy Code. The Company regularly reviews contingent matters relating to these customers and its purchase and sale contracts and records provisions for amounts considered at risk of probable loss. The Company believes its accrued amounts are adequate for probable loss.

The Company's utilities provide services to the city of Detroit, Michigan (Detroit). Detroit filed for Chapter 9 bankruptcy protection on July 18, 2013. The Company had pre-petition accounts receivable of approximately $20 million outstanding as of the bankruptcy filing date. Detroit has been paying amounts owed in a timely manner and its account is substantially current. The Company does not expect Detroit's bankruptcy filing to have a material impact on its financial results.

Other

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

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Trading Activities

We are exposed to credit risk through trading activities. Credit risk is the potential loss that may result if our trading counterparties fail to meet their contractual obligations. We utilize both external and internal credit assessments when determining the credit quality of our trading counterparties. The following table displays the credit quality of our trading counterparties as of September 30, 2013:

	Credit Exposure Before Cash Collateral		Cash Collateral			Net Credit Exposure
	(In millions)
Investment Grade (a)
A− and Greater	$	149	$	—		$	149
BBB+ and BBB	235		—			235
BBB−	109		—			109
Total Investment Grade	493		—			493
Non-investment grade (b)	1		—			1
Internally Rated — investment grade (c)	121		—			121
Internally Rated — non-investment grade (d)	28		(9		)	19
Total	$	643	$	(9	)	$	634

_______________________________________

(a) This category includes counterparties with minimum credit ratings of Baa3 assigned by Moody’s Investors Service (Moody’s) and 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 34 percent 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 1 percent 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 12 percent 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 4 percent of the total gross credit exposure.

Interest Rate Risk

We are subject to interest rate risk in connection with the issuance of debt. In order to manage interest costs, we may use treasury locks and interest rate swap agreements. Our exposure to interest rate risk arises primarily from changes in U.S. Treasury rates, commercial paper rates and London Inter-Bank Offered Rates (LIBOR). As of September 30, 2013, we had a floating rate debt-to-total debt ratio of approximately 4 percent (excluding securitized debt).

Foreign Currency Exchange Risk

We have 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 our exposure to foreign currency exchange fluctuations, we have entered into a series of foreign currency exchange forward contracts through July 2016.

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Summary of Sensitivity Analysis

We performed a sensitivity analysis on the fair values of our commodity contracts, long-term debt obligations and foreign currency exchange forward contracts. The commodity contracts and foreign currency exchange risk listed below principally relate to our energy marketing and trading activities. The sensitivity analysis involved increasing and decreasing forward rates at September 30, 2013 and 2012 by a hypothetical 10% and calculating the resulting change in the fair values.

The results of the sensitivity analysis calculations as of September 30, 2013 and 2012:

	Assuming a 10% Increase in Rates						Assuming a 10% Decrease in Rates
	As of September 30,						As of September 30,
Activity	2013			2012			2013			2012			Change in the Fair Value of
	(In millions)
Coal contracts	$	(1	)	$	3		$	1		$	(1	)	Commodity contracts
Natural gas contracts	$	(10	)	$	(9	)	$	10		$	10		Commodity contracts
Electricity contracts	$	11		$	3		$	(6	)	$	(3	)	Commodity contracts
Interest rate risk	$	(303	)	$	(225	)	$	322		$	237		Long-term debt
Foreign currency exchange risk	$	—		$	(1	)	$	—		$	1		Forward contracts
Discount rates	$	—		$	—		$	—		$	—		Commodity contracts

For further discussion of market risk, see Note 4 of the Notes to Consolidated Financial Statements.

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Item 4.Controls and Procedures

(a) Evaluation of disclosure controls and procedures

Management of the Company carried out an evaluation, under the supervision and with the participation of DTE Energy's Chief Executive Officer (CEO) and Chief Financial Officer (CFO), of the effectiveness of the design and operation of the Company's disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of September 30, 2013, which is the end of the period covered by this report. Based on this evaluation, the Company'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 the Company 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 SEC's rules and forms and (ii) is accumulated and communicated to the Company's management, including its CEO and CFO, as appropriate to allow timely decisions regarding required disclosure. Due to the inherent limitations in the effectiveness of any disclosure controls and procedures, management cannot provide absolute assurance that the objectives of its disclosure controls and procedures will be attained.

(b) Changes in internal control over financial reporting

There have been no changes in the Company's internal control over financial reporting during the quarter ended September 30, 2013 that have materially affected, or are reasonably likely to materially affect, the Company's internal control over financial reporting.

54

Part II — OTHER INFORMATION

Item 1. Legal Proceedings

In July 2009, DTE Energy received a Notice of Violation/Finding of Violation (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. On August 23, 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. On October 20, 2011, the EPA caused to be filed a Notice of Appeal to the U.S. Court of Appeals for the Sixth Circuit. On March 28, 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. On September 3, 2013, the EPA caused to be filed a motion seeking leave to amend their complaint regarding the June 2010 NOV/FOV adding additional claims related to outage work performed at the Trenton Channel and Belle River power plants as well as additional claims related to work performed at the Monroe Power Plant. In addition, the Sierra Club caused to be filed a motion to add a claim regarding the River Rouge Power Plant. The EPA and Sierra Club motions are currently pending with the U. S. District Court Judge.

DTE Energy and DTE Electric believe that the plants identified by the EPA, including Unit 2 of the Monroe Power Plant, have complied with all applicable federal environmental regulations. Depending upon the outcome of discussions with the EPA regarding the two NOVs/FOVs, DTE Electric could be required to install additional pollution control equipment at some or all of the power plants in question, implement early retirement of facilities where control equipment is not economical, engage in supplemental environmental programs, and/or pay fines. The Company cannot predict the financial impact or outcome of this matter, or the timing of its resolution.

On March 13, 2013, the Sierra Club filed suit against DTE Energy and DTE Electric alleging violations of the Clean Air Act at four of DTE Electric's coal-fired power plants. The plaintiffs allege 1,499 6-minute periods of excess opacity of air emissions from 2007-2012 at those facilities. The suit asks that the court enjoin DTE Energy and DTE Electric from operating the power plants except in complete compliance with applicable laws and permit requirements, pay civil penalties, conduct beneficial environmental mitigation projects, pay attorney fees and require the installation of any necessary pollution controls or to convert and/or operate the plants' boilers on natural gas to avoid additional violations and to off-set historic unlawful emissions. The resolution of this matter is not expected to have a material effect on the Company's operations or financial statements.

For additional discussion on legal matters, see Notes 7 and 12 of the Notes to Consolidated Financial Statements.

Item 1A. Risk Factors

There are various risks associated with the operations of DTE Energy's utility and non-utility businesses. To provide a framework to understand the operating environment of DTE Energy, we have provided a brief explanation of the more significant risks associated with our businesses in Part 1, Item 1A. Risk Factors in the Company's 2012 Form 10-K. Although we have tried to identify and discuss key risk factors, others could emerge in the future. In addition to the risk factors set forth in our 10-K, the following updated risk could affect our performance.

55

A work interruption may adversely affect us. Unions represent approximately 4,900 of our employees. Our contracts with several bargaining units for the majority of our represented employees were due to expire in June and October 2013. Early negotiations resulted in new contracts that became effective in March 2013. The new contracts will expire in June 2017 for the DTE Electric bargaining units and in October 2017 for the DTE Gas bargaining units. A union choosing to strike would have an impact on our business. We are unable to predict the effect a work stoppage would have on our costs of operation and financial performance.

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

On September 12, 2013, the Company contributed $100 million of DTE Energy common stock to the DTE Energy Company Affiliates Employee Benefit Plans Master Trust. The contribution consisted of 1,522,301 shares valued at $65.69 per share, the closing market price of DTE Energy common stock on that date in accordance with fair value measurement and accounting requirements. The shares were contributed to the trust in a private placement transaction made in reliance upon the exemption from registration provided by Section 4(2) of the Securities Act of 1933 as amended.

The following table provides information about our purchases of equity securities that are registered by the Company pursuant to Section 12 of the Exchange Act for the quarter ended September 30, 2013:

	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
07/01/2013 — 07/31/2013	1,005	$	65.77	—	—	—
08/01/2013 — 08/31/2013	2,152	$	68.95	—	—	—
09/01/2013 — 09/30/2013	1,000	$	68.34	—	—	—
Total	4,157			—

_______________________________________

(a) Represents shares of common stock withheld to satisfy income tax obligations upon the vesting of restricted stock.

Item 6. Exhibits

	(i) Exhibits filed herewith:
10-87	DTE Energy Affiliates Nonqualified Plans Master Trust, effective as of August 15, 2013
12-55	Computation of Ratio of Earnings to Fixed Charges
31-85	Chief Executive Officer Section 302 Form 10-Q Certification of Periodic Report
31-86	Chief Financial Officer Section 302 Form 10-Q Certification of Periodic Report
101.INS	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema
101.CAL	XBRL Taxonomy Extension Calculation Linkbase
101.DEF	XBRL Taxonomy Extension Definition Database
101.LAB	XBRL Taxonomy Extension Label Linkbase
101.PRE	XBRL Taxonomy Extension Presentation Linkbase

	(ii) Exhibits incorporated herein by reference:
4-281	Supplemental Indenture, dated as of August 1, 2013, to the Mortgage and Deed of Trust dated as of October 1, 1924, between DTE Electric Company and The Bank of New York Mellon, N.A., as successor trustee (Exhibit 4-281 to DTE Electric Form 10-Q for the quarter ended September 30, 2013). (2013 Series B)

56

	(iii) Exhibits furnished herewith:
32-85	Chief Executive Officer Section 906 Form 10-Q Certification of Periodic Report
32-86	Chief Financial Officer Section 906 Form 10-Q Certification of Periodic Report

57

Signature

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

		DTE ENERGY COMPANY
		(Registrant)
Date: October 25, 2013	By	/s/  DONNA M. ENGLAND
		Donna M. England Chief Accounting Officer (Principal Accounting Officer)

58

EX-10.87

EXHIBIT 10-87

DTE ENERGY AFFILIATES

NONQUALIFIED PLANS MASTER TRUST

This Trust Agreement is made effective the 15th day of August, 2013 by and between DTE Energy Company, a corporation organized under the laws of the state of Michigan or any successor corporation (the "Company"), and State Street Bank and Trust Company, a trust company incorporated under the laws of the Commonwealth of Massachusetts (the “Trustee") .

RECITALS:

A.The Company previously adopted the non-qualified deferred compensation plans listed in Appendix A (the "Plans").

B.Appendix A may be revised by the Company from time to time prior to a Change in Control to add or delete Plans by delivering to the Trustee a new Appendix A without requiring an amendment of the Trust Agreement.

C.The Company has incurred and expects to incur liability under the terms of the Plans with respect to the individuals participating in the Plans.

D.The Company previously established an irrevocable grantor trust (the "Trust") and has contributed and expects to continue to contribute to the Trust assets to be held in the Trust subject to the claims of the creditors of the Company and, to the extent provided herein, the creditors of Participating Affiliated Companies in the event of Insolvency, as herein defined, until paid to Plan Participants and their Beneficiaries in such manner and at such times as specified in the Plan(s).

E.It is the intention of the parties that this Trust shall constitute an unfunded arrangement and shall not affect the status of the Plans as unfunded plans maintained primarily for the purpose of providing deferred compensation for a select group of management or highly compensated employees for purposes of Title I of the Employee Retirement Income Security Act of 1974.

F.It is the intention of the Company to make contributions to the Trust to provide itself with a source of funds to assist it in the meeting of its liabilities under the Plans.

G.The Company has appointed the Trustee as the successor to the Bank of New York Mellon as the trustee of the Trust, and the Trustee accepts this appointment, effective September 3, 2013.

The Company and the Trustee now amend and restate the Trust and agree that the Trust shall be comprised, held and disposed of as follows.

SECTION 1

DEFINITIONS

(a)"AFFILIATED COMPANY" means any corporation while such corporation is a member of the same controlled group of corporations (within the meaning of Code section 414(b)) as the Company or any other employing entity while such entity is under common control (within the meaning of Code section 414(c)) with the Company.

(b)"BENEFICIARY" means the person, persons or entity designated in writing by a Participant, on forms provided by the Company, to receive distribution of certain death benefits payable under a Plan in the event of the Participant's death.

(c)“BOARD" or "BOARD OF DIRECTORS" means the Board of Directors of DTE Energy Company.

(d)"CHANGE IN CONTROL" means the occurrence of anyone of the following events:

(1)Individuals who, on January 1, 2002, constitute the Board (the "Incumbent Directors") cease for any reason to constitute at least a majority of the Board, provided that:

(A)Any person becoming a director subsequent to January 1, 2002, whose election or nomination for election was approved by a vote of at least two-thirds of the Incumbent Directors then on the Board (either by a specific vote or by approval of the proxy statement of the Company in which such person is named as a nominee for director, without written objection to such nomination) shall be an Incumbent Director;

(B)No individual initially elected or nominated as a director of the Company as a result of an actual or threatened election contest (as such terms are used in Rule 14a-11 of Regulation 14A promulgated under the Securities Exchange Act of 1934, as amended (the "Exchange Act")) with respect to directors or as a result of any other actual or threatened solicitation of proxies (or consents) by or on behalf of any person other than the Board shall be deemed to be an Incumbent Director; or

(2)Any "person" (as such term is defined in Section 3(a)(9) of the Exchange Act and as used in Sections 13(d)(3) and 14(d)(2) of the Exchange Act) is or becomes a "beneficial owner" (as defined in Rule 13d-3 under the Exchange Act), directly or indirectly, of securities of the Company representing 20% or more of the combined voting power of the Company's then outstanding securities eligible to vote for the election of the Board (the "Company Voting Securities"); provided, however, that the event described in this Paragraph

1(d)(2) shall not be deemed to be a Change in Control by virtue of any of the following acquisitions:

(A)By the Company or any Subsidiary,

(B)By any employee benefit plan (or related trust) sponsored or maintained by the Company or any Subsidiary,

(C)By any underwriter temporarily holding securities pursuant to an offering of such securities,

(D)Pursuant to a Non-Qualifying Transaction (as defined in paragraph (3)), or

(E)A transaction (other than one described in (3) below) in which Company Voting Securities are acquired from the Company, if a majority of the Incumbent Directors approve a resolution providing expressly that the acquisition pursuant to this clause (E) does not constitute a Change in Control under this Paragraph 1(d)(2); or

(3)The consummation of a merger, consolidation, statutory share exchange or similar form of corporate transaction involving the Company or any of its Subsidiaries (a "Business Combination") or sale or other disposition of all or substantially all of the Company's assets to an entity that is not an affiliate of the Company (a "Sale"), unless immediately following such Business Combination or Sale:

(A)More than 50% of the total voting power of:

(i)The corporation resulting from such Business Combination (the "Surviving Corporation"), or

(ii)If applicable, the ultimate parent corporation that directly or indirectly has beneficial ownership of 100% of the voting securities eligible to elect directors of the Surviving Corporation (the "Parent Corporation"),

is represented by Company Voting Securities that were outstanding immediately prior to such Business Combination (or, if applicable, is represented by shares into which such Company Voting Securities were converted pursuant to such Business Combination), and such voting power among the holders thereof is in substantially the same proportion as the voting power of such Company Voting Securities among the holders thereof immediately prior to the Business Combination,

(B)No person (other than any employee benefit plan (or related trust) sponsored or maintained by the Surviving Corporation or the Parent Corporation), is or becomes the beneficial owner, directly or indirectly, of 20% or more of the total voting power of the outstanding voting securities eligible to elect directors of the Parent Corporation (or, if there is no Parent Corporation, the Surviving Corporation) and

(C)At least a majority of the members of the board of directors of the Parent Corporation (or, if there is no Parent Corporation, the Surviving Corporation) following the consummation of the Business Combination were Incumbent Directors at the time of the Board's approval of the execution of the initial agreement providing for such Business Combination (any Business Combination which satisfies all of the criteria specified in (A), (B) and (C) above shall be deemed to be a "Non-Qualifying Transaction"); or

(4)The stockholders of the Company approve a plan of complete liquidation or dissolution of the Company.

Notwithstanding the foregoing, a Change in Control of the Company shall not be deemed to occur solely because any person acquires beneficial ownership of more than 20% of Company Voting Securities as a result of the acquisition of Company Voting Securities by the Company which reduces the number of Company Voting Securities outstanding; provided, that if after such acquisition by the Company such person becomes the beneficial owner of additional Company Voting Securities that increases the percentage of outstanding Company Voting Securities beneficially owned by such person, a Change in Control of the Company shall then occur.

The Company shall immediately notify the Trustee in writing of any Change in Control. The Trustee may conclusively rely upon such notice and shall have no duty to determine whether a Change in Control has occurred.

(e)"CODE" means the Internal Revenue Code of 1986, as amended, and any regulations issued thereunder. References to any section or subsection of the Code includes reference to any comparable or succeeding provisions of any legislation which amends, supplements or replaces such section or subsection.

(f)"COMPANY" means DTE Energy Company or its successors and assigns.

(g)"ERISA" means the Employee Retirement Income Security Act of 1974, as amended, and any regulations issued thereunder. References to any section or subsection of ERISA include references to any comparable or succeeding provisions of any legislation that amends, supplements or replaces such section or subsection.

(h)"INSOLVENCY" OR "INSOLVENT" means for purposes of this Trust Agreement:

(1)The Company or a Participating Affiliated Company is unable to pay its debts as they become due, or

(2)The Company or a Participating Affiliated Company is subject to a pending proceeding as a debtor under the United States Bankruptcy Code.

(i)"PARTICIPANT" means an employee who has made a written election on a properly executed form to participate in a Plan that requires such an election or has otherwise been properly designated to participate in a Plan.

(j)"PARTICIPATING AFFILIATED COMPANY" means any Affiliated Company who has elected to participate in a Plan that requires such an election; otherwise it means any Affiliated Company.

(k)"PLAN" OR "PLANS" means the plans described in Appendix A.

(l)"SUBSIDIARY" means a corporation, partnership, joint venture, limited liability company, unincorporated association or other entity in which the Company has a direct or indirect ownership or other equity interest.

(m)"TRUST" OR "TRUST AGREEMENT" means the DTE Energy Affiliates Nonqualified Plans Master Trust as described herein and as amended from time to time.

(n)"TRUSTEE" means State Street Bank and Trust Company.

SECTION 2

ESTABLISHMENT AND FUNDING OF TRUST

(a)The Company hereby deposits with the Trustee in trust the total assets of the Trust to be held, administered and disposed of by the Trustee as provided in this Trust Agreement. The Trustee shall establish and maintain a subaccount within this Trust in the name of each Plan and each Participating Affiliated Company participating in such Plan (each a "Participating Affiliated Company Account"), as directed by the Company. Contributions or transfers to this Trust shall be credited to the subaccount of one or more Plans and one or more Participating Affiliated Company Accounts, as directed by the Company. The Company may cause the assets of the subaccounts allocable to the Plans to be commingled for investment purposes, provided that the Company shall be responsible for causing sufficient records to be maintained to insure that benefits and liabilities payable with respect to each Plan shall be paid from the assets allocable to each such Plan.

(b)The Trust hereby established shall be irrevocable.

(c)The Trust is intended to be a grantor trust, of which the Company is the grantor, within the meaning of subpart E, part I, subchapter J, chapter 1, subtitle A of

the Internal Revenue Code of 1986, as amended, and shall be construed accordingly. The Company represents and warrants to the Trustee:

(1)No Plan for which benefits are or may become payable under this Trust is subject to Part 4 of Title I of ERISA;

(2)Each Plan covers, and will cover, only:

(A) A select group of management or highly compensated employees as contemplated by Section 401(a) of ERISA and interpretations, opinions, and rulings of the Department of Labor thereunder or

(B)Participants in an excess benefit plan as defined in Section 3(36) of ERISA; and

(3)The Plans are not qualified under Section 401 of the Code and not subject to any of the Code requirements applicable to tax‑qualified plans.

(d)The principal of the Trust, and any earnings thereon shall be held separate and apart from other funds of the Company and Participating Affiliated Companies and shall be used exclusively for the purposes of paying Plan Participants and their Beneficiaries to the extent any Participant or Beneficiary acquires the right to receive a payment under a Plan and general creditors as herein set forth. Plan Participants and their Beneficiaries shall have no preferred claim on, or any beneficial ownership interest in, any assets of the Trust. Any rights created under a Plan and this Trust Agreement shall be mere unsecured contractual rights of Plan Participants and their Beneficiaries against the Company. Any assets held by the Trustee in any subaccount will be subject to the claims of the Company's general creditors in the event of Insolvency of the Company. Any assets held by the Trustee in a Participating Affiliated Company Account will be subject to the claims of such Participating Affiliated Company's general creditors (but shall not be subject to the claims of any other Participating Affiliated Company's general creditors) under federal and state law in the event of Insolvency.

Upon a Change in Control, the Company shall, as soon as possible, but in no event longer than 7 days following the Change in Control, as defined herein, make an irrevocable contribution to the Trust. Such contribution shall be in an amount such that the resulting balance of the Trust and each Plan's subaccount are sufficient to pay each Plan Participant or Beneficiary the benefits to which Plan Participants or their Beneficiaries would be entitled pursuant to the terms of the Plan, as well as an amount deemed necessary to pay estimated Trust administrative expenses for the following 5 years as determined by the Company's accountants, as of the date on which the Change in Control occurred. The Trustee shall have no duty to enforce any funding obligations of the Company or to determine or collect contributions under the Plans and shall have no responsibility for any property until it is received and accepted by the

Trustee. Notwithstanding the preceding, in no event shall the transfer the Company is required to make hereunder upon or following a Change in Control be less than the transfer the Company would have been required to make under the terms of the Plans as in effect immediately prior to the Change in Control. The Company shall have the sole duty and responsibility, both before and after a Change of Control, for the determination of the accuracy or sufficiency of the contributions to be made under the Plans.

The duties of the Trustee shall be governed solely by the terms of this Trust Agreement without reference to the terms of the Plan, and the Trustee shall have no duties other than those specifically set forth in this Trust Agreement.

SECTION 3

PAYMENTS TO PLAN PARTICIPANTS AND THEIR BENEFICIARIES

(a)The Company shall deliver to the Trustee a schedule (the "Payment Schedule") that indicates:

(1)Either:

(A)The amounts payable with respect to each Plan Participant (and his or her Beneficiaries); or

(B)A formula or other instructions acceptable to the Trustee for determining the amounts so payable;

(2)The form in which such amount is to be paid (as provided for or available under the applicable Plan), and

(3)The time of commencement for payment of such amounts.

Except as otherwise provided herein, the Trustee shall make payments to the Plan Participants and their Beneficiaries in accordance with the Payment Schedule. The Company shall be responsible for notifying the Trustee of any change in the information on the Payment Schedule. Except as otherwise provided herein, the Trustee shall make payments to the Participants and their Beneficiaries in accordance with the Payment Schedule; provided, however, that, except as provided in Section 14 and with respect to the payment of the Trustee's expenses:

(1)Amounts credited to a Plan's subaccount under this Trust may only be used to pay benefits to Participants and Beneficiaries of such Plan; and

(2)Amounts credited to a Participating Affiliated Company Account may only be used to pay benefits to Participants and Beneficiaries who are entitled to a benefit from such Participating Affiliated Company.

It is the intent of the Company and the Trustee that the Company shall be responsible for determining and effecting all federal, state and local tax aspects of the Plan and the Trust Fund, including without limitation income taxes payable on the Trust Fund's income, if any, and required withholding of income or other payroll taxes in connection with the payment of benefits from the Trust Fund pursuant to the Plan, and all reporting required in connection with any such taxes. To the extent that the Company is required by applicable law to pay or withhold such taxes or to file such reports, such obligations shall be a responsibility allocated to the Company hereunder. To the extent the Trustee is required by applicable law to pay or withhold such taxes or to file such reports, the Company shall inform the Trustee of such obligation, shall direct the Trustee with respect to the performance of such obligations, and shall provide the Trustee with all information required by the Trustee to meet such obligations. Notwithstanding the foregoing, the Company may elect to pay any applicable taxes directly. In the event the Company pays taxes directly, such amounts may be reimbursed from the Trust assets by the Trustee, provided that the Company certifies the amount of taxes paid directly and instructs the Trustee to remit a reimbursement of such taxes to the Company. In addition, the Trustee shall provide the Company with all information required to enable the Company to pay any taxes on the Trust's income on a timely basis.

(b)The entitlement of a Plan Participant or his or her Beneficiaries to benefits under a Plan shall be determined by the Company or such party as it shall designate under the Plan, and any claim for such benefits shall be considered and reviewed under the procedures set out in the Plan. The Company shall notify the Trustee of such determination and shall direct commencement of payments of such benefits.

(c)The Company or the applicable Participating Affiliated Company may make payment of benefits directly to Plan Participants or their Beneficiaries as they become due under the terms of a Plan. The Company shall notify the Trustee of any decision to make payment of benefits directly prior to the time amounts are payable to Participants or their Beneficiaries. In addition, if the principal of the Trust, and any earnings thereon, are not sufficient to make payments of benefits in accordance with the terms of the Plan, the Company or the applicable Participating Affiliated Company shall make the balance of each such payment to the Participant or Beneficiary as it falls due. The Trustee shall notify the Company where principal and earnings are not sufficient to make a payment then due under the Payment Schedule.

SECTION 4

TRUSTEE RESPONSIBILITY REGARDING PAYMENTS TO TRUST BENEFICIARY WHEN COMPANY IS INSOLVENT

(a)The Trustee shall cease payment of benefits to Plan Participants and their Beneficiaries if the Company is Insolvent, subject to the provisions of Subsection 4(b) below. The Trustee shall cease payment of benefits to Plan Participants and their Beneficiaries on behalf of a Participating Affiliated Company if that Participating Affiliated Company is Insolvent, subject to the provisions of Subsection 4(b) below.

(b)At all times during the continuance of this Trust, as provided in Subsection 2(d) hereof, the principal and income of the Trust shall be subject to claims of general creditors of the Company under federal and state law as set forth below, and the principal and income allocable to each Participating Affiliated Company's Subaccount shall be subject to claims of general creditors of that Participating Affiliated Company, under federal and state law as set forth below, for whose benefit such subaccount was established.

(1)The Board of Directors and the Chief Executive Officer ("CEO") of the Company shall have the duty to inform the Trustee in writing of the Insolvency of the Company or a Participating Affiliated Company. If a person claiming to be a creditor of the Company or a Participating Affiliated Company alleges in writing to the Trustee that the Company or a Participating Affiliated Company has become Insolvent, the Trustee shall determine whether the Company or the Participating Affiliated Company is Insolvent and, pending such determination, the Trustee in the case of the insolvency of the Company, shall discontinue payment of benefits to Plan Participants or their Beneficiaries and; in the case of the Insolvency of a Participating Affiliated Company, shall discontinue payment of benefits to Plan participants who would otherwise be entitled to a benefit payable from the subaccount of such Participating Affiliate Company. In all cases, the Trustee shall be entitled to conclusively rely upon the written certification of the Board of Directors or the CEO of the Company when determining whether the Company or a Participating Affiliated Company is Insolvent.

(2)Unless the Trustee has actual knowledge of the Insolvency of the Company or a Participating Affiliated Company, or has received notice from the Company or a person claiming to be a creditor alleging that the Company or a Participating Affiliated Company is Insolvent, the Trustee shall have no duty to inquire whether the Company or a Participating Affiliated Company is Insolvent. The Trustee may in all events rely on such evidence concerning the solvency of the Company or a Participating Affiliated Company, as may be furnished to the Trustee and that provides the Trustee with a reasonable basis for making a determination concerning the solvency of the Company or a Participating Affiliated Company. In no event shall "actual knowledge" be deemed to include knowledge of the credit status of the Company or a Participating Affiliated Company, held by banking officers or banking employees of State Street Bank and Trust Company which has not been communicated to the trust department of the Trustee. The Trustee may appoint an independent accounting, consulting or law firm to make any determination of solvency required by the Trustee under this Section 4 only in cases where:

(A)The Trustee is required to make an inquiry as to the solvency of the Company or a Participating Affiliated Company, (because a creditor has alleged Insolvency) and

(B)The Company disputes that the Company or a Participating Affiliated Company is Insolvent.

In such event, the Trustee may conclusively rely upon the determination by such firm and shall be responsible only for the prudent selection of such firm.

(3)If at any time the Board of Directors or the CEO of the Company notifies the Trustee or the Trustee has determined that the Company is Insolvent, the Trustee shall discontinue payments to Plan Participants or their Beneficiaries in accordance with Subsection 4(a) and shall hold the assets of the Trust for the benefit of the general creditors of the Company, except that, to the extent permitted by applicable law, the Trustee's fees and expenses may continue to be paid pursuant to Section 11 hereof. If at any time the Board of Directors or the CEO of the Company notifies the Trustee or the Trustee has determined that a Participating Affiliated Company is Insolvent, the Trustee shall discontinue payments to all Plan Participants and their Beneficiaries and the Trustee is hereby directed by the Company (without the need for further direction from the Company or any Participating Affiliated Company at the time of such Insolvency) to segregate into the applicable Participating Affiliated Company's subaccount such Participating Affiliated Company's pro rata portion of each type of asset held by the Trust (on a security by security basis). Upon such segregation, such assets in the Insolvent Participating Affiliated Company's subaccount shall no longer be commingled with the remaining assets of the Trust for investment purposes, and the Trustee shall hold such segregated assets allocable to such Insolvent Participating Affiliated Company for the benefit of the general creditors of such Insolvent Participating Affiliated Company, except that, to the extent permitted by applicable law, the Trustee's fees and expenses may continue to be paid pursuant to Section 11 hereof. Upon such segregation, the Trustee shall resume payments to Plan Participants and Beneficiaries, in accordance with Section 3 of this Trust Agreement, who are entitled to benefits from other than the Insolvent Participating Affiliated Company's subaccount. Nothing in this Trust Agreement shall in any way diminish any rights of Plan Participants or their Beneficiaries to pursue their rights as general creditors of the Company or a Participating Affiliated Company with respect to benefits due under the Plan(s) or otherwise.

(4)In the case of an Insolvency of the Company, the Trustee shall resume the payment of benefits to Plan Participants or their Beneficiaries in accordance with Section 3 of this Trust Agreement only after the Trustee has determined that the Company is not Insolvent (or is no longer Insolvent) or pursuant to an order from the U.S. Bankruptcy Court or other court of competent jurisdiction. In the case of an Insolvency of a Participating Affiliated Company, the Trustee shall resume the payment of benefits to the Plan Participants and Beneficiaries from such subaccount of such Participating Affiliated Company in accordance with Section 3 of this Agreement, and such subaccount may be

commingled with other such Trust Fund assets, only after the Trustee has determined that the Participating Affiliated Company is not Insolvent (or is no longer Insolvent) or pursuant to an order of the U.S. Bankruptcy Court or other Court of competent jurisdiction.

(c)Provided that there are sufficient assets, if the Trustee discontinues the payment of benefits from the Trust pursuant to Subsection 4(b) hereof and subsequently resumes such payments, the first payment following such discontinuance, to the extent not inconsistent with an order from the U.S. Bankruptcy Court or other court of competent jurisdiction, shall include the aggregate amount of all payments due to Plan Participants or their Beneficiaries under the terms of the Plan(s) for the period of such discontinuance, less the aggregate amount of any payments made to Plan Participants or their Beneficiaries by the Company in lieu of the payments provided for here under during any such period of discontinuance, all in accordance with the Payment Schedule, which shall be modified by the Company as necessary to comply with the provisions of this Subsection 4(c).

SECTION 5

PAYMENTS TO COMPANY

The Company shall have no right or power to direct the Trustee to return to the Company (or any Participating Affiliated Company) or to divert to others any of the Trust assets before all payments of benefits have been made to Plan Participants and their Beneficiaries pursuant to the terms of the Plan(s). The Trustee shall be entitled to rely conclusively upon the Company’s written certification that all such payments have been made.

SECTION 6

INVESTMENT AND ADMINISTRATIVE

(a)Prior to a Change of Control, the Company shall establish and maintain written investment guidelines ("Investment Guidelines"), which may be used from time to time for the investment of the assets in the Trust. The Company may appoint and remove one or more investment managers from time to time to manage specified portions of the Trust; provided, however, that the Company may also manage all or a portion of the Trust. To the extent that assets of the Trust are not so managed by an investment manager appointed by the Company, the Company shall manage all such assets. The Company and each investment manager shall designate in writing the persons who are authorized to represent such party in dealing with the Trustee. The Trustee shall have no investment duties for the Trust. The Trustee shall have no duty to inquire whether investment directions received from the Company or an investment manager are in accordance with the Plans or the Investment Guidelines, or to review the assets purchased, retained or sold. The Trustee shall be fully indemnified by the Company for any action taken in accordance with, or any failure to act in the absence of, the Company's or an investment manager's directions.

(b)The Company shall have the right, at anytime, and from time to time in its sole discretion, to substitute assets of equal fair market value for any asset held by the Trust; the Trustee shall have no responsibility for determining whether such right has been properly exercised or for any investment losses that may result from its exercise.

(c)After a Change of Control, the Trustee shall have and exercise sole investment discretion with respect to the Trust in accordance with the Investment Guidelines in effect immediately prior to the Change of Control, a copy of which shall be provided to the Trustee by the Company. The Trustee's sole responsibility with respect to investment discretion shall be to exercise such discretion in accordance with the Investment Guidelines. The Investment Guidelines may be changed from time to time by mutual agreement of the Trustee and the Company. The Trustee may, in its sole discretion, appoint, retain or terminate an investment manager (including any affiliate of the Trustee) to manage all or a portion of the Trust in accordance with the current Investment Guidelines and shall pay their reasonable compensation from the Trust assets.

(d)If directed by the Company or any investment manager before a Change of Control, or in the Trustee’s discretion after a Change of Control, the Trustee may collect and receive any and all money and other property due the Trust and give full discharge therefor.

(e)If directed by the Company or any investment manager before a Change of Control, or in the Trustee’s discretion after a Change of Control, the Trustee may settle, compromise or submit to arbitration any claims, debt or damages due or owing to or from the Trust; the Trustee may also commence or defend suits or legal proceedings to protect any interest of the Trust, and may represent the Trust in all suits or legal proceedings in any court or before any other body or tribunal.

(f)If directed by the Company or any investment manager before a Change of Control, or in the Trustee’s discretion after a Change of Control, the Trustee may take all action necessary to pay for authorized transactions, including the borrowing or raising monies from any lender, including the Trustee, in its corporate capacity in conjunction with its duties under this Agreement and upon such terms and conditions as the Trustee may deem advisable to settle security purchases and/or foreign exchange or contracts for foreign exchange, and securing the repayments thereof by pledging all or any part of the Trust.

(g)The Trustee may appoint custodians, subcustodians or subtrustees, domestic or foreign (including affiliates of the Trustee), as to part or all of the Trust. The Trustee shall not be responsible or liable for any losses or damages suffered by the Company arising as a result of the insolvency of any custodian, subcustodian or subtrustee, except to the extent the Trustee was negligent in its selection or continued retention of such custodian, subcustodian or subtrustee. In no event shall the Trustee be liable for the acts or omissions of any custodian, subcustodian or subtrustee appointed pursuant to the direction of the Company or an investment manager.

(h)The Trustee may hold property in nominee name, in bearer form, or in book entry form, in a clearinghouse corporation or in a depository (including an affiliate of the Trustee), so long as the Trustee's records clearly indicate that the assets held are a part of the Trust. The Trustee shall not be responsible for any losses resulting from the deposit or maintenance of securities or other property (in accordance with market practice, custom, or regulation) with any recognized foreign or domestic clearing facility, book entry system, centralized depository, or similar organization.

SECTION 7

CONTRACTUAL SETTLEMENT AND INCOME; MARKET PRACTICE SETTLEMENTS

(a)In accordance with the Trustee's standard operating procedure, the Trustee shall credit the Trust with income and maturity proceeds on securities on contractual payment date net of any taxes or upon actual receipt. To the extent the Trustee credits income on contractual payment date, the Trustee may reverse such accounting entries to the contractual payment date if the Trustee reasonably believes that such amount will not be received.

(b)In accordance with the Trustee's standard operating procedure, the Trustee will attend to the settlement of securities transactions on the basis of either contractual settlement date accounting or actual settlement date accounting. To the extent the Trustee settles certain securities transactions on the basis of contractual settlement date accounting, the Trustee may reverse to the contractual settlement date any entry relating to such contractual settlement if the Trustee reasonably believes that such amount will not be received.To the extent the Trustee advances funds to the Trust for disbursements or to effect the settlement of purchase transaction, the Trustee shall be entitled to collect from the Trust an overdraft fee as set forth in the fee schedule agreed between the parties.

(c)Settlements of transactions may be effected in trading and processing practices customary in the jurisdiction or market where the transaction occurs. The Company acknowledges that this may, in certain circumstances, require the delivery of cash or securities (or other property) without the concurrent receipt of securities (or other property) or cash. In such circumstances, the Trustee shall have no responsibility for nonreceipt of payment (or late payment) or nondelivery of securities or other property (or late delivery) by the counterparty unless the nonreceipt of payment (or late payment) or nondelivery of securities or other property (or late delivery) is due to the Trustee's negligence or willful misconduct.

SECTION 8

DISPOSITION OF INCOME

During the term of this Trust, all income received by the Trust, net of expenses and taxes, shall be accumulated and reinvested.

SECTION 9

ACCOUNTING BY TRUSTEE

(a)The Trustee shall keep accurate and detailed records of all investments, receipts, disbursements, and all other transactions required to be made, including such specific records as shall be agreed upon in writing between the Company and the Trustee. The records shall include separate subaccounts established and maintained for each Plan and for each Participating Affiliated Company Account within each Plan. The assets of a subaccount allocable to a Plan shall not be used to satisfy the liabilities with respect to Plan Participants or Beneficiaries of another Plan.

(b)The Company shall keep full, accurate and detailed records with respect to the Participants and benefits paid and payable under the Plan, which records shall be made available to the Trustee at its request.

(c)Within 60 days following the close of each calendar year and within 90 days after the removal or resignation of the Trustee, the Trustee shall deliver to the Company a written account of its administration of the Trust during such year or during the period from the close of the last preceding year to the date of such removal or resignation, setting forth all investments, receipts, disbursements and other transactions effected by it, including a description of all securities and investments purchased and sold with the cost or net proceeds of such purchases or sales (accrued interest paid or receivable being shown separately), and showing all cash, securities and other property held in the Trust at the end of such year or as of the date of such removal or resignation, as the case may be. In the absence of the filing in writing with the Trustee by the Company of exceptions or objections to any such account within 90 days, the Company shall be deemed to have approved such account; in such case, or upon the written approval by the Company of any such account, the Trustee shall be released, relieved and discharged with respect to all matters and things set forth in such account as though such account had been settled by the decree of a court of competent jurisdiction. The Trustee may conclusively rely on determinations of the Company of valuations for assets of the Trust for which the Trustee deems there to be no readily determinable fair market value and on determinations of the issuing insurance company of valuations for insurance contracts/policies.

SECTION 10

RESPONSIBILITY OF TRUSTEE

(a)The Trustee shall act with the care, skill, prudence and diligence under the circumstances then prevailing that a prudent person acting in like capacity and familiar with such matters would use in the conduct of an enterprise of a like character and with like aims, provided, however, that the Trustee shall incur no liability to any person for any action taken pursuant to a direction, request or approval given in writing by the Company or any investment manager appointed by the Company. In the event of a dispute between the Company or any Participating Affiliated Company and a party, the

Trustee may apply to a court of competent jurisdiction to resolve the dispute that is contemplated by and in conformity with the terms of the Plans or this Trust.

(b)The Trustee is not a party to and has no duties or responsibilities under the Plans, and has not duties or responsibilities other than those that are expressly contained in this Trust Agreement. Except as provided in Subsection 2(d) of this Trust Agreement relating to the Company’s contribution obligation on a Change in Control, in any case in which a provision of this Trust Agreement conflicts with any provision in any Plan, this Trust Agreement shall control.

(c)The Trustee shall not be responsible for the title, validity or genuineness of any property or evidence of title hereto received by it or delivered by it pursuant to this Trust Agreement and shall be held harmless in acting upon any notice, request, direction, instruction, consent, certification or other instrument reasonably believed by it to be genuine and delivered by the proper party or parties.

(d)The Company agrees to indemnify and hold harmless, to the extent not prohibited by law, the Trustee and its Nominee from and against all liability, loss and expense, including reasonable attorneys’ fees and expenses, incurred by the Trustee or any of the foregoing indemnitees arising out of or in connection with this Trust Agreement, except as a result of the Trustee’s own negligence, willful misconduct, or breach of the Trustee’s duties under this Trust Agreement. The Trustee shall be fully indemnified by the Company for any action taken in accordance with or any failure to act in the absence of the Company’s or investment manager’s written direction.

The Trustee agrees to use reasonable efforts to rectify any errors caused by its or any of the Trustee’s agents’ negligence, breach of fiduciary duty, or willful misconduct including, without limitation making financial contributions to the Trust. Nothing in this Trust Agreement shall in any way constitute a waiver or limitation of any rights that the Company may have under applicable law, including, without limitation, Federal and State securities laws.

This Subsection 10(d) shall survive termination of this Agreement.

(e)The Trustee may consult with legal counsel (who may be counsel for the Company generally) with respect to any of its duties or obligations hereunder and, as a part of its reimbursable expenses under this Agreement, pay counsel’s reasonable compensation and expenses. The Trustee shall be entitled to rely on and may act upon advice of counsel on all matters, and shall be without liability for any action reasonably taken or omitted pursuant to such advice.

(f)The Trustee may, in the Trustee’s reasonable judgment, hire agents, accountants, actuaries, investment advisors, financial consultants, or other professionals to assist it in performing any of its duties or obligations hereunder, and such professionals’ reasonable compensation shall be part of the Trustee’s reimbursable expenses under this Trust Agreement.

(g)The Trustee shall have, without exclusion, all powers conferred on trustees by applicable law, unless expressly provided otherwise in this Agreement. However, if an insurance policy is held as an asset of the Trust, the Trustee shall have no power to name a beneficiary of the policy other than the Trust, to assign the policy (as distinct from conversion of the policy to a different form) other than to a successor trustee, or to loan to any person the proceeds of any borrowing against such policy and shall act with respect to any such policy only as directed by the Company.

(h)However, notwithstanding the provisions of Subsection 10(g) above, where directed by the Company, the Trustee may loan to the Company the proceeds of any borrowing against an insurance policy held as an asset of the Trust.

(i)Notwithstanding any powers granted to the Trustee pursuant to this Trust Agreement or to applicable law, the Trustee shall not have any power that could give this Trust the objective of carrying on a business and dividing the gains therefrom, within the meaning of section 301.7701-2 of the Procedure and Administrative Regulations promulgated pursuant to the Internal Revenue Code.

(j)Notwithstanding anything in this Agreement to the contrary contained herein, if a Force Majeure Event occurs, the Trustee will be excused from performing any one or more obligations under this Trust Agreement but only if the Trustee complies with this Subsection 10(j). For purposes of this Agreement, “Force Majeure Event” means any event or circumstance beyond the control of the Trustee, regardless of whether it was foreseeable, that could not be avoided by the Trustee’s exercise of due care and that prevents the Trustee from performing any of its obligations under this Agreement, except that a Force Majeure Event will not include the Trustee’s financial hardship or a change of law. The Trustee shall promptly notify the Company of the occurrence and nature of a Force Majeure Event, its effect on the Trustee’s performance, and how long the Trustee expects the Force Majeure Event to last and the Trustee’s resulting inability to perform its obligations under this Agreement. Thereafter the Trustee shall update that information as reasonably necessary. During a Force Majeure Event, the Trustee shall use reasonable efforts to limit damages to the Company, the Participating Affiliated Companies, Plan Participants and Plan Beneficiaries and to resume its performance under this Agreement as soon as possible. This Section shall survive the termination of this Agreement.

(k)The Trustee shall not be liable for any act of omission of any other person not selected or retained by the Trustee in the exercise of its sole discretion in carrying out any responsibility imposed upon such person. Under no circumstances shall the Trustee be liable for any indirect, consequential, or special damages with respect to its role as the Trustee.

(l)If the Company either contributes or directs the Trustee to invest the Trust Fund in securities or other obligations of the Company, then the Trustee shall have no fiduciary or other liability for decisions to purchase or hold such investments. Also, the

Company shall direct the Trustee as to the voting of any Company stock held in the Trust. The Company shall indemnify the Trustee for any liabilities that arise on account of such contributions or investments. This Section shall survive the termination of this Agreement.

SECTION 11

COMPENSATION AND EXPENSES OF TRUSTEE

The Company shall pay all reasonable administrative expenses and the Trustee's fees and reasonable expenses. If not so paid, the fees and expenses shall be paid from the Trust. The Trustee shall be entitled to fees for services as mutually agreed. The Company acknowledges that as part of the Trustee's compensation, the Trustee may earn interest on cash balances including disbursement balances and balances arising from purchase and sale transactions. If the Trustee advances cash or securities to the Trust for any purpose, or in the event that the Trustee shall incur or be assessed taxes, interest, charges, or assessments, in connection with the performance of this Agreement, except such as may arise from its own negligent failure to act or willful misconduct, any property at any time held in the Trust shall be security therefor and the Trustee shall be entitled to collect from the Trust sufficient cash for reimbursement, and if such cash is insufficient, dispose of the assets of the Trust to the extent necessary to obtain reimbursement. To the extent the Trustee advances funds to the Trust for disbursements or to effect the settlement of purchase transactions, the Trustee shall be entitled to collect from the Trust an overdraft fee as set forth in the fee schedule agreed between the parties.

SECTION 12

RESIGNATION AND REMOVAL OF TRUSTEE

(a)The Trustee may resign at any time by written notice to the Company, which shall be effective as of the later of:

(1)30 days after receipt of such notice, or

(2)The date of the transfer of Trust assets to a successor Trustee, unless the Company and the Trustee agree otherwise.

The Company may remove the Trustee on 30 days notice or such shorter notice accepted by the Trustee.

(b)Upon resignation or removal of the Trustee and appointment of a successor Trustee, all assets shall subsequently be transferred to the successor Trustee. The resigning or removed Trustee is authorized, however, to reserve such amount as may be necessary for the payment of its fees and expenses incurred prior to resignation or removal. The transfer shall be completed within 30 days after receipt of notice of resignation, removal or transfer, unless the Company extends the time limit.

The Company's consent to extension of such time limit shall not be unreasonably withheld.

(c)If the Trustee resigns or is removed, a successor shall be appointed in accordance with Section 13 hereof, by the effective date of resignation or removal under paragraph (a) of this section. If no such appointment has been made within 60 days after the notice of such resignation or removal, the Trustee may apply to a court of competent jurisdiction for appointment of a successor or for instructions. All expenses of the Trustee in connection with the proceeding shall be allowed as administrative expenses of the Trust.

SECTION 13

APPOINTMENT OF SUCCESSOR

(a)If the Trustee resigns (or is removed) in accordance with Subsection 12(a) hereof, the Company may appoint any third party, such as a bank trust department, that may validly exercise corporate trustee powers under state law, as a successor to replace the Trustee upon resignation or removal. The appointment shall be effective when accepted in writing by the new Trustee, who shall have all of the rights and powers of the former Trustee, including ownership rights in the Trust assets. The former Trustee shall execute any instrument necessary or reasonably requested by the Company or the successor Trustee to evidence the transfer.

(b)The successor Trustee need not examine the records and acts of any prior Trustee and may retain or dispose of existing Trust assets, subject to the terms hereof. The successor Trustee shall not be responsible for and the Company shall indemnify and defend the successor Trustee from any claim or liability resulting from any action or inaction of any prior Trustee or from any other past event, or any condition existing at the time it becomes successor Trustee.

SECTION 14

AMENDMENT OR TERMINATION

(a)This Trust Agreement may be amended by a written instrument executed by the Trustee and the Company. Notwithstanding the foregoing, no such amendment shall conflict with the terms of a Plan, as certified to in writing by the Company (upon which certification the Trustee may conclusively rely), or make the Trust revocable.

(b)The Trust shall not terminate until the date on which the Plan Participants and their Beneficiaries are no longer entitled to benefits pursuant to the terms of the Plan, as certified to in writing by the Company (upon which certification the Trustee may conclusively rely). Upon termination of the Trust any assets remaining in the Trust shall be returned to the Company, Subsection 2(b) notwithstanding. The preceding sentences to the contrary notwithstanding, this Trust may terminate with respect to a Plan (and the subaccount maintained with respect to that Plan) if that Plan's Participants and Beneficiaries are no longer entitled to benefits pursuant to the terms of that Plan, as

certified in writing by the Company (upon which certification the Trustee may conclusively rely), in which case any assets remaining in that Plan's subaccount shall be reallocated to the subaccount of one or more of the remaining Plans and the applicable Participating Affiliated Company Account as directed by the Company.

(c)Upon written approval of Participants or Beneficiaries entitled to payment of benefits pursuant to the terms of the Plan, the Company may terminate this Trust prior to the time all benefit payments under the Plan have been made. Such approval shall be obtained and certified to in writing by the Company (upon which certification the Trustee may conclusively rely), and the Trustee shall have no responsibility therefor. All assets in the Trust at termination shall be returned to the Company, Subsection 2(b) notwithstanding.

SECTION 15

MISCELLANEOUS

(a)Neither the Company nor the Trustee may assign this Trust Agreement without the prior written consent of the other, except that the Trustee may assign its rights and delegate its duties hereunder to any corporation or entity which directly or indirectly is controlled by, or is under common control with, the Trustee. This Trust Agreement shall be binding upon, and inure to the benefit of, the Company and the Trustee and their respective successors and permitted assigns. Any entity which shall by merger, consolidation, purchase, or otherwise, succeed to substantially the trust business of the Trustee shall, upon such succession and without any appointment or other action by the Company, be and become successor trustee hereunder, upon notification to the Company.

(b)If any provision of this Trust Agreement is held by a court of competent jurisdiction to be invalid or unenforceable, this Trust Agreement will continue as if the provision was modified, to the minimum extent necessary, to make the provision valid and enforceable and to accomplish the original reasonable objectives of the Company and the Trustee for entering into this Trust Agreement.

(c)Benefits payable to Plan Participants and their Beneficiaries under this Trust Agreement may not be anticipated, assigned (either at law or in equity), alienated, pledged, encumbered or subjected to attachment, garnishment, levy, execution, or other legal or equitable process.

(d)Notwithstanding anything to the contrary contained elsewhere in this Trust Agreement, any reference to the Plans or to Plan provisions which require knowledge or interpretation of the Plans shall impose a duty upon the Company to communicate such knowledge or interpretation to the Trustee. The Trustee shall have no obligation to know or interpret any portion of any Plan and shall in no way be liable for any proper action taken contrary to any Plan.

(e)This Trust Agreement shall be governed by and construed in accordance with the laws of the Commonwealth of Massachusetts. The parties hereby expressly waive, to the full extent permitted by applicable law, any right to trial by jury with respect to any judicial proceeding arising from or related to this Agreement.

(f)Any action required to be taken by the Company shall be by resolution of its Board of Directors or by written direction of one or more of its president, any vice president or treasurer or anyone designated by such person to act on behalf of the Company under this Trust Agreement. The Trustee may rely upon a resolution or direction filed with the Trustee that is contemplated by and in conformity with the terms of the Plans or this Trust and shall have no responsibility for any action taken by the Trustee in accordance with any such resolution or direction.

(g)In making payments to service providers pursuant to authorized directions, the Company acknowledges that the Trustee is acting as paying agent and not as the payor, for tax information reporting and withholding purposes.

(h)Notices and other writings shall be delivered or mailed postage prepaid to:

To the Trustee:

State Street Bank and Trust Company

2 Avenue de Lafayette, LCC2

Boston, MA 02111

ATTN: DTE Relationship Manager

To the Company:

DTE Trust Investments

One Energy Plaza

Suite: WCB 852

Detroit, MI 48226

or to such other address as the Trustee or the Administrator may hereafter specify in writing.

Facsimile notices shall be sufficient if communicated to the party entitled to receive such notice at the following numbers:

If to Trustee:

Facsimile: (617) 769-6902

If to Company:

Facsimile: (313) 235-0160

or to such other numbers as either party may furnish the other party by written notice under this Section.

Electronic notices shall also be sufficient if communicated to the party entitled to receive such notice at the following email address:

If to Trustee:

Email address: steven.lichty@statestreet.com

If to Company:

Email address: cavazosp@dteenergy.com

or to such other email addresses as either party may furnish the other party by written notice under this Section. For purposes of the foregoing, electronic notices shall be deemed to include notice given via mystatestreet.com.

(i)Each of the Company and the Trustee hereby represents and warrants to the other that it has full authority to enter into this Agreement upon the Agreement’s terms and conditions and that the individual executing this Agreement on its behalf has the requisite authority to bind it to this Agreement.

(j)The Company and the Trustee agree that each shall treat confidentially all information provided by each party to the other party in connection with the services provided under this Agreement.  All confidential information provided by a party hereto shall be used by any other party hereto solely for the purpose of rendering or receiving services pursuant to this Agreement and, except as may be required in carrying out this Agreement, shall not be disclosed to any third party.  The foregoing shall not be applicable to any information:

(1)That is publicly available when provided or thereafter becomes publicly available, other than through a breach of this Agreement, or that is independently derived by any party hereto without the use of any information provided by the other party hereto in connection with this Agreement,

(2)That is required in any legal or regulatory proceeding, investigation, audit, examination, subpoena, civil investigative demand or other similar process, or by operation of law or regulation, or

(3)Where the party seeking to disclose has received the prior written consent of the party providing the information, which consent shall not be unreasonably withheld. 

Notwithstanding anything herein to the contrary, the Trustee, its subsidiaries and affiliates may report and use nonpublic portfolio holdings information of its clients on an aggregated basis with all or substantially all other client information and without specific reference to the Company.

(k)The Trustee will implement and maintain a written information security program that contains appropriate security measures to safeguard the personal information of the Company’s or the Trust’s beneficiaries, unit holders, shareholders, employees, directors and/or officers that it receives, stores, maintains, processes or otherwise accesses in connection with the provision of services hereunder. For these purposes, “personal information” means:

(1)An individual’s name (first initial and last name or first name and last name), address or telephone number plus:

(A)Social security number,

(B)Drivers license number,

(C)State identification card number,

(D)Debit or credit card number,

(E)Financial account number or

(F)Personal identification number or password that would permit access to a person’s account or

(2)Any combination of the foregoing that would allow a person to log onto or access an individual’s account.

Notwithstanding the foregoing “personal information” shall not include information that is lawfully obtained from publicly available information, or from federal, state or local government records lawfully made available to the general public.

(l)This Agreement may be executed in any number of counterparts, each of which shall be deemed to be an original, but all of which shall together constitute only one Agreement.

(m)The Company hereby represents and warrants that it does not engage in an “internet gambling business,” as such term is defined in Section 233.2(r) of Federal Reserve Regulation GG (12 CFR 233.1-233.7) (“Regulation GG”). The Company hereby covenants and agrees that it shall not engage in an internet gambling business. In accordance with Regulation GG, the Company is hereby notified that “restricted transactions,” as such term is defined in Section 233.2(y) of Regulation GG, are prohibited in any dealings with the Trustee pursuant to this Agreement or otherwise between or among any party hereto.

(Signatures Next Page)

DTE ENERGY COMPANY

By:/s/Paul B. Cavazos

Name:Paul B. Cavazos

Title:Solely in his capacity as Assistant Treasurer

Date:8/15/13

STATE STREET BANK AND TRUST COMPANY

By:/s/Steven Lichty

Name:Steven Lichty

Title:Vice President

Date:8/15/13

APPENDIX A

NON-QUALIFIED DEFERRED COMPENSATION PLANS

DTE Energy Company Executive Supplemental Retirement Plan, as amended and restated effective January 1, 2005

DTE Energy Company Supplemental Retirement Plan, as amended and restated effective January 1, 2005

DTE Energy Company Supplement Savings Plan, as amended and restated effective January 1, 2005

DTE Energy Company Executive Deferred Compensation Plan, as amended and restated effective January 1, 2005

EX-12.55

Exhibit 12-55

DTE Energy Company
Computation of Ratio of Earnings to Fixed Charges
	Nine Months Ended			Twelve Months Ended December 31
(Millions of Dollars)	September 30, 2013			2012			2011		2010		2009		2008
Earnings:
Pretax earnings	$	753		$	1,035		$	989	$	968	$	778	$	518
Adjustments	(10		)	(4		)	6		1		4		(3		)
Fixed Charges	346			463			520		567		572		540
Net earnings	$	1,089		$	1,494		$	1,515	$	1,536	$	1,354	$	1,055
Fixed Charges:
Interest expense	$	323		$	441		$	490	$	543	$	545	$	503
Adjustments	23			22			30		24		27		37
Fixed Charges	$	346		$	463		$	520	$	567	$	572	$	540
Ratio of earnings to fixed charges	3.15			3.23			2.91		2.71		2.37		1.95

EX-31.85

Exhibit 31-85

FORM 10-Q CERTIFICATION

I, Gerard M. Anderson, certify that:

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

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

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

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

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

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

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

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

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

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

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

/S/ GERARD M. ANDERSON	Date:	October 25, 2013
Gerard M. Anderson Chairman of the Board, President and Chief Executive Officer of DTE Energy Company

EX-31.86

Exhibit 31-86

FORM 10-Q CERTIFICATION

I, David E. Meador, certify that:

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

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

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

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

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

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

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

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

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

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

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

/S/ DAVID E. MEADOR	Date:	October 25, 2013
David E. Meador Executive Vice President and Chief Financial Officer of DTE Energy Company

EX-32.85

Exhibit 32-85

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of DTE Energy Company (the “Company”) for the quarter ended September 30, 2013, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Gerard M. Anderson, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge and belief:

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

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

Date:	October 25, 2013	/S/ GERARD M. ANDERSON
		Gerard M. Anderson Chairman of the Board, President and Chief Executive Officer of DTE Energy Company

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

EX-32.86

Exhibit 32-86

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of DTE Energy Company (the “Company”) for the quarter ended September 30, 2013, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, David E. Meador, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge and belief:

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

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

Date:	October 25, 2013	/S/ DAVID E. MEADOR
		David E. Meador Executive Vice President and Chief Financial Officer of DTE Energy Company

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

XML

Stock-Based Compensation (Details Textuals) (USD $) In Millions, except Share data, unless otherwise specified	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
Share-based Compensation [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercisable, Weighted Average Remaining Contractual Term	4 years 2 months 2 days
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Exercisable, Number	200,844
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period, Total Intrinsic Value	$ 11	$ 21
Stock or Unit Option Plan Expense	0	0.5
Unrecognized Compensation Cost	$ 72
Weighted Average to be Recognized	1 year 2 months 6 days

XML

Segment Information (Details 1) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income (Loss) Attributable to Parent	$ 198	$ 227	$ 537	$ 529
Electric [Member]
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income (Loss) Attributable to Parent	179	194	383	417
Gas [Member]
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income (Loss) Attributable to Parent	(13)	4	91	60
Gas Storage and Pipelines [Member]
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income (Loss) Attributable to Parent	16	14	49	48
Power and Industrial Projects [Member]
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income (Loss) Attributable to Parent	27	22	46	40
Energy Trading [Member]
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income (Loss) Attributable to Parent	(6)	1	(1)	3
Corporate and Other [Member]
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income (Loss) Attributable to Parent	(5)	(9)	(31)	(39)
Discontinued Operations [Member]
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items]
Net Income (Loss) Attributable to Parent	$ 0	$ 1	$ 0	$ 0

XML

Earnings Per Share (Notes)

9 Months Ended

Sep. 30, 2013

Earnings Per Share [Abstract]

Earnings per Share

EARNINGS PER SHARE

The Company reports both basic and diluted earnings per share. The calculation of diluted earnings per share assumes the issuance of potentially dilutive common shares outstanding during the period from the exercise of stock options. A reconciliation of both calculations is presented in the following table for the three months and nine months ended September 30:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2013		2012		2013		2012
	(In millions, except per share amounts)
Basic Earnings per Share
Net income attributable to DTE Energy Company	$	198	$	227	$	537	$	529
Average number of common shares outstanding	175		172		174		171
Weighted average net restricted shares outstanding	—		1		1		1
Dividends declared — common shares	$	115	$	106	$	337	$	307
Dividends declared — net restricted shares	1		1		1		2
Total distributed earnings	$	116	$	107	$	338	$	309
Net income less distributed earnings	$	82	$	120	$	199	$	220
Distributed (dividends per common share)	$	0.66	$	0.62	$	1.93	$	1.80
Undistributed	0.47		0.70		1.14		1.29
Total Basic Earnings per Common Share	$	1.13	$	1.32	$	3.07	$	3.09
Diluted Earnings per Share
Net income attributable to DTE Energy Company	$	198	$	227	$	537	$	529
Average number of common shares outstanding	176		172		175		171
Average incremental shares from assumed exercise of options	—		—		—		—
Common shares for dilutive calculation	176		172		175		171
Weighted average net restricted shares outstanding	—		1		1		1
Dividends declared — common shares	$	115	$	106	$	337	$	307
Dividends declared — net restricted shares	1		1		1		2
Total distributed earnings	$	116	$	107	$	338	$	309
Net income less distributed earnings	$	82	$	120	$	199	$	220
Distributed (dividends per common share)	$	0.66	$	0.62	$	1.93	$	1.80
Undistributed	0.47		0.69		1.14		1.28
Total Diluted Earnings per Common Share	$	1.13	$	1.31	$	3.07	$	3.08

XML

Financial and Other Derivative Instruments (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Derivatives designated as hedging instruments:
Derivative Asset Fair Value Gross Asset	$ 843	$ 1,016
Derivative Liability Fair Value Gross Liability	(815)	(1,020)
Derivative Assets, Current	72	108
Derivative Assets, Noncurrent	26	39
Derivative Liabilities, Current	(58)	(125)
Derivative Liabilities, Noncurrent	(21)	(26)
Estimate of Fair Value, Fair Value Disclosure [Member]
Derivatives designated as hedging instruments:
Derivative Assets, Current	711	862
Derivative Assets, Noncurrent	132	154
Derivative Liabilities, Current	(668)	(879)
Derivative Liabilities, Noncurrent	(147)	(141)
Interest rate contracts [Member]
Derivatives designated as hedging instruments:
Derivative Liability Fair Value Gross Liability	0	(1)
Natural Gas Commodity Contract [Member]
Derivatives designated as hedging instruments:
Derivative Asset Fair Value Gross Asset	483	645
Derivative Liability Fair Value Gross Liability	(471)	(661)
Electricity [Member]
Derivatives designated as hedging instruments:
Derivative Asset Fair Value Gross Asset	298	360
Derivative Liability Fair Value Gross Liability	(287)	(351)
Designated as Hedging Instrument [Member] | Interest rate contracts [Member]
Derivatives designated as hedging instruments:
Derivative Asset Fair Value Gross Asset	0	0
Derivative Liability Fair Value Gross Liability	0	(1)
Not Designated as Hedging Instrument [Member]
Derivatives designated as hedging instruments:
Derivative Asset Fair Value Gross Asset	843	1,016
Derivative Liability Fair Value Gross Liability	(815)	(1,019)
Not Designated as Hedging Instrument [Member] | Natural Gas Commodity Contract [Member]
Derivatives designated as hedging instruments:
Derivative Asset Fair Value Gross Asset	483	645
Derivative Liability Fair Value Gross Liability	(471)	(661)
Not Designated as Hedging Instrument [Member] | Electricity [Member]
Derivatives designated as hedging instruments:
Derivative Asset Fair Value Gross Asset	298	360
Derivative Liability Fair Value Gross Liability	(287)	(351)
Not Designated as Hedging Instrument [Member] | Other [Member]
Derivatives designated as hedging instruments:
Derivative Asset Fair Value Gross Asset	62	11
Derivative Liability Fair Value Gross Liability	$ (57)	$ (7)

XML

Consolidated Statements of Comprehensive Income (Unaudited) (Parenthetical) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Benefit Plan Improvement, Tax	$ 2	$ 1	$ 4	$ 4
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Tax	1	0	1	0
Other Comprehensive Income (Loss), Foreign Currency Translation Gain (Loss) Arising During Period, Tax	$ 0	$ 1	$ (1)	$ 1

XML

Significant Accounting Policies (Notes)

9 Months Ended

Sep. 30, 2013

Accounting Policies [Abstract]

Significant Accounting Policies [Text Block]

SIGNIFICANT ACCOUNTING POLICIES

Comprehensive Income

Comprehensive income is the change in common shareholders’ equity during a period from transactions and events from non-owner sources, including net income. As shown in the following tables, amounts recorded to accumulated other comprehensive loss for the three and nine months ended September 30, 2013 include unrealized gains and losses from derivatives accounted for as cash flow hedges, unrealized gains and losses on available-for-sale securities and the Company’s interest in other comprehensive income of equity investees, which comprise the net unrealized gains and losses on investments, changes in benefit obligations, consisting of deferred actuarial losses, prior service costs and transition amounts related to pension and other postretirement benefit plans, and foreign currency translation adjustments.

	Changes in Accumulated Other Comprehensive Loss by Component (a)
	For The Three Months Ended September 30, 2013
	Net Unrealized Gain/(Loss) on Derivatives			Net Unrealized Gain/(Loss) on Investments			Benefit Obligations (b)			Foreign Currency Translation		Total
	(In millions)
Beginning balance, June 30, 2013	$	(4	)	$	(8	)	$	(143	)	$	—	$	(155	)
Other comprehensive income before reclassifications	—			1			—			1		2
Amounts reclassified from accumulated other comprehensive income	—			—			2			—		2
Net current-period other comprehensive income	—			1			2			1		4
Ending balance, September 30, 2013	$	(4	)	$	(7	)	$	(141	)	$	1	$	(151	)

	Changes in Accumulated Other Comprehensive Loss by Component (a)
	For The Nine Months Ended September 30, 2013
	Net Unrealized Gain/(Loss) on Derivatives			Net Unrealized Gain/(Loss) on Investments			Benefit Obligations (b)			Foreign Currency Translation			Total
	(In millions)
Beginning balance, December 31, 2012	$	(4	)	$	(8	)	$	(148	)	$	2		$	(158	)
Other comprehensive income before reclassifications	—			1			—			(1		)	—
Amounts reclassified from accumulated other comprehensive income	—			—			7			—			7
Net current-period other comprehensive income (loss)	—			1			7			(1		)	7
Ending balance, September 30, 2013	$	(4	)	$	(7	)	$	(141	)	$	1		$	(151	)

______________________________________

(a) All amounts are net of tax.

(b) The amounts reclassified from accumulated other comprehensive income are included in the computation of the net periodic pension cost (see Retirement Benefits and Trusteed Assets Note 13).

Intangible Assets

The Company has certain intangible assets relating to emission allowances, renewable energy credits and non-utility contracts as shown below:

	September 30,		December 31,
	2013		2012
	(In millions)
Emission allowances	$	3	$	6
Renewable energy credits	48		44
Contract intangible assets	126		139
	177		189
Less accumulated amortization	41		34
Intangible assets, net	136		155
Less current intangible assets	14		20
	$	122	$	135

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 Company amortizes contract intangible assets on a straight-line basis over the expected period of benefit, ranging from 3 to 30 years.

Income Taxes

The Company's effective tax rate from continuing operations for the three months ended September 30, 2013 was 28 percent as compared to 32 percent for the three months ended September 30, 2012. The Company's effective tax rate from continuing operations for the nine months ended September 30, 2013 was 29 percent as compared to 32 percent for the nine months ended September 30, 2012. The decrease in the effective tax rate in 2013 is due primarily to higher production tax credits.

The Company had $3 million of unrecognized tax benefits at September 30, 2013, that, if recognized, would favorably impact its effective tax rate. The Company believes that it is possible that there will be a decrease in the unrecognized tax benefits of up to $1 million in the next twelve months.

XML

Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2013

Accounting Policies [Abstract]

Comprehensive Income [Policy Text Block]

Comprehensive Income

Comprehensive income is the change in common shareholders’ equity during a period from transactions and events from non-owner sources, including net income. As shown in the following tables, amounts recorded to accumulated other comprehensive loss for the three and nine months ended September 30, 2013 include unrealized gains and losses from derivatives accounted for as cash flow hedges, unrealized gains and losses on available-for-sale securities and the Company’s interest in other comprehensive income of equity investees, which comprise the net unrealized gains and losses on investments, changes in benefit obligations, consisting of deferred actuarial losses, prior service costs and transition amounts related to pension and other postretirement benefit plans, and foreign currency translation adjustments.

Intangible Assets [Policy Text Block]

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 Company amortizes contract intangible assets on a straight-line basis over the expected period of benefit

Income Tax [Policy Text Block]

Income Taxes

The Company's effective tax rate from continuing operations for the three months ended September 30, 2013 was 28 percent as compared to 32 percent for the three months ended September 30, 2012. The Company's effective tax rate from continuing operations for the nine months ended September 30, 2013 was 29 percent as compared to 32 percent for the nine months ended September 30, 2012. The decrease in the effective tax rate in 2013 is due primarily to higher production tax credits.

The Company had $3 million of unrecognized tax benefits at September 30, 2013, that, if recognized, would favorably impact its effective tax rate. The Company believes that it is possible that there will be a decrease in the unrecognized tax benefits of up to $1 million in the next twelve months.

XML

Long-Term Debt Long-Term Debt (Details Textuals) (Gas [Member], Mortgages [Member], USD $) In Millions, unless otherwise specified	Sep. 30, 2013
Ten Years [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount, Future Issuance	$ 50
Future Debt Instrument, Interest Rate, Stated Percentage	3.64%
Twelve Years [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount, Future Issuance	70
Future Debt Instrument, Interest Rate, Stated Percentage	3.74%
Fifteen Years [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount, Future Issuance	$ 50
Future Debt Instrument, Interest Rate, Stated Percentage	3.94%

XML

Financial and Other Derivative Instruments (Details 3) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$ 23	$ 12	$ 56	$ 57
Foreign currency exchange contracts [Member] | Operating Revenue [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	0	(2)	(1)	(1)
Natural Gas Commodity Contract [Member] | Operating Revenue [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	1	(54)	37	(51)
Natural Gas Commodity Contract [Member] | Fuel, purchased power and gas [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(1)	50	(33)	45
Electricity [Member] | Operating Revenue [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	22	17	52	52
Other [Member] | Operating Revenue [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$ 1	$ 1	$ 1	$ 12

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Long-Term Debt (Notes)

9 Months Ended

Sep. 30, 2013

Long-term Debt, Unclassified [Abstract]

Long-term Debt [Text Block]

LONG-TERM DEBT

Debt Issuances

In 2013, the following debt was issued:

Company	Month Issued	Type	Interest Rate		Maturity	Amount
						(In millions)
DTE Electric	March	Mortgage Bonds (a)	4.00	%	2043	$	375
DTE Electric	August	Mortgage Bonds (a)	3.65	%	2024	400
						$	775

_______________________________________

(a) Proceeds were used for the redemption of DTE Electric long-term debt, for the repayment of short-term borrowings, and for general corporate purposes.

In September 2013, DTE Gas agreed to issue $50 million of 3.64%, 10-year mortgage bonds, $70 million of 3.74%, 12-year mortgage bonds, and $50 million of 3.94%, 15-year mortgage bonds to a group of institutional investors in a private placement transaction. The bonds are expected to close and fund in December 2013. The aggregate proceeds are planned to be used for general corporate purposes.

Debt Redemptions

In 2013, the following debt was redeemed:

Company	Month	Type	Interest Rate		Maturity	Amount
						(In millions)
DTE Electric	March	Securitization Bonds	6.42	%	2013	$	88
DTE Electric	March	Tax Exempt Revenue Bonds (a)	5.30	%	2030	51
DTE Electric	April	Other Long-Term Debt	Various		2013	13
DTE Gas	April	Senior Notes	5.26	%	2013	60
DTE Energy	Various	Other Long-Term Debt	Various		2013	4
DTE Energy	June	Senior Notes	Variable		2013	300
DTE Electric	September	Securitization Bonds	6.62	%	2015	89
DTE Electric	September	Senior Notes	6.40	%	2013	250
						$	855

_______________________________________

(a) 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.

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Fair Value Fair Value (Details 4) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Fair Value of Financial Instruments [Line Items]
Notes Receivable Excudling Capital Leases	$ 37	$ 39
Dividends payable	116	107
Short-term Debt	271	240
Long-term Debt	7,729	7,813
Fair Value, Inputs, Level 1 [Member]
Fair Value of Financial Instruments [Line Items]
Notes Receivable, Fair Value Disclosure	0	0
Dividends Payable Fair Value Disclosure	116	107
Short-term Debt, Fair Value	0	0
Long-term Debt, Fair Value	436	507
Fair Value, Inputs, Level 2 [Member]
Fair Value of Financial Instruments [Line Items]
Notes Receivable, Fair Value Disclosure	0	0
Dividends Payable Fair Value Disclosure	0	0
Short-term Debt, Fair Value	271	240
Long-term Debt, Fair Value	7,067	7,453
Fair Value, Inputs, Level 3 [Member]
Fair Value of Financial Instruments [Line Items]
Notes Receivable, Fair Value Disclosure	37	39
Dividends Payable Fair Value Disclosure	0	0
Short-term Debt, Fair Value	0	0
Long-term Debt, Fair Value	$ 738	$ 933

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Financial and Other Derivative Instruments (Details 4)	Sep. 30, 2013 dte.volumes
Natural Gas Commodity Contract [Member]
Derivative [Line Items]
Volume of Commodity Contracts	683,113,433
Electricity [Member]
Derivative [Line Items]
Volume of Commodity Contracts	59,672,654
Foreign currency exchange contracts [Member]
Derivative [Line Items]
Volume of Commodity Contracts	48,741,288
FTR [Member]
Derivative [Line Items]
Volume of Commodity Contracts	13,005,024

XML

Organization and Basis of Presentation (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2012	Dec. 31, 2011
Assets [Abstract]
Cash and cash equivalents	$ 71	$ 65	$ 59	$ 68
Restricted cash	64	122
Accounts receivable	1,239	1,336
Other current assets	248	194
Property, plant and equipment	15,511	14,684
Securitized regulatory assets	280	413
Other assets	198	197
Total Assets	26,231	26,339
Liabilities [Abstract]
Current portion long-term debt, including, capital leases	896	817
Current regulatory liabilities	230	89
Other current liabilities	457	449
Mortgage bonds, notes and other	6,253	6,220
Securitization bonds	105	302
Capital lease obligations	8	12
Other long term liabilities	290	306
Variable Interest Entity Securitization [Member]
Assets [Abstract]
Cash and cash equivalents	0	0
Restricted cash	44	102
Accounts receivable	39	34
Inventories	0	0
Other current assets	0	0
Property, plant and equipment	0	0
Securitized regulatory assets	280	413
Other assets	5	7
Total Assets	368	556
Liabilities [Abstract]
Accounts payable and accrued current liabilities	2	11
Current portion long-term debt, including, capital leases	196	177
Current regulatory liabilities	48	50
Other current liabilities	0	0
Mortgage bonds, notes and other	0	0
Securitization bonds	105	302
Capital lease obligations	0	0
Other long term liabilities	8	7
Total Liabilities	359	547
Variable Interest Entity, Primary Beneficiary [Member]
Assets [Abstract]
Cash and cash equivalents	10	10
Restricted cash	7	7
Accounts receivable	17	7
Inventories	112	141
Other current assets	1	1
Property, plant and equipment	100	93
Securitized regulatory assets	0	0
Other assets	9	11
Total Assets	256	270
Liabilities [Abstract]
Accounts payable and accrued current liabilities	35	14
Current portion long-term debt, including, capital leases	9	8
Current regulatory liabilities	0	0
Other current liabilities	3	4
Mortgage bonds, notes and other	22	25
Securitization bonds	0	0
Capital lease obligations	7	11
Other long term liabilities	3	2
Total Liabilities	79	64
Consolidated Variable Interest Entity [Member]
Assets [Abstract]
Cash and cash equivalents	10	10
Restricted cash	51	109
Accounts receivable	56	41
Inventories	112	141
Other current assets	1	1
Property, plant and equipment	100	93
Securitized regulatory assets	280	413
Other assets	14	18
Total Assets	624	826
Liabilities [Abstract]
Accounts payable and accrued current liabilities	37	25
Current portion long-term debt, including, capital leases	205	185
Current regulatory liabilities	48	50
Other current liabilities	3	4
Mortgage bonds, notes and other	22	25
Securitization bonds	105	302
Capital lease obligations	7	11
Other long term liabilities	11	9
Total Liabilities	$ 438	$ 611

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Fair Value (Tables)

9 Months Ended

Sep. 30, 2013

Fair Value Disclosures [Abstract]

Assets and liabilities measured and recorded at fair value on a recurring basis

The following table presents assets and liabilities measured and recorded at fair value on a recurring basis as of September 30, 2013 and December 31, 2012:

	September 30, 2013															December 31, 2012
	Level 1			Level 2			Level 3			Netting (a)			Net Balance			Level 1			Level 2			Level 3			Netting (a)			Net Balance
	(In millions)
Assets:
Cash equivalents (b)	$	—		$	68		$	—		$	—		$	68		$	—		$	123		$	—		$	—		$	123
Nuclear decommissioning trusts	757			382			—			—			1,139			694			343			—			—			1,037
Other investments (c) (d)	76			48			—			—			124			66			44			—			—			110
Derivative assets:
Commodity Contracts:
Natural Gas	388			61			34			(474		)	9			555			66			24			(605		)	40
Electricity	—			210			88			(216		)	82			—			226			134			(258		)	102
Other	48			9			5			(55		)	7			6			3			2			(6		)	5
Total derivative assets	436			280			127			(745		)	98			561			295			160			(869		)	147
Total	$	1,269		$	778		$	127		$	(745	)	$	1,429		$	1,321		$	805		$	160		$	(869	)	$	1,417
Liabilities:
Derivative liabilities:
Interest rate contracts	$	—		$	—		$	—		$	—		$	—		$	—		$	(1	)	$	—		$	—		$	(1	)
Commodity Contracts:
Natural Gas	(374		)	(49		)	(48		)	445			(26		)	(526		)	(73		)	(62		)	605			(56		)
Electricity	—			(204		)	(83		)	236			(51		)	—			(240		)	(111		)	258			(93		)
Other	(52		)	(5		)	—			55			(2		)	(6		)	(1		)	—			6			(1		)
Total derivative liabilities	(426		)	(258		)	(131		)	736			(79		)	(532		)	(315		)	(173		)	869			(151		)
Total	$	(426	)	$	(258	)	$	(131	)	$	736		$	(79	)	$	(532	)	$	(315	)	$	(173	)	$	869		$	(151	)
Net Assets (Liabilities) at the end of the period	$	843		$	520		$	(4	)	$	(9	)	$	1,350		$	789		$	490		$	(13	)	$	—		$	1,266
Assets:
Current	$	400		$	285		$	94		$	(639	)	$	140		$	493		$	372		$	120		$	(754	)	$	231
Noncurrent (e)	869			493			33			(106		)	1,289			828			433			40			(115		)	1,186
Total Assets	$	1,269		$	778		$	127		$	(745	)	$	1,429		$	1,321		$	805		$	160		$	(869	)	$	1,417
Liabilities:
Current	$	(379	)	$	(189	)	$	(100	)	$	610		$	(58	)	$	(466	)	$	(269	)	$	(144	)	$	754		$	(125	)
Noncurrent	(47		)	(69		)	(31		)	126			(21		)	(66		)	(46		)	(29		)	115			(26		)
Total Liabilities	$	(426	)	$	(258	)	$	(131	)	$	736		$	(79	)	$	(532	)	$	(315	)	$	(173	)	$	869		$	(151	)
Net Assets (Liabilities) at the end of the period	$	843		$	520		$	(4	)	$	(9	)	$	1,350		$	789		$	490		$	(13	)	$	—		$	1,266

_______________________________________

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

(b) At September 30, 2013, available-for-sale securities of $68 million included $51 million and $17 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position. At December 31, 2012, available-for-sale securities of $123 million, included $109 million and $14 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position.

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

(d) Available-for-sale equity securities of $6 million at September 30, 2013 and $5 million at December 31, 2012, are included in Other investments on the Consolidated Statements of Financial Position.

(e) Includes $124 million and $110 million at September 30, 2013 and December 31, 2012, respectively, of Other investments that are included in the Consolidated Statements of Financial Position in Other investments.

Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block]

The following tables present the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for the three months and nine months ended September 30, 2013 and 2012:

	Three Months Ended September 30, 2013											Three Months Ended September 30, 2012
	Natural Gas			Electricity			Other		Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of June 30	$	(30	)	$	12		$	2	$	(16	)	$	2		$	50		$	5		$	57
Transfers into Level 3	—			—			—		—			—			—			—			—
Transfers out of Level 3	—			(1		)	—		(1		)	—			—			—			—
Total gains (losses):
Included in earnings	8			17			—		25			(43		)	12			1			(30		)
Recorded in regulatory assets/liabilities	—			—			3		3			—			—			7			7
Purchases, issuances and settlements:
Settlements	8			(23		)	—		(15		)	(3		)	(38		)	(7		)	(48		)
Net Assets (Liabilities) as of September 30	$	(14	)	$	5		$	5	$	(4	)	$	(44	)	$	24		$	6		$	(14	)
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 September 30, 2013 and 2012 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations	$	(8	)	$	8		$	—	$	—		$	(43	)	$	5		$	1		$	(37	)

	Nine Months Ended September 30, 2013												Nine Months Ended September 30, 2012
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of December 31	$	(38	)	$	23		$	2		$	(13	)	$	6		$	32		$	6		$	44
Transfers into Level 3	—			—			—			—			1			28			—			29
Transfers out of Level 3	(2		)	—			—			(2		)	(2		)	—			—			(2		)
Total gains (losses):
Included in earnings	(1		)	44			—			43			(38		)	53			—			15
Recorded in regulatory assets/liabilities	—			—			7			7			—			—			12			12
Purchases, issuances and settlements:
Purchases	—			(1		)	—			(1		)	—			1			—			1
Settlements	27			(61		)	(4		)	(38		)	(11		)	(90		)	(12		)	(113		)
Net Assets (Liabilities) as of September 30	$	(14	)	$	5		$	5		$	(4	)	$	(44	)	$	24		$	6		$	(14	)
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 September 30, 2013 and 2012 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations	$	(14	)	$	36		$	—		$	22		$	(39	)	$	43		$	—		$	4

Transfers Between Level 1 Level 2 and Level 3 [Table Text Block]

The following table shows transfers between the levels of the fair value hierarchy for the three months and nine months ended September 30, 2013 and 2012:

	Three Months Ended September 30, 2013					Three Months Ended September 30, 2012
	Level 1	Level 2		Level 3		Level 1	Level 2		Level 3
	(In millions)
Transfers into Level 1 from	$ N/A	$	—	$	—	$ N/A	$	—	$	—
Transfers into Level 2 from	—	N/A		1		—	N/A		—
Transfers into Level 3 from	—	—		N/A		—	—		N/A

	Nine Months Ended September 30, 2013					Nine Months Ended September 30, 2012
	Level 1	Level 2		Level 3		Level 1	Level 2		Level 3
	(In millions)
Transfers into Level 1 from	$ N/A	$	—	$	—	$ N/A	$	—	$	—
Transfers into Level 2 from	—	N/A		2		—	N/A		2
Transfers into Level 3 from	—	—		N/A		—	29		N/A

Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Table Text Block]

The following table presents the unobservable inputs related to Level 3 assets and liabilities as of September 30, 2013:

	September 30, 2013
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	34	$	(48	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.10	)	—	$	4.22	/MMBtu	$	0.10	/MMBtu
Electricity	$	88	$	(83	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(8	)	—	$	15	/MWh	$	2	/MWh

The following table presents the unobservable inputs related to Level 3 assets and liabilities as of December 31, 2012:

	December 31, 2012
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	24	$	(62	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(0.63	)	—	$	1.95	/MMBtu	$	0.03	/MMBtu
Electricity	$	134	$	(111	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(2	)	—	$	16	/MWh	$	3	/MWh

Fair Value of Financial Instruments [Table Text Block]

The following table presents the carrying amount and fair value of financial instruments as of September 30, 2013 and December 31, 2012:

	September 30, 2013								December 31, 2012
	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	$	37	$	—	$	—	$	37	$	39	$	—	$	—	$	39
Dividends payable	$	116	$	116	$	—	$	—	$	107	$	107	$	—	$	—
Short-term borrowings	$	271	$	—	$	271	$	—	$	240	$	—	$	240	$	—
Long-term debt	$	7,729	$	436	$	7,067	$	738	$	7,813	$	507	$	7,453	$	933

Fair Value of Nuclear Decommissioning Trust Fund Assets [Table Text Block]

The following table summarizes the fair value of the nuclear decommissioning trust fund assets:

	September 30, 2013		December 31, 2012
	(In millions)
Fermi 2	$	1,120	$	1,021
Fermi 1	3		3
Low level radioactive waste	16		13
Total	$	1,139	$	1,037

Schedule of Realized Gain (Loss) [Table Text Block]

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

	Three Months Ended September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
	(In millions)
Realized gains	$	11		$	7		$	30		$	21
Realized losses	$	(11	)	$	(6	)	$	(25	)	$	(17	)
Proceeds from sales of securities	$	13		$	12		$	40		$	48

Fair Value and Unrealized Gains for Nuclear Decommissioning Trust Fund [Table Text Block]

The following table sets forth the fair value and unrealized gains for the nuclear decommissioning trust funds:

	September 30, 2013				December 31, 2012
	Fair Value		Unrealized Gains		Fair Value		Unrealized Gains
	(In millions)
Equity securities	$	732	$	195	$	631	$	122
Debt securities	395		17		399		27
Cash and cash equivalents	12		—		7		—
	$	1,139	$	212	$	1,037	$	149

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Significant Accounting Policies (Tables)

9 Months Ended

Sep. 30, 2013

Accounting Policies [Abstract]

Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block]

	Changes in Accumulated Other Comprehensive Loss by Component (a)
	For The Three Months Ended September 30, 2013
	Net Unrealized Gain/(Loss) on Derivatives			Net Unrealized Gain/(Loss) on Investments			Benefit Obligations (b)			Foreign Currency Translation		Total
	(In millions)
Beginning balance, June 30, 2013	$	(4	)	$	(8	)	$	(143	)	$	—	$	(155	)
Other comprehensive income before reclassifications	—			1			—			1		2
Amounts reclassified from accumulated other comprehensive income	—			—			2			—		2
Net current-period other comprehensive income	—			1			2			1		4
Ending balance, September 30, 2013	$	(4	)	$	(7	)	$	(141	)	$	1	$	(151	)

	Changes in Accumulated Other Comprehensive Loss by Component (a)
	For The Nine Months Ended September 30, 2013
	Net Unrealized Gain/(Loss) on Derivatives			Net Unrealized Gain/(Loss) on Investments			Benefit Obligations (b)			Foreign Currency Translation			Total
	(In millions)
Beginning balance, December 31, 2012	$	(4	)	$	(8	)	$	(148	)	$	2		$	(158	)
Other comprehensive income before reclassifications	—			1			—			(1		)	—
Amounts reclassified from accumulated other comprehensive income	—			—			7			—			7
Net current-period other comprehensive income (loss)	—			1			7			(1		)	7
Ending balance, September 30, 2013	$	(4	)	$	(7	)	$	(141	)	$	1		$	(151	)

______________________________________

(a) All amounts are net of tax.

(b) The amounts reclassified from accumulated other comprehensive income are included in the computation of the net periodic pension cost (see Retirement Benefits and Trusteed Assets Note 13).

Schedule of Finite-Lived Intangible Assets by Major Class [Table Text Block]

The Company has certain intangible assets relating to emission allowances, renewable energy credits and non-utility contracts as shown below:

	September 30,		December 31,
	2013		2012
	(In millions)
Emission allowances	$	3	$	6
Renewable energy credits	48		44
Contract intangible assets	126		139
	177		189
Less accumulated amortization	41		34
Intangible assets, net	136		155
Less current intangible assets	14		20
	$	122	$	135

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Fair Value Fair Value (Details 2) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Fair Value Transfers Between Level 1, Level 2 and Level 3 [Line Items]
Transfers from Level 2 to Level 1	$ 0	$ 0	$ 0	$ 0
Transfers from Level 3 to Level 1	0	0	0	0
Transfers from Level 1 to Level 2	0	0	0	0
Transfers from Level 3 to Level 2	1	0	2	2
Transfers from Level 1 to Level 3	0	0	0	0
Transfers from Level 2 to Level 3	$ 0	$ 0	$ 0	$ 29

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Short-Term Credit Arrangements and Borrowings (Tables)

9 Months Ended

Sep. 30, 2013

Short-term Debt [Abstract]

Schedule of Line of Credit Facilities [Table Text Block]

The availability under the facilities in place at September 30, 2013 is shown in the following table:

	DTE Energy		DTE Electric		DTE Gas		Total
	(In millions)
Unsecured letter of credit facility, expiring in May 2014	$	50	$	—	$	—	$	50
Unsecured letter of credit facility, expiring in August 2015	125		—		—		125
Unsecured revolving credit facility, expiring April 2018	1,200		300		300		1,800
Total credit facilities at September 30, 2013	1,375		300		300		1,975
Amounts outstanding at September 30, 2013:
Commercial paper issuances	44		11		216		271
Letters of credit	235		—		—		235
	279		11		216		506
Net availability at September 30, 2013	$	1,096	$	289	$	84	$	1,469

XML

Organization and Basis of Presentation (Details Textuals) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013 customers
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of Electric Customers	2,100,000
Number of Gas Customers	1,200,000
Significant Potential Exposure to Loss Due to VIE Long-Term Purchase Contracts	$ 0

XML

Fair Value (Details 5) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Decommissioning Fund Investments	$ 1,139	$ 1,037
Fermi 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Decommissioning Fund Investments	1,120	1,021
Fermi 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Decommissioning Fund Investments	3	3
Low level radioactive waste [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Decommissioning Fund Investments	$ 16	$ 13

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Common Stock Common Stock (Tables)

9 Months Ended

Sep. 30, 2013

Stockholders' Equity Note [Abstract]

Common Stock Issued [Table Text Block]

During 2013, the Company contributed the following amounts of DTE Energy Common stock to the DTE Energy Company Affiliates Employee Benefit Plans Master Trust:

Date	Number of Shares	Price Per Share		Amount
				(In millions)
March 12, 2013	750,075	$	66.66	$	50
June 12, 2013	753,579	$	66.35	50
September 12, 2013	1,522,301	$	65.69	100
				$	200

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Earnings Per Share (Details) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Basic Earnings per Share
Net Income Attributable to DTE Energy Company	$ 198	$ 227	$ 537	$ 529
Average number of common shares outstanding	175	172	174	171
Weighted average net restricted shares outstanding	0	1	1	1
Dividends declared on common stock	115	106	337	307
Dividends declared - net restricted shares	1	1	1	2
Total distributed earnings	116	107	338	309
Net income less distributed earnings	82	120	199	220
Distributed (dividends per common share)	$ 0.66	$ 0.62	$ 1.93	$ 1.80
Undistributed	$ 0.47	$ 0.70	$ 1.14	$ 1.29
Total Basic Earnings per Common Share	$ 1.13	$ 1.32	$ 3.07	$ 3.09
Diluted Earnings per Share
Net Income Attributable to DTE Energy Company	198	227	537	529
Average number of common shares outstanding	175	172	174	171
Average incremental shares from assumed exercise of options	0	0	0	0
Common shares for dilutive calculation	176	172	175	171
Weighted average net restricted shares outstanding	0	1	1	1
Dividends declared on common stock	115	106	337	307
Dividends declared - net restricted shares	1	1	1	2
Total distributed earnings	116	107	338	309
Net income less distributed earnings	$ 82	$ 120	$ 199	$ 220
Distributed (dividends per common share)	$ 0.66	$ 0.62	$ 1.93	$ 1.80
Undistributed	$ 0.47	$ 0.69	$ 1.14	$ 1.28
Total Diluted Earnings per Common Share	$ 1.13	$ 1.31	$ 3.07	$ 3.08

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Retirement Benefits and Trusteed Assets Retirement Benefits and Trusteed Assets (Details Textuals) (USD $)	9 Months Ended			3 Months Ended		9 Months Ended				3 Months Ended		9 Months Ended		3 Months Ended			9 Months Ended
	Sep. 30, 2013	Jun. 30, 2013	Dec. 31, 2012	Sep. 30, 2013 Other Postretirement Benefit Plan, Defined Benefit [Member]	Sep. 30, 2012 Other Postretirement Benefit Plan, Defined Benefit [Member]	Sep. 30, 2013 Other Postretirement Benefit Plan, Defined Benefit [Member]	Sep. 30, 2012 Other Postretirement Benefit Plan, Defined Benefit [Member]	Jun. 30, 2013 Other Postretirement Benefit Plan, Defined Benefit [Member]	Dec. 31, 2012 Other Postretirement Benefit Plan, Defined Benefit [Member]	Sep. 30, 2013 Pension Plan, Defined Benefit [Member]	Sep. 30, 2012 Pension Plan, Defined Benefit [Member]	Sep. 30, 2013 Pension Plan, Defined Benefit [Member]	Sep. 30, 2012 Pension Plan, Defined Benefit [Member]	Sep. 30, 2013 Common Stock [Member] Pension Plan, Defined Benefit [Member]	Jun. 30, 2013 Common Stock [Member] Pension Plan, Defined Benefit [Member]	Mar. 31, 2013 Common Stock [Member] Pension Plan, Defined Benefit [Member]	Sep. 30, 2013 Common Stock [Member] Pension Plan, Defined Benefit [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Service Cost				$ 9,000,000	$ 15,000,000	$ 37,000,000	$ 51,000,000			$ 22,000,000	$ 20,000,000	$ 71,000,000	$ 61,000,000
Pension Contributions												250,000,000		100,000,000	50,000,000	50,000,000	200,000,000
Estimated Future Employer Contributions in Current Fiscal Year						120,000,000						25,000,000
Contributions by Employer						145,000,000
Retiree Health Care Allowance	3,250
Assumptions Used Calculating Benefit Obligation, Discount Rate								4.30%	4.15%
Remeasurement Reduction to Post Retirement Benefit Obligation		258,000,000	439,000,000
Remeasurement Reduction to Post Retirement Benefit Obligation Liability		721,000,000	1,200,000,000
Remeasurement Decrease in Benefit Cost for Postretirement Plans		69,000,000
Annual Decrease in Other Postretirement Benefits Costs due to Remeasurement	$ 40,000,000

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Common Stock (Details) (Pension Plan, Defined Benefit [Member], USD $) In Millions, except Share data, unless otherwise specified	3 Months Ended			9 Months Ended
	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Sep. 30, 2013	Sep. 12, 2013
Class of Stock [Line Items]
Pension Contributions				$ 250
Common Stock [Member]
Class of Stock [Line Items]
Pension Contributions	$ 100	$ 50	$ 50	$ 200
Contribution of Common Stock to Pension Plan Shares	1,522,301	753,579	750,075
Contribution of Common Stock to Pension Plans Amount Per Share		$ 66.35	$ 66.66		$ 65.69

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Significant Accounting Policies (Details Textuals) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Significant Accounting Policies [Line Items]
Effective Income Tax Rate, Continuing Operations	28.00%	32.00%	29.00%	32.00%
Unrecognized Tax Benefits	$ 3		$ 3
Time Period of Decrease in Unrecognized Tax Benefits			12 months
Minimum [Member]
Significant Accounting Policies [Line Items]
Finite Lived Asset Useful Life			3 years
Maximum [Member]
Significant Accounting Policies [Line Items]
Finite Lived Asset Useful Life			30 years
Unrecognized Tax Benefits, Decreases Resulting from Settlements with Taxing Authorities			$ 1

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Short-Term Credit Arrangements and Borrowings (Details Textuals) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Short-term Debt [Line Items]
Revolving Credit Facilities with a Syndicate Number of Banks	19
Number of Banks that Provide Percentage of Commitment in any Facility	1
Maximum Percentage of Commitment to Bank in any Facility	8.70%
Maximum Total Funded Debt to Total Capitalization Ratio	0.65
Other outstanding letters of credit	$ 506
DTE Energy [Member]
Short-term Debt [Line Items]
Total Funded Debt to Total Capitalization Ratio, Amount	0.48
Other outstanding letters of credit	279
DTE Electric [Member]
Short-term Debt [Line Items]
Total Funded Debt to Total Capitalization Ratio, Amount	0.53
Other outstanding letters of credit	11
DTE Gas [Member]
Short-term Debt [Line Items]
Total Funded Debt to Total Capitalization Ratio, Amount	0.44
Other outstanding letters of credit	216
Letter of Credit [Member]
Short-term Debt [Line Items]
Other outstanding letters of credit	235
Letter of Credit [Member] | DTE Energy [Member]
Short-term Debt [Line Items]
Other outstanding letters of credit	235
Letter of Credit [Member] | DTE Electric [Member]
Short-term Debt [Line Items]
Other outstanding letters of credit	0
Letter of Credit [Member] | DTE Gas [Member]
Short-term Debt [Line Items]
Other outstanding letters of credit	0
Demand Financing Agreement with Newedge plus letter of credit [Member] | DTE Energy [Member]
Short-term Debt [Line Items]
Financing Agreement, Maximum Borrowing Capacity	140
Demand Financing Agreement with Newedge [Member] | DTE Energy [Member]
Short-term Debt [Line Items]
Financing Agreement, Maximum Borrowing Capacity	100
Financing Agreement, Amount Outstanding	75	65
Maximum Additional Margin Financing	50
Other outstanding letters of credit [Member] | Letter of Credit [Member] | DTE Energy [Member]
Short-term Debt [Line Items]
Other outstanding letters of credit	47
Demand Financing Agreement with Newedge letter of credit to raise capacity [Member] | Letter of Credit [Member] | DTE Energy [Member]
Short-term Debt [Line Items]
Financing Agreement, Maximum Borrowing Capacity	$ 40

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Organization and Basis of Presentation (Tables)

9 Months Ended

Sep. 30, 2013

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

Schedule of Variable Interest Entities [Table Text Block]

	September 30, 2013						December 31, 2012
	Securitization		Other		Total		Securitization		Other		Total
	(In millions)
ASSETS
Cash and cash equivalents	$	—	$	10	$	10	$	—	$	10	$	10
Restricted cash	44		7		51		102		7		109
Accounts receivable	39		17		56		34		7		41
Inventories	—		112		112		—		141		141
Other current assets	—		1		1		—		1		1
Property, plant and equipment	—		100		100		—		93		93
Securitized regulatory assets	280		—		280		413		—		413
Other assets	5		9		14		7		11		18
	$	368	$	256	$	624	$	556	$	270	$	826
LIABILITIES
Accounts payable and accrued current liabilities	$	2	$	35	$	37	$	11	$	14	$	25
Current portion long-term debt, including capital leases	196		9		205		177		8		185
Current regulatory liabilities	48		—		48		50		—		50
Other current liabilities	—		3		3		—		4		4
Mortgage bonds, notes and other	—		22		22		—		25		25
Securitization bonds	105		—		105		302		—		302
Capital lease obligations	—		7		7		—		11		11
Other long-term liabilities	8		3		11		7		2		9
	$	359	$	79	$	438	$	547	$	64	$	611

Summary of Amounts for Non-Consolidated Variable Interest Entities [Table Text Block]

Amounts for non-consolidated VIEs as of September 30, 2013 and December 31, 2012 are as follows:

	September 30, 2013		December 31, 2012
	(In millions)
Other investments	$	138	$	130
Notes receivable	$	3	$	6

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Consolidated Statements of Financial Position (Unaudited) (Parenthetical) (Parentheticals) (USD $) In Millions, except Share data, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Allowance for doubtful accounts	$ 67	$ 62
Common stock, par value	$ 0	$ 0
Common stock, shares authorized	400,000,000	400,000,000
Common stock, shares issued	176,797,248	172,351,680
Common stock, shares outstanding	176,797,248	172,351,680

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Consolidated Statements of Changes in Equity (Unaudited) (USD $) In Millions, except Share data	Total	Common Stock	Retained Earnings	Accumulated Other Comprehensive Loss	Accumulated Translation Adjustment [Member]	Accumulated Defined Benefit Plans Adjustment [Member]	Accumulated Net Unrealized Investment Gain (Loss) [Member]	Non-controlling Interest
Stockholders' Equity, Including Portion Attributable to Noncontrolling interest at Dec. 31, 2012	$ 7,411	$ 3,587	$ 3,944	$ (158)				$ 38
Beginning Balance, shares at Dec. 31, 2012	172,351,680	172,352,000
Net Income	542		537					5
Dividends declared on common stock	(339)		(339)
Stock Issued During Period, Shares, New Issues		439,000
Issuance of common stock, value	29	29
Contribution of Common Stock to Pension Plan Shares		3,026,000
Contribution of Common Stock to Pension Plan	200	200
Other Comprehensive Income (Loss), Net of Tax	7				(1)	7	1
Stock-based compensation, distributions to noncontrolling interests and other, shares		980,000
Stock-based compensation, distributions to noncontrolling interests and other	60	69						(9)
Stockholders' Equity, Including Portion Attributable to Noncontrolling interest at Sep. 30, 2013	7,910	3,885	4,142	(151)				34
Ending Balance, shares at Sep. 30, 2013	176,797,248	176,797,000
Stockholders' Equity, Including Portion Attributable to Noncontrolling interest at Jun. 30, 2013
Net Income	200
Other Comprehensive Income (Loss), Net of Tax	4				(1)	2	1
Stockholders' Equity, Including Portion Attributable to Noncontrolling interest at Sep. 30, 2013	$ 7,910			$ (151)
Ending Balance, shares at Sep. 30, 2013	176,797,248

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Fair Value (Notes)

9 Months Ended

Sep. 30, 2013

Fair Value Disclosures [Abstract]

Fair Value Disclosure

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 Company makes certain assumptions it believes 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 Company and its counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at September 30, 2013 and December 31, 2012. The Company believes it uses valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.

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

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

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

The following table presents assets and liabilities measured and recorded at fair value on a recurring basis as of September 30, 2013 and December 31, 2012:

	September 30, 2013															December 31, 2012
	Level 1			Level 2			Level 3			Netting (a)			Net Balance			Level 1			Level 2			Level 3			Netting (a)			Net Balance
	(In millions)
Assets:
Cash equivalents (b)	$	—		$	68		$	—		$	—		$	68		$	—		$	123		$	—		$	—		$	123
Nuclear decommissioning trusts	757			382			—			—			1,139			694			343			—			—			1,037
Other investments (c) (d)	76			48			—			—			124			66			44			—			—			110
Derivative assets:
Commodity Contracts:
Natural Gas	388			61			34			(474		)	9			555			66			24			(605		)	40
Electricity	—			210			88			(216		)	82			—			226			134			(258		)	102
Other	48			9			5			(55		)	7			6			3			2			(6		)	5
Total derivative assets	436			280			127			(745		)	98			561			295			160			(869		)	147
Total	$	1,269		$	778		$	127		$	(745	)	$	1,429		$	1,321		$	805		$	160		$	(869	)	$	1,417
Liabilities:
Derivative liabilities:
Interest rate contracts	$	—		$	—		$	—		$	—		$	—		$	—		$	(1	)	$	—		$	—		$	(1	)
Commodity Contracts:
Natural Gas	(374		)	(49		)	(48		)	445			(26		)	(526		)	(73		)	(62		)	605			(56		)
Electricity	—			(204		)	(83		)	236			(51		)	—			(240		)	(111		)	258			(93		)
Other	(52		)	(5		)	—			55			(2		)	(6		)	(1		)	—			6			(1		)
Total derivative liabilities	(426		)	(258		)	(131		)	736			(79		)	(532		)	(315		)	(173		)	869			(151		)
Total	$	(426	)	$	(258	)	$	(131	)	$	736		$	(79	)	$	(532	)	$	(315	)	$	(173	)	$	869		$	(151	)
Net Assets (Liabilities) at the end of the period	$	843		$	520		$	(4	)	$	(9	)	$	1,350		$	789		$	490		$	(13	)	$	—		$	1,266
Assets:
Current	$	400		$	285		$	94		$	(639	)	$	140		$	493		$	372		$	120		$	(754	)	$	231
Noncurrent (e)	869			493			33			(106		)	1,289			828			433			40			(115		)	1,186
Total Assets	$	1,269		$	778		$	127		$	(745	)	$	1,429		$	1,321		$	805		$	160		$	(869	)	$	1,417
Liabilities:
Current	$	(379	)	$	(189	)	$	(100	)	$	610		$	(58	)	$	(466	)	$	(269	)	$	(144	)	$	754		$	(125	)
Noncurrent	(47		)	(69		)	(31		)	126			(21		)	(66		)	(46		)	(29		)	115			(26		)
Total Liabilities	$	(426	)	$	(258	)	$	(131	)	$	736		$	(79	)	$	(532	)	$	(315	)	$	(173	)	$	869		$	(151	)
Net Assets (Liabilities) at the end of the period	$	843		$	520		$	(4	)	$	(9	)	$	1,350		$	789		$	490		$	(13	)	$	—		$	1,266

_______________________________________

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

(b) At September 30, 2013, available-for-sale securities of $68 million included $51 million and $17 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position. At December 31, 2012, available-for-sale securities of $123 million, included $109 million and $14 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position.

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

(d) Available-for-sale equity securities of $6 million at September 30, 2013 and $5 million at December 31, 2012, are included in Other investments on the Consolidated Statements of Financial Position.

(e) Includes $124 million and $110 million at September 30, 2013 and December 31, 2012, respectively, of Other investments that are included in the Consolidated Statements of Financial Position in Other investments.

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. The fair values of the shares in these investments are based upon observable market prices for similar securities and, therefore, have been categorized as Level 2 in the fair value hierarchy.

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. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. The institutional mutual funds which hold exchange-traded equity or debt securities are valued based on the underlying securities, using quoted prices in actively traded markets. Non-exchange-traded fixed income securities are valued 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 determines that another price source is considered to be preferable. 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, DTE Energy selectively corroborates the fair value of securities by comparison of market-based price sources. Investment policies and procedures are determined by the Company's Trust Investments Department which reports to the Company's Vice President and Treasurer.

Derivative Assets and Liabilities

Derivative assets and liabilities are comprised of physical and financial derivative contracts, including futures, forwards, options and swaps that are both exchange-traded and over-the-counter traded contracts. Various inputs are used to value derivatives depending on the type of contract and availability of market data. Exchange-traded derivative contracts are valued using quoted prices in active markets. DTE Energy considers 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. DTE Energy monitors 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. DTE Energy has obtained an understanding of how these prices are derived. Additionally, DTE Energy selectively corroborates the fair value of its 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 Company has 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 our forward price curves has been assigned to our Risk Management Department, which is separate and distinct from the trading functions within the Company.

The following tables present the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for the three months and nine months ended September 30, 2013 and 2012:

	Three Months Ended September 30, 2013											Three Months Ended September 30, 2012
	Natural Gas			Electricity			Other		Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of June 30	$	(30	)	$	12		$	2	$	(16	)	$	2		$	50		$	5		$	57
Transfers into Level 3	—			—			—		—			—			—			—			—
Transfers out of Level 3	—			(1		)	—		(1		)	—			—			—			—
Total gains (losses):
Included in earnings	8			17			—		25			(43		)	12			1			(30		)
Recorded in regulatory assets/liabilities	—			—			3		3			—			—			7			7
Purchases, issuances and settlements:
Settlements	8			(23		)	—		(15		)	(3		)	(38		)	(7		)	(48		)
Net Assets (Liabilities) as of September 30	$	(14	)	$	5		$	5	$	(4	)	$	(44	)	$	24		$	6		$	(14	)
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 September 30, 2013 and 2012 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations	$	(8	)	$	8		$	—	$	—		$	(43	)	$	5		$	1		$	(37	)

	Nine Months Ended September 30, 2013												Nine Months Ended September 30, 2012
	Natural Gas			Electricity			Other			Total			Natural Gas			Electricity			Other			Total
	(In millions)
Net Assets (Liabilities) as of December 31	$	(38	)	$	23		$	2		$	(13	)	$	6		$	32		$	6		$	44
Transfers into Level 3	—			—			—			—			1			28			—			29
Transfers out of Level 3	(2		)	—			—			(2		)	(2		)	—			—			(2		)
Total gains (losses):
Included in earnings	(1		)	44			—			43			(38		)	53			—			15
Recorded in regulatory assets/liabilities	—			—			7			7			—			—			12			12
Purchases, issuances and settlements:
Purchases	—			(1		)	—			(1		)	—			1			—			1
Settlements	27			(61		)	(4		)	(38		)	(11		)	(90		)	(12		)	(113		)
Net Assets (Liabilities) as of September 30	$	(14	)	$	5		$	5		$	(4	)	$	(44	)	$	24		$	6		$	(14	)
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 September 30, 2013 and 2012 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations	$	(14	)	$	36		$	—		$	22		$	(39	)	$	43		$	—		$	4

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. The following table shows transfers between the levels of the fair value hierarchy for the three months and nine months ended September 30, 2013 and 2012:

	Three Months Ended September 30, 2013					Three Months Ended September 30, 2012
	Level 1	Level 2		Level 3		Level 1	Level 2		Level 3
	(In millions)
Transfers into Level 1 from	$ N/A	$	—	$	—	$ N/A	$	—	$	—
Transfers into Level 2 from	—	N/A		1		—	N/A		—
Transfers into Level 3 from	—	—		N/A		—	—		N/A

	Nine Months Ended September 30, 2013					Nine Months Ended September 30, 2012
	Level 1	Level 2		Level 3		Level 1	Level 2		Level 3
	(In millions)
Transfers into Level 1 from	$ N/A	$	—	$	—	$ N/A	$	—	$	—
Transfers into Level 2 from	—	N/A		2		—	N/A		2
Transfers into Level 3 from	—	—		N/A		—	29		N/A

The following table presents the unobservable inputs related to Level 3 assets and liabilities as of September 30, 2013:

	September 30, 2013
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	34	$	(48	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(1.10	)	—	$	4.22	/MMBtu	$	0.10	/MMBtu
Electricity	$	88	$	(83	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(8	)	—	$	15	/MWh	$	2	/MWh

The following table presents the unobservable inputs related to Level 3 assets and liabilities as of December 31, 2012:

	December 31, 2012
Commodity Contracts	Derivative Assets		Derivative Liabilities			Valuation Techniques	Unobservable Input	Range							Weighted Average
	(In millions)
Natural Gas	$	24	$	(62	)	Discounted Cash Flow	Forward basis price (per MMBtu)	$	(0.63	)	—	$	1.95	/MMBtu	$	0.03	/MMBtu
Electricity	$	134	$	(111	)	Discounted Cash Flow	Forward basis price (per MWh)	$	(2	)	—	$	16	/MWh	$	3	/MWh

The unobservable inputs used in the fair value measurement of the electricity and natural gas commodity types consist of inputs that are less observable due in part to lack of available broker quotes, supported by little, if any, market activity at the measurement date or are based on internally developed models. Certain basis prices (i.e. the difference in pricing between two locations) included in the valuation of natural gas and electricity contracts were deemed unobservable.

The inputs listed above would have a direct impact on the fair values of the above security types if they were adjusted. A significant increase (decrease) in the basis price would result in a higher (lower) fair value for long positions, with offsetting impacts to short positions.

Fair Value of Financial Instruments

The fair value of financial instruments included in the table below is determined by using quoted market prices when available. When quoted prices are not available, pricing services may be used to determine the fair value with reference to observable interest rate indexes. DTE Energy has obtained an understanding of how the fair values are derived. DTE Energy also selectively corroborates the fair value of its transactions by comparison of market-based price sources. Discounted cash flow analyses based upon estimated current borrowing rates are also used to determine fair value when quoted market prices are not available. The fair values of notes receivable, excluding capital leases, are 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 are determined by DTE Energy's Treasury Department which reports to the Company's Vice President and Treasurer.

The following table presents the carrying amount and fair value of financial instruments as of September 30, 2013 and December 31, 2012:

	September 30, 2013								December 31, 2012
	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	$	37	$	—	$	—	$	37	$	39	$	—	$	—	$	39
Dividends payable	$	116	$	116	$	—	$	—	$	107	$	107	$	—	$	—
Short-term borrowings	$	271	$	—	$	271	$	—	$	240	$	—	$	240	$	—
Long-term debt	$	7,729	$	436	$	7,067	$	738	$	7,813	$	507	$	7,453	$	933

See Note 4 for further fair value information on financial and derivative instruments.

Nuclear Decommissioning Trust Funds

DTE Electric has a legal obligation to decommission its nuclear power plants following the expiration of their operating licenses. This obligation is reflected as an asset retirement obligation on the 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.

The following table summarizes the fair value of the nuclear decommissioning trust fund assets:

	September 30, 2013		December 31, 2012
	(In millions)
Fermi 2	$	1,120	$	1,021
Fermi 1	3		3
Low level radioactive waste	16		13
Total	$	1,139	$	1,037

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

	Three Months Ended September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
	(In millions)
Realized gains	$	11		$	7		$	30		$	21
Realized losses	$	(11	)	$	(6	)	$	(25	)	$	(17	)
Proceeds from sales of securities	$	13		$	12		$	40		$	48

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. The following table sets forth the fair value and unrealized gains for the nuclear decommissioning trust funds:

	September 30, 2013				December 31, 2012
	Fair Value		Unrealized Gains		Fair Value		Unrealized Gains
	(In millions)
Equity securities	$	732	$	195	$	631	$	122
Debt securities	395		17		399		27
Cash and cash equivalents	12		—		7		—
	$	1,139	$	212	$	1,037	$	149

The debt securities at September 30, 2013 and December 31, 2012 had an average maturity of approximately 7 and 6 years, respectively. Securities held in the nuclear decommissioning trust funds are classified as available-for-sale. As DTE Electric does not have the ability to hold impaired investments for a period of time sufficient to allow for the anticipated recovery of market value, all unrealized losses are considered to be other-than-temporary impairments.

Unrealized losses incurred by the Fermi 2 trust are recognized as a Regulatory asset. DTE Electric recognized $38 million and $44 million of unrealized losses as Regulatory assets at September 30, 2013 and December 31, 2012, respectively. Since the decommissioning of Fermi 1 is funded by DTE Electric rather than through a regulatory recovery mechanism, there is no corresponding regulatory asset treatment. Therefore, unrealized losses incurred by the Fermi 1 trust are recognized in earnings immediately. There were no unrealized losses recognized in the three and nine months ended September 30, 2013 and September 30, 2012 for Fermi 1.

Other Securities

At September 30, 2013 and December 31, 2012, the securities were comprised primarily of money market and equity securities. During the three and nine months ended September 30, 2013 and September 30, 2012, no amounts of unrealized losses on available-for-sale securities were reclassified out of other comprehensive income and realized into net income for the periods. Gains related to trading securities held at September 30, 2013 and September 30, 2012 were $14 million and $11 million, respectively.

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Stock-Based Compensation (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Stock-based compensation expense	$ 18	$ 21	$ 81	$ 61
Tax benefit	7	8	31	23
Stock-based compensation cost capitalized in property, plant and equipment	$ 1	$ 1	$ 5	$ 3

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Organization and Basis of Presentation (Notes)

9 Months Ended

Sep. 30, 2013

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]

ORGANIZATION AND BASIS OF PRESENTATION

Corporate Structure

DTE Energy owns the following businesses:

• DTE Electric, an electric utility engaged in the generation, purchase, distribution and sale of electricity to approximately 2.1 million customers in southeastern Michigan;

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

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

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

References in this Report to “Company” or “DTE” are to DTE Energy and its subsidiaries, collectively.

Basis of Presentation

These Consolidated Financial Statements should be read in conjunction with the Notes to Consolidated Financial Statements included in the 2012 Annual Report on Form 10-K.

The accompanying Consolidated Financial Statements 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 Company’s estimates.

The Consolidated Financial Statements are unaudited, but in the Company's opinion include all adjustments necessary to present a fair statement of the results for the interim periods. All adjustments are of a normal recurring nature, except as otherwise disclosed in these Consolidated Financial Statements and Notes to Consolidated Financial Statements. Financial results for this interim period are not necessarily indicative of results that may be expected for any other interim period or for the fiscal year ending December 31, 2013.

Certain prior year balances were reclassified to match the current year's financial statement presentation.

Principles of Consolidation

The Company consolidates all majority-owned subsidiaries and investments in entities in which it has controlling influence. Non-majority owned investments are accounted for using the equity method when the Company is able to influence the operating policies of the investee. When the Company does not influence the operating policies of an investee, the cost method is used. These consolidated financial statements also reflect the Company's proportionate interests in certain jointly owned utility plants. The Company eliminates all intercompany balances and transactions.

The Company evaluates whether an entity is a VIE whenever reconsideration events occur. The Company consolidates VIEs for which it is the primary beneficiary. If the Company 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, the Company 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 Company performs ongoing reassessments of all VIEs to determine if the primary beneficiary status has changed.

Legal entities within the Company'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 the Company retaining operational and customer default risk. These entities generally are VIEs and consolidated when the Company is the primary beneficiary. In addition, we have interests in certain VIEs that we share control of all significant activities for those entities with our partners, and therefore are accounted for under the equity method.

The Company has variable interests in VIEs through certain of its long-term purchase contracts. As of September 30, 2013, the carrying amount of assets and liabilities in the Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase contracts are predominately related to working capital accounts and generally represent the amounts owed by the Company for the deliveries associated with the current billing cycle under the contracts. The Company has not provided any form of financial support associated with these long-term contracts. There is no significant potential exposure to loss as a result of its variable interests through these long-term purchase contracts.

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 performs servicing activities including billing and collecting surcharge revenue for Securitization. This entity is a VIE and is consolidated by the Company.

The maximum risk exposure for consolidated VIEs is reflected on the Company's Consolidated Statements of Financial Position. For non-consolidated VIEs, the maximum risk exposure is generally limited to its investment and amounts which it has guaranteed.

The following table summarizes the major balance sheet items for consolidated VIEs as of September 30, 2013 and December 31, 2012. All assets and liabilities of a consolidated VIE are presented where it has been determined that aconsolidated VIE has either (1) assets that can be used only to settle obligations of the VIE or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary. VIEs, in which the Company 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.

	September 30, 2013						December 31, 2012
	Securitization		Other		Total		Securitization		Other		Total
	(In millions)
ASSETS
Cash and cash equivalents	$	—	$	10	$	10	$	—	$	10	$	10
Restricted cash	44		7		51		102		7		109
Accounts receivable	39		17		56		34		7		41
Inventories	—		112		112		—		141		141
Other current assets	—		1		1		—		1		1
Property, plant and equipment	—		100		100		—		93		93
Securitized regulatory assets	280		—		280		413		—		413
Other assets	5		9		14		7		11		18
	$	368	$	256	$	624	$	556	$	270	$	826
LIABILITIES
Accounts payable and accrued current liabilities	$	2	$	35	$	37	$	11	$	14	$	25
Current portion long-term debt, including capital leases	196		9		205		177		8		185
Current regulatory liabilities	48		—		48		50		—		50
Other current liabilities	—		3		3		—		4		4
Mortgage bonds, notes and other	—		22		22		—		25		25
Securitization bonds	105		—		105		302		—		302
Capital lease obligations	—		7		7		—		11		11
Other long-term liabilities	8		3		11		7		2		9
	$	359	$	79	$	438	$	547	$	64	$	611

Amounts for non-consolidated VIEs as of September 30, 2013 and December 31, 2012 are as follows:

	September 30, 2013		December 31, 2012
	(In millions)
Other investments	$	138	$	130
Notes receivable	$	3	$	6

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Significant Accounting Policies (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Loss	$ (155)		$ (158)
Other Comprehensive Income Before Reclassifications	2		0
Amounts Reclassified From Accumulated Other Comprehensive Income	2		7
Other Comprehensive Income (Loss), Net of Tax	4	4	7	11
Accumulated Other Comprehensive Loss	(151)		(151)
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Loss	(4)		(4)
Other Comprehensive Income Before Reclassifications	0		0
Amounts Reclassified From Accumulated Other Comprehensive Income	0		0
Other Comprehensive Income (Loss), Net of Tax	0		0
Accumulated Other Comprehensive Loss	(4)		(4)
Accumulated Net Unrealized Investment Gain (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Loss	(8)		(8)
Other Comprehensive Income Before Reclassifications	1		1
Amounts Reclassified From Accumulated Other Comprehensive Income	0		0
Other Comprehensive Income (Loss), Net of Tax	1		1
Accumulated Other Comprehensive Loss	(7)		(7)
Accumulated Defined Benefit Plans Adjustment [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Loss	(143)		(148)
Other Comprehensive Income Before Reclassifications	0		0
Amounts Reclassified From Accumulated Other Comprehensive Income	2		7
Other Comprehensive Income (Loss), Net of Tax	2		7
Accumulated Other Comprehensive Loss	(141)		(141)
Accumulated Translation Adjustment [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Loss	0		2
Other Comprehensive Income Before Reclassifications	1		(1)
Amounts Reclassified From Accumulated Other Comprehensive Income	0		0
Other Comprehensive Income (Loss), Net of Tax	(1)		(1)
Accumulated Other Comprehensive Loss	$ 1		$ 1

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Financial and Other Derivative Instruments (Tables)

9 Months Ended

Sep. 30, 2013

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair value of derivative instruments

The following tables present the fair value of derivative instruments as of September 30, 2013 and December 31, 2012:

	September 30, 2013					December 31, 2012
	Derivative Assets		Derivative Liabilities			Derivative Assets		Derivative Liabilities
	(In millions)
Derivatives designated as hedging instruments:
Interest rate contracts	$	—	$	—		$	—	$	(1	)
Derivatives not designated as hedging instruments:
Commodity Contracts:
Natural Gas	$	483	$	(471	)	$	645	$	(661	)
Electricity	298		(287		)	360		(351		)
Other	62		(57		)	11		(7		)
Total derivatives not designated as hedging instruments:	$	843	$	(815	)	$	1,016	$	(1,019	)
Total derivatives:
Current	$	711	$	(668	)	$	862	$	(879	)
Noncurrent	132		(147		)	154		(141		)
Total derivatives	$	843	$	(815	)	$	1,016	$	(1,020	)

Netting Offsets of Derivative Assets and Liabilities [Table Text Block]

The following table presents the netting offsets of derivative assets and liabilities at September 30, 2013 and December 31, 2012:

	September 30, 2013									December 31, 2012
	Gross Amounts of Recognized Assets (Liabilities)			Gross Amounts Offset in the Consolidated Statements of Financial Position			Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position			Gross Amounts of Recognized Assets (Liabilities)			Gross Amounts Offset in the Consolidated Statements of Financial Position			Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position
	(In millions)
Derivative assets:
Commodity Contracts:
Natural Gas	$	483		$	(474	)	$	9		$	645		$	(605	)	$	40
Electricity	298			(216		)	82			360			(258		)	102
Other	62			(55		)	7			11			(6		)	5
Total derivative assets	$	843		$	(745	)	$	98		$	1,016		$	(869	)	$	147
Derivative liabilities:
Interest rate contracts	$	—		$	—		$	—		$	(1	)	$	—		$	(1	)
Commodity Contracts:
Natural Gas	(471		)	445			(26		)	(661		)	605			(56		)
Electricity	(287		)	236			(51		)	(351		)	258			(93		)
Other	(57		)	55			(2		)	(7		)	6			(1		)
Total derivative liabilities	$	(815	)	$	736		$	(79	)	$	(1,020	)	$	869		$	(151	)

Netting Offsets of Derivative Assets and Liabilities Reconciliation to the Statements of Financial Position [Table Text Block]

The following table presents the netting offsets of derivative assets and liabilities at September 30, 2013 and December 31, 2012:

	September 30, 2013												December 31, 2012
	Derivative Assets						Derivative Liabilities						Derivative Assets						Derivative Liabilities
	Current			Noncurrent			Current			Noncurrent			Current			Noncurrent			Current			Noncurrent
	(In millions)
Reconciliation of derivative instruments to Consolidated Statements of Financial Position:
Total fair value of derivatives	$	711		$	132		$	(668	)	$	(147	)	$	862		$	154		$	(879	)	$	(141	)
Counterparty netting	(610		)	(106		)	610			106			(754		)	(115		)	754			115
Collateral adjustment	(29		)	—			—			20			—			—			—			—
Total derivatives as reported	$	72		$	26		$	(58	)	$	(21	)	$	108		$	39		$	(125	)	$	(26	)

Gain (Loss) Recognized in Income on Derivative

The effect of derivatives not designated as hedging instruments on the Consolidated Statements of Operations for the three and nine months ended September 30, 2013 and 2012 is as follows:

	Location of Gain (Loss) Recognized in Income on Derivatives	Gain (Loss) Recognized in Income on Derivatives for the Three Months Ended September 30,						Gain (Loss) Recognized in Income on Derivatives for the Nine Months Ended September 30,
Derivatives not Designated as Hedging Instruments		2013			2012			2013			2012
		(In millions)
Foreign currency exchange contracts	Operating Revenue	$	—		$	(2	)	$	(1	)	$	(1	)
Commodity Contracts:
Natural Gas	Operating Revenue	1			(54		)	37			(51		)
Natural Gas	Fuel, purchased power and gas	(1		)	50			(33		)	45
Electricity	Operating Revenue	22			17			52			52
Other	Operating Revenue	1			1			1			12
Total		$	23		$	12		$	56		$	57

Volume of Commodity Contracts [Table Text Block]

The following represents the cumulative gross volume of derivative contracts outstanding as of September 30, 2013:

Commodity	Number of Units
Natural Gas (MMBtu)	683,113,433
Electricity (MWh)	59,672,654
Foreign Currency Exchange ($ CAD)	48,741,288
FTR (MWh)	13,005,024

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Earnings Per Share (Tables)

9 Months Ended

Sep. 30, 2013

Earnings Per Share [Abstract]

Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]

A reconciliation of both calculations is presented in the following table for the three months and nine months ended September 30:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2013		2012		2013		2012
	(In millions, except per share amounts)
Basic Earnings per Share
Net income attributable to DTE Energy Company	$	198	$	227	$	537	$	529
Average number of common shares outstanding	175		172		174		171
Weighted average net restricted shares outstanding	—		1		1		1
Dividends declared — common shares	$	115	$	106	$	337	$	307
Dividends declared — net restricted shares	1		1		1		2
Total distributed earnings	$	116	$	107	$	338	$	309
Net income less distributed earnings	$	82	$	120	$	199	$	220
Distributed (dividends per common share)	$	0.66	$	0.62	$	1.93	$	1.80
Undistributed	0.47		0.70		1.14		1.29
Total Basic Earnings per Common Share	$	1.13	$	1.32	$	3.07	$	3.09
Diluted Earnings per Share
Net income attributable to DTE Energy Company	$	198	$	227	$	537	$	529
Average number of common shares outstanding	176		172		175		171
Average incremental shares from assumed exercise of options	—		—		—		—
Common shares for dilutive calculation	176		172		175		171
Weighted average net restricted shares outstanding	—		1		1		1
Dividends declared — common shares	$	115	$	106	$	337	$	307
Dividends declared — net restricted shares	1		1		1		2
Total distributed earnings	$	116	$	107	$	338	$	309
Net income less distributed earnings	$	82	$	120	$	199	$	220
Distributed (dividends per common share)	$	0.66	$	0.62	$	1.93	$	1.80
Undistributed	0.47		0.69		1.14		1.28
Total Diluted Earnings per Common Share	$	1.13	$	1.31	$	3.07	$	3.08

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Retirement Benefits and Trusteed Assets (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Pension Plan, Defined Benefit [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service Cost	$ 22	$ 20	$ 71	$ 61
Interest Cost	49	51	144	153
Expected Return on Plan Assets	(67)	(61)	(200)	(183)
Amortization of Net Actuarial Losses	55	48	156	133
Amortization of Prior Service Cost (Credit)	0	0	0	0
Amortization of Net Transition Liability			0	0
Settlements			0	2
Net Periodic Benefit Cost	59	58	171	166
Other Postretirement Benefit Plan, Defined Benefit [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service Cost	9	15	37	51
Interest Cost	21	29	66	90
Expected Return on Plan Assets	(28)	(23)	(82)	(69)
Amortization of Net Actuarial Losses	16	21	48	60
Amortization of Prior Service Cost (Credit)	(36)	(6)	(95)	(20)
Amortization of Net Transition Liability			0	1
Settlements			0	0
Net Periodic Benefit Cost	$ (18)	$ 36	$ (26)	$ 113

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Segment Information (Tables)

9 Months Ended

Sep. 30, 2013

Segment Reporting [Abstract]

Reconciliation of Revenue from Segments to Consolidated [Table Text Block]

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

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
	(In millions)
Inter-segment Revenues
Electric	$	6		$	7		$	19		$	22
Gas	2			1			4			3
Gas Storage and Pipelines	(2		)	1			2			5
Power and Industrial Projects	231			225			621			608
Energy Trading	13			10			36			34
Corporate and Other	(8		)	(11		)	(23		)	(28		)
Discontinued Operations	—			1			—			1
	$	242		$	234		$	659		$	645

Financial data of the business segments follows:

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
	(In millions)
Operating Revenues
Electric	$	1,458		$	1,543		$	3,942		$	4,031
Gas	161			160			1,013			883
Gas Storage and Pipelines	34			21			92			73
Power and Industrial Projects	512			477			1,431			1,375
Energy Trading	463			223			1,307			723
Corporate & Other	1			—			2			2
Reconciliation & Eliminations	(242		)	(234		)	(659		)	(645		)
Total	$	2,387		$	2,190		$	7,128		$	6,442

Reconciliation of Operating Profit (Loss) from Segments to Consolidated [Table Text Block]

Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	179		$	194		$	383		$	417
Gas	(13		)	4			91			60
Gas Storage and Pipelines	16			14			49			48
Power and Industrial Projects	27			22			46			40
Energy Trading	(6		)	1			(1		)	3
Corporate & Other	(5		)	(9		)	(31		)	(39		)
Discontinued operations	—			1			—			—
Net Income Attributable to DTE Energy	$	198		$	227		$	537		$	529

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Commitments and Contingencies (Details Textuals) (USD $)	9 Months Ended			9 Months Ended			9 Months Ended		9 Months Ended			12 Months Ended
	Sep. 30, 2013	Aug. 31, 2013	Dec. 31, 2010 dte_instances	Sep. 30, 2013 Electric [Member] facilities kWh dte_instances	Dec. 31, 2012 Electric [Member]	Aug. 31, 2012 Electric [Member]	Sep. 30, 2013 Gas [Member] facilities	Dec. 31, 2012 Gas [Member]	Sep. 30, 2013 Synthetic Fuel [Member]	Sep. 30, 2013 Emissions [Member]	Sep. 30, 2013 Other Guarantees [Member]	Dec. 31, 2011 Eight Year [Member]
Loss Contingencies [Line Items]
Environmental Capital Expenditures Through Current Year				$ 1,900,000,000
Environmental Capital Expenditures in Current Year				190,000,000
Environmental Capital Expenditures In Future Years				1,800,000,000
EPA is Alleging Detroit Edison Power Plants Violated New Source Performance Standards				5
Number of NOVs/FOVs currently being discussed with the EPA				2
Sierra Club is Alleging DTE Electric Coal Fired Power Plants Violated the Clean Air Act				4
Exceedances of Opacity Standard				1,499
Period of excess opacity of air emissions at alleged facilities	6 minutes
2004 EPA proposed compliance timeline in years												8 years
Number of Former MGP Sites				3			15
Accrual for Environmental Loss Contingencies, Gross				9,000,000	9,000,000		29,000,000	29,000,000
Number of Options to Regulate Coal Ash Residue				2
Period Gas Utility Can Amortize MGP Costs							10 years
Number of NOVs			2
Possible Environmental Capital Expenditures to Comply with Requirements	7,000,000
EPA Sulfur Dioxide Ambient Air Quality Standard	1 hour
Waiting Period of Policy	P12W
Insurance Coverage for Extra ExpenseWhen to Necessitate Power Plant when Unavailable				490,000,000
Period of Coverage of Policy for Extra Expenses				3 years
Primary Coverage				500,000,000
Coverage for Stabilization Decontamination Debris Removal Repair and Replacement of Property and Decommissioning				2,250,000,000
Combined Coverage Limit for Total Property Damage				2,750,000,000
Insurance Deductible for Nuclear Power Plant				1,000,000
Total Limit for Property Damage for Non-Nuclear Events				1,800,000,000
Limit for Property Damage for Non-Nuclear Events Aggregate of Extra Expenses				327,000,000
Limit for Property Damage for Non-Nuclear Events Aggregate of Extra Expenses of Period				2 years
Time Period for TRIA Insurance After the First Loss from Terrorism				1 year
NEIL Policies Against Terrorism Loss				3,200,000,000
Amount per Event Loss Associated with Nuclear Power Plants				34,000,000
Maintenance of Public Liability Insurance for Nuclear Power Plants				375,000,000
Aggregate Limit of Liabilities Arises From Terrorist Act Outside Scope of Trials Subject to One Industry				300,000,000
Deferred Premium Charged Leviied Against Each Licensed Nuclear Facility				127,300,000
Limit Deferred Premium Charges Per Year				19,000,000
Company Obligated to Pay DOE Fee of Fermi 2 Electricity Generated and Sold				1
Settlement Provided for Delay-Related Costs						48,000,000
Days Obligations will Survive After Expiration of All Applicable Statutes of Limiations									90 days	90 days
Guarantor Obligations, Maximum Exposure, Undiscounted									1,200,000,000	125,000,000	60,000,000
Performance Bonds Outstanding	41,000,000
Long-term Purchase Commitment, Amount	6,200,000,000
Purchase Obligation, Future Minimum Payments, Remainder of Fiscal Year	2,100,000,000
Bankruptcy Claims, Accounts Receivable under Review by Management		$ 20,000,000

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Financial and Other Derivative Instruments Financial and Other Derivative Instruments (Details 2) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Derivative [Line Items]
Derivative Assets, Current	$ 72	$ 108
Derivative Assets, Noncurrent	26	39
Derivative Liabilities, Current	(58)	(125)
Derivative Liabilities, Noncurrent	(21)	(26)
Derivative Asset [Member]
Derivative [Line Items]
Derivative Assets, Current	711	862
Derivative Assets, Noncurrent	132	154
Derivative Liabilities [Member]
Derivative [Line Items]
Derivative Liabilities, Current	(668)	(879)
Derivative Liabilities, Noncurrent	(147)	(141)
Counterparty Netting [Member]
Derivative [Line Items]
Derivative Assets, Current	(610)	(754)
Derivative Assets, Noncurrent	(106)	(115)
Derivative Liabilities, Current	(610)	(754)
Derivative Liabilities, Noncurrent	(106)	(115)
Collateral Adjustment [Member]
Derivative [Line Items]
Derivative Assets, Current	(29)	0
Derivative Assets, Noncurrent	0	0
Derivative Liabilities, Current	0	0
Derivative Liabilities, Noncurrent	(20)	0
Derivative [Member]
Derivative [Line Items]
Derivative Assets, Current	72	108
Derivative Assets, Noncurrent	26	39
Derivative Liabilities, Current	(58)	(125)
Derivative Liabilities, Noncurrent	$ (21)	$ (26)

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Fair Value (Details 6) (Nuclear Decommissioning Trust Fund [Member], USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Nuclear Decommissioning Trust Fund [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Realized gains	$ 11	$ 7	$ 30	$ 21
Realized losses	(11)	(6)	(25)	(17)
Proceeds from sales of securities	$ 13	$ 12	$ 40	$ 48

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Fair Value (Details 1) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis
Beginning Balance	$ (16)	$ 57	$ (13)	$ 44
Transfers into Level 3	0	0	0	29
Transfer out of Level 3	1	0	2	(2)
Total gains (losses): [Abstract]
Included in earnings	25	(30)	43	15
Recorded in regulatory assets/liabilities	3	7	7	12
Purchases issuances and settlements [Abstract]
Purchases			(1)	1
Settlements	(15)	(48)	(38)	(113)
Ending Balance	(4)	(14)	(4)	(14)
The amount of total gains (losses) included in net income attributed to the change in unrealized gains or losses related to assets still held at the end of the period	0	(37)	22	4
Natural Gas Commodity Contract [Member]
Fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis
Beginning Balance	(30)	2	(38)	6
Transfers into Level 3	0	0	0	1
Transfer out of Level 3	0	0	2	(2)
Total gains (losses): [Abstract]
Included in earnings	8	(43)	(1)	(38)
Recorded in regulatory assets/liabilities	0	0	0	0
Purchases issuances and settlements [Abstract]
Purchases			0	0
Settlements	8	(3)	27	(11)
Ending Balance	(14)	(44)	(14)	(44)
The amount of total gains (losses) included in net income attributed to the change in unrealized gains or losses related to assets still held at the end of the period	(8)	(43)	(14)	(39)
Electricity [Member]
Fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis
Beginning Balance	12	50	23	32
Transfers into Level 3	0	0	0	28
Transfer out of Level 3	1	0	0	0
Total gains (losses): [Abstract]
Included in earnings	17	12	44	53
Recorded in regulatory assets/liabilities	0	0	0	0
Purchases issuances and settlements [Abstract]
Purchases			(1)	1
Settlements	(23)	(38)	(61)	(90)
Ending Balance	5	24	5	24
The amount of total gains (losses) included in net income attributed to the change in unrealized gains or losses related to assets still held at the end of the period	8	5	36	43
Other Commodity Contract [Member]
Fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis
Beginning Balance	2	5	2	6
Transfers into Level 3	0	0	0	0
Transfer out of Level 3	0	0	0	0
Total gains (losses): [Abstract]
Included in earnings	0	1	0	0
Recorded in regulatory assets/liabilities	3	7	7	12
Purchases issuances and settlements [Abstract]
Purchases			0	0
Settlements	0	(7)	(4)	(12)
Ending Balance	5	6	5	6
The amount of total gains (losses) included in net income attributed to the change in unrealized gains or losses related to assets still held at the end of the period	$ 0	$ 1	$ 0	$ 0

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Consolidated Statements of Comprehensive Income (Unaudited) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Statement of Income and Comprehensive Income [Abstract]
Net Income	$ 200	$ 230	$ 542	$ 535
Benefit obligations:
Benefit obligations, net of tax	(2)	(3)	(7)	(9)
Net unrealized gains (losses) on derivatives:
Net unrealized gains on investments during the period, net of taxes of $1, $—, $1 and $—	1	0	1	1
Foreign currency translation, net of taxes of $—, $1, $(1) and $1	1	1	(1)	1
Other Comprehensive income	4	4	7	11
Comprehensive income	204	234	549	546
Less: Comprehensive income attributable to noncontrolling interests	2	3	5	6
Comprehensive income attributable to DTE Energy Company	$ 202	$ 231	$ 544	$ 540

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Asset Retirement Obligations (Notes)

9 Months Ended

Sep. 30, 2013

Asset Retirement Obligation [Abstract]

Asset Retirement Obligations

ASSET RETIREMENT OBLIGATIONS

A reconciliation of the asset retirement obligations for the nine months ended September 30, 2013 follows:

	(In millions)
Asset retirement obligations at December 31, 2012	$	1,719
Accretion	79
Liabilities incurred	1
Liabilities settled	(12		)
Revision in estimated cash flows	13
Asset retirement obligations at September 30, 2013	$	1,800

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Consolidated Statements of Financial Position (Unaudited) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Current Assets
Cash and cash equivalents	$ 71	$ 65
Restricted cash, principally Securitization	64	122
Accounts receivable (less allowance for doubtful accounts of $67 and $62, respectively)
Customer	1,239	1,336
Other	81	126
Inventories
Fuel and gas	467	527
Materials and supplies	258	234
Deferred income taxes	0	21
Derivative assets	72	108
Regulatory assets	49	182
Other	248	194
Total Current Assets	2,549	2,915
Investments
Nuclear decommissioning trust funds	1,139	1,037
Other	584	554
Total Investments	1,723	1,591
Property
Property, plant and equipment	24,795	23,631
Less accumulated depreciation, depletion and amortization	(9,284)	(8,947)
Property, plant and equipment, net	15,511	14,684
Other Assets
Goodwill	2,018	2,018
Regulatory assets	3,700	4,235
Securitized regulatory assets	280	413
Intangible Assets	122	135
Notes receivable	104	112
Derivative assets	26	39
Other	198	197
Total Noncurrent Assets	6,448	7,149
Total Assets	26,231	26,339
Current Liabilities
Accounts payable	866	848
Accrued interest	114	93
Dividends payable	116	107
Short-term borrowings	271	240
Current portion long-term debt, including capital leases	896	817
Derivative liabilities	58	125
Regulatory liabilities	230	89
Other	457	449
Total Current Liabilities	3,008	2,768
Long-Term Debt (net of current portion)
Mortgage bonds, notes and other	6,253	6,220
Securitization bonds	105	302
Junior subordinated debentures	480	480
Capital lease obligations	8	12
Total Long-Term Debt (net of current portion)	6,846	7,014
Other Liabilities
Deferred income taxes	3,290	3,191
Regulatory liabilities	907	1,031
Asset retirement obligations	1,800	1,719
Unamortized investment tax credit	49	56
Derivative liabilities	21	26
Accrued pension liability	1,254	1,498
Accrued postretirement liability	684	1,160
Nuclear decommissioning	172	159
Other	290	306
Total Noncurrent Liabilities	8,467	9,146
Equity
Common stock, without par value, 400,000,000 shares authorized, 176,797,248 and 172,351,680 shares issued and outstanding, respectively	3,885	3,587
Retained earnings	4,142	3,944
Accumulated other comprehensive loss	(151)	(158)
Total DTE Energy Company Equity	7,876	7,373
Noncontrolling interests	34	38
Total Equity	7,910	7,411
Total Liabilities and Equity	$ 26,231	$ 26,339

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Financial and Other Derivative Instruments (Details Textuals) (USD $)			3 Months Ended	9 Months Ended
	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013 FTR [Member]	Sep. 30, 2013 FTR [Member]
Derivative [Line Items]
Interest Rate Cash Flow Hedge Gain (Loss) to be Reclassified During Next 12 Months, Net	$ 1,000,000
Letters of Credit Outstanding, Amount	21,000,000	63,000,000
Cash Collateral Posted Net of Cash Collateral Received	30,000,000
Collateral Already Posted, Aggregate Fair Value		20,000,000
Cash Collateral Paid or Received for Derivative Assets	29,000,000	0
Cash Collateral Paid or Received for Derivative Liabilities	20,000,000
Cash Collateral Received	24,000,000	24,000,000
Cash Collateral Paid	3,000,000	4,000,000
Effect of Derivative Instruments Recoverable Through PSCR Mechanism			3,000,000	7,000,000
Value of Transactions Company Would Have Been Exposed to if Credit Rating Below Investment Grade	$ 327,000,000

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Consolidated Statements of Operations (Unaudited) (USD $) In Millions, except Per Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Operating Revenues	$ 2,387	$ 2,190	$ 7,128	$ 6,442
Operating Expenses
Fuel, purchased power and gas	967	761	2,931	2,347
Operation and maintenance	728	687	2,168	2,111
Depreciation, depletion and amortization	284	259	811	730
Taxes other than income	84	78	262	252
Asset (gains) and losses, reserves and impairments, net	(5)	(1)	(6)	(10)
Total operating expenses	2,058	1,784	6,166	5,430
Operating Income	329	406	962	1,012
Other (Income) and Deductions
Interest expense	106	109	327	331
Interest income	(2)	(2)	(7)	(7)
Other income	(58)	(47)	(148)	(125)
Other expenses	7	9	23	27
Total Other (Income) and Deductions	(53)	(69)	(195)	(226)
Income Before Income Taxes	276	337	767	786
Income Tax Expense	76	108	225	251
Income from Continuing Operations	200	229	542	535
Loss from Discontinued Operations, net of tax	0	1	0	0
Net Income	200	230	542	535
Less: Net Income Attributable to Noncontrolling Interests	2	3	5	6
Net Income Attributable to DTE Energy Company	$ 198	$ 227	$ 537	$ 529
Basic Earnings per Common Share
Total Basic Earnings per Common Share	$ 1.13	$ 1.32	$ 3.07	$ 3.09
Income from continuing operations	$ 1.13	$ 1.31	$ 3.07	$ 3.09
Loss from discontinued operations, net of tax	$ 0.00	$ 0.01	$ 0.00	$ 0.00
Diluted Earnings per Common Share
Total Diluted Earnings per Common Share	$ 1.13	$ 1.31	$ 3.07	$ 3.08
Income from continuing operations	$ 1.13	$ 1.30	$ 3.07	$ 3.08
Loss from discontinued operations, net of tax	$ 0.00	$ 0.01	$ 0.00	$ 0.00
Weighted Average Common Shares Outstanding
Basic	175	172	174	171
Diluted	176	172	175	171
Dividends Declared per Common Share	$ 0.66	$ 0.62	$ 1.93	$ 1.80

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Fair Value (Details 7) (USD $) In Millions, unless otherwise specified	9 Months Ended	12 Months Ended
	Sep. 30, 2013	Dec. 31, 2012
Fair Value, Option, Quantitative Disclosures [Line Items]
Nuclear decommissioning trusts	$ 1,139	$ 1,037
Unrealized Gains	212	149
Nuclear Decommissioning Trust Fund [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Cash and Cash Equivalents	12	7
Nuclear Decommissioning Trust Fund [Member] | Equity securities [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Equity securities	732	631
Unrealized Gains	195	122
Nuclear Decommissioning Trust Fund [Member] | Debt securities [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Debt securities	395	399
Unrealized Gains	17	27
Nuclear Decommissioning Trust Fund [Member] | Cash and cash equivalents [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Unrealized Gains	$ 0	$ 0

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Segment Information (Details Textuals)	Sep. 30, 2013 customers
Entity Information [Line Items]
Number of Electric Customers	2,100,000
Number of Gas Customers	1,200,000
Number of Citizens Gas Customers	17,000

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Stock-Based Compensation Stock-Based Compensation (Details 2) (USD $)	9 Months Ended
	Sep. 30, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted Stock Award Activity Forfeitures	(10,370)
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number	597,648
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	127,785
Restricted Stock Award Activity Forfeitures	(5,621)
Restricted Stock Award Activity Vested and Issued	(218,600)
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number	501,212
Weighted Average Grant Date Fair Value Per Share Balance	$ 48.33
Weighted Average Grant Date Fair Value, Grants	$ 64.72
Weighted Average Grant Date Fair Value, Forfeitures	$ 53.53
Weighted Average Fair Value Per Share, Vested and issued	$ 45.39
Weighted Average Grant Date Fair Value Per Share Balance	$ 53.71
Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number	1,634,364
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	549,360
Restricted Stock Award Activity Forfeitures	(36,168)
Share Based Compensation Arrangements Other than options payout in period	(548,624)
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number	1,598,932

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Discontinued Operations Discontinued Operations (Tables)

9 Months Ended

Sep. 30, 2013

Discontinued Operations and Disposal Groups [Abstract]

Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]

	Three Months Ended		Nine Months Ended
	September 30, 2012		September 30, 2012
	(In millions)
Operating Revenues	$	16	$	38
Operation and Maintenance	6		16
Depreciation, Depletion and Amortization	6		17
Taxes Other Than Income	1		2
Operating Income	3		3
Other (Income) and Deductions	1		4
Income Tax Expense (Benefit)	1		(1		)
Net Income Attributable to DTE Energy Company	$	1	$	—

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Segment Information (Notes)

9 Months Ended

Sep. 30, 2013

Segment Reporting [Abstract]

Segment Information

SEGMENT AND RELATED INFORMATION

The Company sets strategic goals, allocates resources and evaluates performance based on the following structure:

Electric segment consists principally of DTE Electric, which is engaged in the generation, purchase, distribution and sale of electricity to approximately 2.1 million residential, commercial and industrial customers in southeastern Michigan.

Gas segment consists of DTE Gas and Citizens.  DTE Gas is engaged in the purchase, storage, transportation, distribution and sale of natural gas to approximately 1.2 million residential, commercial and industrial customers throughout Michigan and the sale of storage and transportation capacity. Citizens distributes natural gas in Adrian, Michigan to approximately 17,000 customers.

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

Power and Industrial Projects is comprised primarily of projects that deliver energy and utility-type products and services to industrial, commercial and institutional customers; produce reduced emissions fuel (REF) and sell electricity from biomass-fired energy projects.

Energy Trading consists of energy marketing and trading operations.

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

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

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

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
	(In millions)
Inter-segment Revenues
Electric	$	6		$	7		$	19		$	22
Gas	2			1			4			3
Gas Storage and Pipelines	(2		)	1			2			5
Power and Industrial Projects	231			225			621			608
Energy Trading	13			10			36			34
Corporate and Other	(8		)	(11		)	(23		)	(28		)
Discontinued Operations	—			1			—			1
	$	242		$	234		$	659		$	645

Financial data of the business segments follows:

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
	(In millions)
Operating Revenues
Electric	$	1,458		$	1,543		$	3,942		$	4,031
Gas	161			160			1,013			883
Gas Storage and Pipelines	34			21			92			73
Power and Industrial Projects	512			477			1,431			1,375
Energy Trading	463			223			1,307			723
Corporate & Other	1			—			2			2
Reconciliation & Eliminations	(242		)	(234		)	(659		)	(645		)
Total	$	2,387		$	2,190		$	7,128		$	6,442

Net Income (Loss) Attributable to DTE Energy by Segment:
Electric	$	179		$	194		$	383		$	417
Gas	(13		)	4			91			60
Gas Storage and Pipelines	16			14			49			48
Power and Industrial Projects	27			22			46			40
Energy Trading	(6		)	1			(1		)	3
Corporate & Other	(5		)	(9		)	(31		)	(39		)
Discontinued operations	—			1			—			—
Net Income Attributable to DTE Energy	$	198		$	227		$	537		$	529

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Fair Value (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Assets [Abstract]
Nuclear decommissioning trusts	$ (1,139)	$ (1,037)
Liabilities [Abstract]
Derivative Liabilities, Current	58	125
Derivative Liabilities, Noncurrent	21	26
Fair Value, Measurements, Recurring [Member]
Assets [Abstract]
Cash and Cash Equivalents, Fair Value Disclosure	(68)	(123)
Nuclear decommissioning trusts	(1,139)	(1,037)
Other investments	(124)	(110)
Derivative assets [Abstract]
Derivative Assets	(98)	(147)
Assets, Fair Value Disclosure	(1,429)	(1,417)
Liabilities [Abstract]
Interest Rate Derivative Liabilities, at Fair Value	0	1
Derivative Liabilities	79	151
Financial and Nonfinancial Liabilities, Fair Value Disclosure	1,350	1,266
Fair Value, Measurements, Recurring [Member] | Natural Gas Commodity Contract [Member]
Derivative assets [Abstract]
Derivative Assets	(9)	(40)
Liabilities [Abstract]
Derivative Liabilities	26	56
Fair Value, Measurements, Recurring [Member] | Electricity [Member]
Derivative assets [Abstract]
Derivative Assets	(82)	(102)
Liabilities [Abstract]
Derivative Liabilities	51	93
Fair Value, Measurements, Recurring [Member] | Other Commodity Contract [Member]
Derivative assets [Abstract]
Derivative Assets	(7)	(5)
Liabilities [Abstract]
Derivative Liabilities	2	1
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Assets [Abstract]
Cash and Cash Equivalents, Fair Value Disclosure	0	0
Nuclear decommissioning trusts	(757)	(694)
Other investments	(76)	(66)
Derivative assets [Abstract]
Derivative Assets	(436)	(561)
Assets, Fair Value Disclosure	(1,269)	(1,321)
Liabilities [Abstract]
Interest Rate Derivative Liabilities, at Fair Value	0	0
Derivative Liabilities	426	532
Financial and Nonfinancial Liabilities, Fair Value Disclosure	843	789
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Natural Gas Commodity Contract [Member]
Derivative assets [Abstract]
Derivative Assets	(388)	(555)
Liabilities [Abstract]
Derivative Liabilities	374	526
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Electricity [Member]
Derivative assets [Abstract]
Derivative Assets	0	0
Liabilities [Abstract]
Derivative Liabilities	0	0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Other Commodity Contract [Member]
Derivative assets [Abstract]
Derivative Assets	(48)	(6)
Liabilities [Abstract]
Derivative Liabilities	52	6
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Assets [Abstract]
Cash and Cash Equivalents, Fair Value Disclosure	(68)	(123)
Nuclear decommissioning trusts	(382)	(343)
Other investments	(48)	(44)
Derivative assets [Abstract]
Derivative Assets	(280)	(295)
Assets, Fair Value Disclosure	(778)	(805)
Liabilities [Abstract]
Interest Rate Derivative Liabilities, at Fair Value	0	1
Derivative Liabilities	258	315
Financial and Nonfinancial Liabilities, Fair Value Disclosure	520	490
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Natural Gas Commodity Contract [Member]
Derivative assets [Abstract]
Derivative Assets	(61)	(66)
Liabilities [Abstract]
Derivative Liabilities	49	73
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Electricity [Member]
Derivative assets [Abstract]
Derivative Assets	(210)	(226)
Liabilities [Abstract]
Derivative Liabilities	204	240
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Other Commodity Contract [Member]
Derivative assets [Abstract]
Derivative Assets	(9)	(3)
Liabilities [Abstract]
Derivative Liabilities	5	1
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Assets [Abstract]
Cash and Cash Equivalents, Fair Value Disclosure	0	0
Nuclear decommissioning trusts	0	0
Other investments	0	0
Derivative assets [Abstract]
Derivative Assets	(127)	(160)
Assets, Fair Value Disclosure	(127)	(160)
Liabilities [Abstract]
Interest Rate Derivative Liabilities, at Fair Value	0	0
Derivative Liabilities	131	173
Financial and Nonfinancial Liabilities, Fair Value Disclosure	(4)	(13)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Natural Gas Commodity Contract [Member]
Derivative assets [Abstract]
Derivative Assets	(34)	(24)
Liabilities [Abstract]
Derivative Liabilities	48	62
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Electricity [Member]
Derivative assets [Abstract]
Derivative Assets	(88)	(134)
Liabilities [Abstract]
Derivative Liabilities	83	111
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Other Commodity Contract [Member]
Derivative assets [Abstract]
Derivative Assets	(5)	(2)
Liabilities [Abstract]
Derivative Liabilities	0	0
Fair Value, Measurements, Recurring [Member] | Netting [Member]
Assets [Abstract]
Cash and Cash Equivalents, Fair Value Disclosure	0	0
Nuclear decommissioning trusts	0	0
Other investments	0	0
Derivative assets [Abstract]
Derivative Assets	(745)	(869)
Assets, Fair Value Disclosure	(745)	(869)
Liabilities [Abstract]
Interest Rate Derivative Liabilities, at Fair Value	0	0
Derivative Liabilities	736	869
Financial and Nonfinancial Liabilities, Fair Value Disclosure	9	0
Fair Value, Measurements, Recurring [Member] | Netting [Member] | Natural Gas Commodity Contract [Member]
Derivative assets [Abstract]
Derivative Assets	(474)	(605)
Liabilities [Abstract]
Derivative Liabilities	445	605
Fair Value, Measurements, Recurring [Member] | Netting [Member] | Electricity [Member]
Derivative assets [Abstract]
Derivative Assets	(216)	(258)
Liabilities [Abstract]
Derivative Liabilities	236	258
Fair Value, Measurements, Recurring [Member] | Netting [Member] | Other Commodity Contract [Member]
Derivative assets [Abstract]
Derivative Assets	(55)	(6)
Liabilities [Abstract]
Derivative Liabilities	55	6
Current Asset [Member] | Fair Value, Measurements, Recurring [Member]
Derivative assets [Abstract]
Assets, Fair Value Disclosure	(140)	(231)
Current Asset [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Derivative assets [Abstract]
Assets, Fair Value Disclosure	(400)	(493)
Current Asset [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Derivative assets [Abstract]
Assets, Fair Value Disclosure	(285)	(372)
Current Asset [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Derivative assets [Abstract]
Assets, Fair Value Disclosure	(94)	(120)
Current Asset [Member] | Fair Value, Measurements, Recurring [Member] | Netting [Member]
Derivative assets [Abstract]
Assets, Fair Value Disclosure	(639)	(754)
Non Current Asset [Member] | Fair Value, Measurements, Recurring [Member]
Derivative assets [Abstract]
Assets, Fair Value Disclosure	(1,289)	(1,186)
Non Current Asset [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Derivative assets [Abstract]
Assets, Fair Value Disclosure	(869)	(828)
Non Current Asset [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Derivative assets [Abstract]
Assets, Fair Value Disclosure	(493)	(433)
Non Current Asset [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Derivative assets [Abstract]
Assets, Fair Value Disclosure	(33)	(40)
Non Current Asset [Member] | Fair Value, Measurements, Recurring [Member] | Netting [Member]
Derivative assets [Abstract]
Assets, Fair Value Disclosure	(106)	(115)
Current Liability [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities [Abstract]
Derivative Liabilities, Current	58	125
Current Liability [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Liabilities [Abstract]
Derivative Liabilities, Current	379	466
Current Liability [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Liabilities [Abstract]
Derivative Liabilities, Current	189	269
Current Liability [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Liabilities [Abstract]
Derivative Liabilities, Current	100	144
Current Liability [Member] | Fair Value, Measurements, Recurring [Member] | Netting [Member]
Liabilities [Abstract]
Derivative Liabilities, Current	610	754
Noncurrent Liability [Member] | Fair Value, Measurements, Recurring [Member]
Liabilities [Abstract]
Derivative Liabilities, Noncurrent	21	26
Noncurrent Liability [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Liabilities [Abstract]
Derivative Liabilities, Noncurrent	47	66
Noncurrent Liability [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Liabilities [Abstract]
Derivative Liabilities, Noncurrent	69	46
Noncurrent Liability [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Liabilities [Abstract]
Derivative Liabilities, Noncurrent	31	29
Noncurrent Liability [Member] | Fair Value, Measurements, Recurring [Member] | Netting [Member]
Liabilities [Abstract]
Derivative Liabilities, Noncurrent	126	115
Other Investments [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Assets [Abstract]
Cash and Cash Equivalents, Fair Value Disclosure	(17)	(14)
Other Investments [Member] | Equity [Member] | Fair Value, Measurements, Recurring [Member]
Assets [Abstract]
Other investments	$ (124)	$ (110)

XML

Segment Information (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	$ 2,387	$ 2,190	$ 7,128	$ 6,442
Operating Segments [Member] | Electric [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	1,458	1,543	3,942	4,031
Operating Segments [Member] | Gas [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	161	160	1,013	883
Operating Segments [Member] | Gas Storage and Pipelines [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	34	21	92	73
Operating Segments [Member] | Power and Industrial Projects [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	512	477	1,431	1,375
Operating Segments [Member] | Energy Trading [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	463	223	1,307	723
Operating Segments [Member] | Corporate and Other [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Operating Revenues	1	0	2	2
Intersegment Eliminations [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Inter-segment Revenues	242	234	659	645
Intersegment Eliminations [Member] | Electric [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Inter-segment Revenues	6	7	19	22
Intersegment Eliminations [Member] | Gas [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Inter-segment Revenues	2	1	4	3
Intersegment Eliminations [Member] | Gas Storage and Pipelines [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Inter-segment Revenues	(2)	1	2	5
Intersegment Eliminations [Member] | Power and Industrial Projects [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Inter-segment Revenues	231	225	621	608
Intersegment Eliminations [Member] | Energy Trading [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Inter-segment Revenues	13	10	36	34
Intersegment Eliminations [Member] | Corporate and Other [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Inter-segment Revenues	(8)	(11)	(23)	(28)
Intersegment Eliminations [Member] | Discontinued Operations [Member]
Segment Reporting, Revenue Reconciling Item [Line Items]
Inter-segment Revenues	$ 0	$ 1	$ 0	$ 1

XML

Financial and Other Derivative Instruments Financial and Other Derivative Instruments (Details 1) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Netting Offsets of Derivative Assets and Liabilities [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 843	$ 1,016
Gross Amounts Offset in the Statements of Financial Position	(745)	(869)
Net Amounts of Assets Presented in the Statements of Financial Position	98	147
Fair Value Gross Amounts of Recognized Liabilities	(815)	(1,020)
Gross Amounts Offset in the Statement of Financial Position	736	869
Net Amounts of Liabilities Presented in the Statements of Financial Position	(79)	(151)
Natural Gas Commodity Contract [Member]
Netting Offsets of Derivative Assets and Liabilities [Line Items]
Derivative Asset, Fair Value, Gross Asset	483	645
Gross Amounts Offset in the Statements of Financial Position	(474)	(605)
Net Amounts of Assets Presented in the Statements of Financial Position	9	40
Fair Value Gross Amounts of Recognized Liabilities	(471)	(661)
Gross Amounts Offset in the Statement of Financial Position	445	605
Net Amounts of Liabilities Presented in the Statements of Financial Position	(26)	(56)
Electricity [Member]
Netting Offsets of Derivative Assets and Liabilities [Line Items]
Derivative Asset, Fair Value, Gross Asset	298	360
Gross Amounts Offset in the Statements of Financial Position	(216)	(258)
Net Amounts of Assets Presented in the Statements of Financial Position	82	102
Fair Value Gross Amounts of Recognized Liabilities	(287)	(351)
Gross Amounts Offset in the Statement of Financial Position	236	258
Net Amounts of Liabilities Presented in the Statements of Financial Position	(51)	(93)
Other Contract [Member]
Netting Offsets of Derivative Assets and Liabilities [Line Items]
Derivative Asset, Fair Value, Gross Asset	62	11
Gross Amounts Offset in the Statements of Financial Position	(55)	(6)
Net Amounts of Assets Presented in the Statements of Financial Position	7	5
Fair Value Gross Amounts of Recognized Liabilities	(57)	(7)
Gross Amounts Offset in the Statement of Financial Position	55	6
Net Amounts of Liabilities Presented in the Statements of Financial Position	(2)	(1)
Interest rate contracts [Member]
Netting Offsets of Derivative Assets and Liabilities [Line Items]
Fair Value Gross Amounts of Recognized Liabilities	0	(1)
Gross Amounts Offset in the Statement of Financial Position	0	0
Net Amounts of Liabilities Presented in the Statements of Financial Position	$ 0	$ (1)

XML

Long-Term Debt (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Mar. 31, 2013
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 775
Electric [Member] | Mortgages [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.65%	4.00%
Debt Instrument, Face Amount	$ 400	$ 375

XML

Organization and Basis of Presentation (Details 1) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Variable Interest Entity, Nonconsolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Notes receivable	$ 104	$ 112
Unconsolidated Variable Interest Entity [Member]
Variable Interest Entity, Nonconsolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]
Other investments	138	130
Notes receivable	$ 3	$ 6

XML

Retirement Benefits and Trusteed Assets (Tables)

9 Months Ended

Sep. 30, 2013

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

Schedule of Costs of Retirement Plans [Table Text Block]

The following table details the components of net periodic benefit costs for pension benefits and other postretirement benefits:

	Pension Benefits						Other Postretirement Benefits
	2013			2012			2013			2012
Three Months Ended September 30	(In millions)
Service cost	$	22		$	20		$	9		$	15
Interest cost	49			51			21			29
Expected return on plan assets	(67		)	(61		)	(28		)	(23		)
Amortization of:
Net actuarial loss	55			48			16			21
Prior service credit	—			—			(36		)	(6		)
Net periodic benefit cost (credit)	$	59		$	58		$	(18	)	$	36

	Pension Benefits						Other Postretirement Benefits
	2013			2012			2013			2012
Nine Months Ended September 30	(In millions)
Service cost	$	71		$	61		$	37		$	51
Interest cost	144			153			66			90
Expected return on plan assets	(200		)	(183		)	(82		)	(69		)
Amortization of:
Net actuarial loss	156			133			48			60
Prior service credit	—			—			(95		)	(20		)
Net transition liability	—			—			—			1
Settlements	—			2			—			—
Net periodic benefit cost (credit)	$	171		$	166		$	(26	)	$	113

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Stock-Based Compensation (Tables)

9 Months Ended

Sep. 30, 2013

Share-based Compensation [Abstract]

Schedule of Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Table Text Block]

The following table summarizes the components of stock-based compensation:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2013		2012		2013		2012
	(In millions)
Stock-based compensation expense	$	18	$	21	$	81	$	61
Tax benefit	$	7	$	8	$	31	$	23
Stock-based compensation cost capitalized in property, plant and equipment	$	1	$	1	$	5	$	3

Schedule of Share-based Compensation, Stock Options, Activity [Table Text Block]

The following table summarizes our stock option activity for the nine months ended September 30, 2013:

	Number of Options		Weighted Average Exercise Price		Aggregate Intrinsic Value (In millions)
Options outstanding at December 31, 2012	1,192,670		$	41.86
Exercised	(399,139	)	$	40.54
Forfeited or expired	(10,370	)	$	41.46
Options outstanding at September 30, 2013	783,161		$	42.54	$	20
Options exercisable at September 30, 2013	783,161		$	42.54	$	20

Schedule of Share-based Compensation Arrangements by Share-based Payment Award [Table Text Block]

Restricted Stock Awards

The following table summarizes the Company’s restricted stock awards activity for the nine months ended September 30, 2013:

	Restricted Stock		Weighted Average Grant Date Fair Value
Balance at December 31, 2012	597,648		$	48.33
Grants	127,785		$	64.72
Forfeitures	(5,621	)	$	53.53
Vested and issued	(218,600	)	$	45.39
Balance at September 30, 2013	501,212		$	53.71

Performance Share Awards

The following table summarizes the Company’s performance share activity for the nine months ended September 30, 2013:

	Performance Shares
Balance at December 31, 2012	1,634,364
Grants	549,360
Forfeitures	(36,168	)
Payouts	(548,624	)
Balance at September 30, 2013	1,598,932

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Discontinued Operations (Notes)

9 Months Ended

Sep. 30, 2013

Discontinued Operations and Disposal Groups [Abstract]

Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]

DISCONTINUED OPERATIONS

Sale of Unconventional Gas Production Business

In December 2012, the Company sold its 100% equity interest in its Unconventional Gas Production business which consisted of gas and oil production assets in the western Barnett and Marble Falls shale areas of Texas. The activity of the discontinued business for the three and nine months ended September 30, 2012 is shown below. The amounts exclude general corporate overhead costs, and the related tax effects, and no portion of corporate interest costs were allocated to discontinued operations.

	Three Months Ended		Nine Months Ended
	September 30, 2012		September 30, 2012
	(In millions)
Operating Revenues	$	16	$	38
Operation and Maintenance	6		16
Depreciation, Depletion and Amortization	6		17
Taxes Other Than Income	1		2
Operating Income	3		3
Other (Income) and Deductions	1		4
Income Tax Expense (Benefit)	1		(1		)
Net Income Attributable to DTE Energy Company	$	1	$	—

XML

Regulatory Matters (Details Textuals) (USD $)		3 Months Ended	9 Months Ended			3 Months Ended
	Jul. 29, 2013	Mar. 31, 2013 MPSC [Member] Electric [Member]	Sep. 30, 2013 MPSC [Member] Electric [Member]	Oct. 17, 2013 MPSC [Member] Electric [Member]	Jul. 30, 2012 MPSC [Member] Electric [Member]	Sep. 30, 2013 MPSC [Member] Gas [Member]	Mar. 31, 2013 MPSC [Member] Gas [Member]	Jun. 30, 2013 Five Year (Minimum) [Member]	Jun. 30, 2013 Seven Year (Maximum) [Member]
Regulatory Asset and Liability [Line Items]
Years to transition PLD customers to DTE Electric distribution system								5 years	7 years
Rate increase previously authorized by the MPSC challeged by Court of Appeals affirmed by the MPSC				$ 8,000,000
Rate Base Amount related to Advanced Metering Infrasctructure Program reopened related to previously approved order			55,000,000
PSCR under-recovery from One Plan Year Prior		87,000,000
PSCR Under-Recovery from Two Plan Years Prior		148,000,000
Two Plan Years Prior PSCR Reconciliation included amount of Purchased Power Cost Related to Manual Shutdown of Fermi 2		30,000,000
Fermi 2 Production Level of Full Capacity					68.00%
Monthly Funding Factor for all Michigan Electric utilities participating in Low Income Energy Assistance Fund	0.99
Requesting Authority to Refund Uncollectible Expense to Customers							$ 20,000,000
Time Period to Refund the UETM Overrecovery						12 months

XML

Asset Retirement Obligations (Tables)

9 Months Ended

Sep. 30, 2013

Asset Retirement Obligation Disclosure [Abstract]

Schedule of Change in Asset Retirement Obligation [Table Text Block]

A reconciliation of the asset retirement obligations for the nine months ended September 30, 2013 follows:

	(In millions)
Asset retirement obligations at December 31, 2012	$	1,719
Accretion	79
Liabilities incurred	1
Liabilities settled	(12		)
Revision in estimated cash flows	13
Asset retirement obligations at September 30, 2013	$	1,800

XML

Significant Accounting Policies (Details 1) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Finite-Lived Intangible Assets [Line Items]
Intangible Assets, Gross	$ 177	$ 189
Less: Accumulated Amortization	41	34
Intangible Assets, Net	136	155
Less current intangible assets	14	20
Finite-Lived Intangible Assets, Net	122	135
Emission Allowances [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible Assets, Gross	3	6
Renewable Energy Credits [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible Assets, Gross	48	44
Contractual Rights [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible Assets, Gross	$ 126	$ 139

XML

Common Stock

9 Months Ended

Sep. 30, 2013

Stockholders' Equity Note [Abstract]

Common Stock [Text Block]

COMMON STOCK

During 2013, the Company contributed the following amounts of DTE Energy Common stock to the DTE Energy Company Affiliates Employee Benefit Plans Master Trust:

Date	Number of Shares	Price Per Share		Amount
				(In millions)
March 12, 2013	750,075	$	66.66	$	50
June 12, 2013	753,579	$	66.35	50
September 12, 2013	1,522,301	$	65.69	100
				$	200

The shares for all the contributions were valued at the closing market price of DTE Energy common stock on the contribution dates in accordance with fair value measurement and accounting requirements.

XML

Stock-Based Compensation (Details 1) (USD $) In Millions, except Share data, unless otherwise specified	9 Months Ended
	Sep. 30, 2013
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Options outstanding	1,192,670
Exercised	399,139
Forfeitured or expired	10,370
Options outstanding	783,161
Options exercisable	783,161
Weighted Average Exercise Price Per Share - Options outstanding	$ 41.86
Weighted Average Exercise Price Per Share - Exercised	$ 40.54
Weighted Average Exercise Price Per Share - Forfeitured or expired	$ 41.46
Weighted Average Exercise Price Per Share - Options outstanding	$ 42.54
Weighted Average Exercise Price Per Share - Options exercisable	$ 42.54
Aggregate Intrinsic Value - Options outstanding	$ 20
Aggregate Intrinsic Value - Options exercisable	$ 20

XML

Financial and Other Derivative Instruments (Notes)

9 Months Ended

Sep. 30, 2013

Derivative Instruments and Hedges, Assets [Abstract]

FINANCIAL AND OTHER DERIVATIVE INSTRUMENTS

NOTE 4 — FINANCIAL AND OTHER DERIVATIVE INSTRUMENTS

The Company recognizes all derivatives at their fair value as Derivative Assets or Liabilities on the 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 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 Company’s primary market risk exposure is associated with commodity prices, credit, and interest rates. The Company has risk management policies to monitor and manage market risks. The Company uses derivative instruments to manage some of the exposure. The Company uses derivative instruments for trading purposes in its Energy Trading segment. Contracts classified as derivative instruments include power, natural gas, oil and certain coal forwards, futures, options and 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.

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 sales exemption and are therefore accounted for under the accrual method. Other derivative contracts are recoverable through the PSCR mechanism when settled. This results in the deferral of unrealized gains and losses as Regulatory assets or liabilities until realized.

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 2016. Substantially all of these contracts meet the normal purchases and sales exemption and are therefore accounted for under the accrual method. DTE Gas may also sell forward transportation and storage capacity contracts. Forward transportation and storage contracts are generally not derivatives and are therefore accounted for under the accrual method.

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

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

Energy Trading — Commodity Price Risk — Energy Trading markets and trades electricity, coal, 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. The Company 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 — The Company uses interest rate swaps, treasury locks and other derivatives to hedge the risk associated with interest rate market volatility. In 2004 and 2000, the Company entered into a series of interest rate derivatives to limit its sensitivity to market interest rate risk associated with the issuance of long-term debt. Such instruments were designated as cash flow hedges. The Company subsequently issued long-term debt and terminated these hedges at a cost that is included in Other comprehensive loss. Amounts recorded in Other comprehensive loss will be reclassified to interest expense through 2033. In 2013, the Company estimates reclassifying less than $1 million of losses to earnings.

Credit Risk — The utility and non-utility businesses are exposed to credit risk if customers or counterparties do not comply with their contractual obligations. The Company maintains credit policies that significantly minimize overall credit risk. These policies include an evaluation of potential customers’ and counterparties’ financial condition, credit rating, collateral requirements or other credit enhancements such as letters of credit or guarantees. The Company generally uses standardized agreements that allow the netting of positive and negative transactions associated with a single counterparty. The Company maintains a provision for credit losses based on factors surrounding the credit risk of its customers, historical trends, and other information. Based on the Company’s credit policies and its September 30, 2013 provision for credit losses, the Company’s exposure to counterparty nonperformance is not expected to have a material adverse effect on the Company’s financial statements.

Derivative Activities

The Company manages its mark-to-market (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 tables present the fair value of derivative instruments as of September 30, 2013 and December 31, 2012:

	September 30, 2013					December 31, 2012
	Derivative Assets		Derivative Liabilities			Derivative Assets		Derivative Liabilities
	(In millions)
Derivatives designated as hedging instruments:
Interest rate contracts	$	—	$	—		$	—	$	(1	)
Derivatives not designated as hedging instruments:
Commodity Contracts:
Natural Gas	$	483	$	(471	)	$	645	$	(661	)
Electricity	298		(287		)	360		(351		)
Other	62		(57		)	11		(7		)
Total derivatives not designated as hedging instruments:	$	843	$	(815	)	$	1,016	$	(1,019	)
Total derivatives:
Current	$	711	$	(668	)	$	862	$	(879	)
Noncurrent	132		(147		)	154		(141		)
Total derivatives	$	843	$	(815	)	$	1,016	$	(1,020	)

Certain of the Company'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, the Company offsets the fair value of derivative instruments with cash collateral received or paid for those contracts executed with the same counterparty, which reduces the Company's total assets and liabilities. Cash collateral is allocated between the fair value of derivative instruments and customer accounts receivable and payable with the same counterparty on a pro rata basis to the extent there is exposure. Any cash collateral remaining, after the exposure is netted to zero, is reflected in accounts receivable and accounts payable as collateral paid or received, respectively.

The Company 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. The Company had issued letters of credit of approximately $21 million and $63 million at September 30, 2013 and December 31, 2012, respectively, which could be used to offset our net derivative liabilities. Letters of credit received from third parties which could be used to offset our net derivative assets were not material for the periods presented. Such balances of letters of credit are excluded from the tables below and are not netted with the recognized assets and liabilities in the 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 the 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.

As of September 30, 2013, the total cash collateral received, net of cash collateral posted, was $30 million. As of December 31, 2012, the total cash collateral received, net of cash collateral posted, was $20 million. As of September 30, 2013, derivative assets and derivative liabilities are shown net of cash collateral of $29 million and $20 million, respectively. There was no cash collateral related to unrealized positions to net against derivative assets and liabilities as of December 31, 2012. The Company recorded cash collateral paid of $3 million and cash collateral received of $24 million not related to unrealized derivative positions as of September 30, 2013. The Company recorded cash collateral paid of $4 million and cash collateral received of $24 million not related to unrealized derivative positions as of December 31, 2012. These amounts are included in accounts receivable and accounts payable and are recorded net by counterparty.

The following table presents the netting offsets of derivative assets and liabilities at September 30, 2013 and December 31, 2012:

	September 30, 2013									December 31, 2012
	Gross Amounts of Recognized Assets (Liabilities)			Gross Amounts Offset in the Consolidated Statements of Financial Position			Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position			Gross Amounts of Recognized Assets (Liabilities)			Gross Amounts Offset in the Consolidated Statements of Financial Position			Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position
	(In millions)
Derivative assets:
Commodity Contracts:
Natural Gas	$	483		$	(474	)	$	9		$	645		$	(605	)	$	40
Electricity	298			(216		)	82			360			(258		)	102
Other	62			(55		)	7			11			(6		)	5
Total derivative assets	$	843		$	(745	)	$	98		$	1,016		$	(869	)	$	147
Derivative liabilities:
Interest rate contracts	$	—		$	—		$	—		$	(1	)	$	—		$	(1	)
Commodity Contracts:
Natural Gas	(471		)	445			(26		)	(661		)	605			(56		)
Electricity	(287		)	236			(51		)	(351		)	258			(93		)
Other	(57		)	55			(2		)	(7		)	6			(1		)
Total derivative liabilities	$	(815	)	$	736		$	(79	)	$	(1,020	)	$	869		$	(151	)

The following table presents the netting offsets of derivative assets and liabilities at September 30, 2013 and December 31, 2012:

	September 30, 2013												December 31, 2012
	Derivative Assets						Derivative Liabilities						Derivative Assets						Derivative Liabilities
	Current			Noncurrent			Current			Noncurrent			Current			Noncurrent			Current			Noncurrent
	(In millions)
Reconciliation of derivative instruments to Consolidated Statements of Financial Position:
Total fair value of derivatives	$	711		$	132		$	(668	)	$	(147	)	$	862		$	154		$	(879	)	$	(141	)
Counterparty netting	(610		)	(106		)	610			106			(754		)	(115		)	754			115
Collateral adjustment	(29		)	—			—			20			—			—			—			—
Total derivatives as reported	$	72		$	26		$	(58	)	$	(21	)	$	108		$	39		$	(125	)	$	(26	)

The effect of derivatives not designated as hedging instruments on the Consolidated Statements of Operations for the three and nine months ended September 30, 2013 and 2012 is as follows:

	Location of Gain (Loss) Recognized in Income on Derivatives	Gain (Loss) Recognized in Income on Derivatives for the Three Months Ended September 30,						Gain (Loss) Recognized in Income on Derivatives for the Nine Months Ended September 30,
Derivatives not Designated as Hedging Instruments		2013			2012			2013			2012
		(In millions)
Foreign currency exchange contracts	Operating Revenue	$	—		$	(2	)	$	(1	)	$	(1	)
Commodity Contracts:
Natural Gas	Operating Revenue	1			(54		)	37			(51		)
Natural Gas	Fuel, purchased power and gas	(1		)	50			(33		)	45
Electricity	Operating Revenue	22			17			52			52
Other	Operating Revenue	1			1			1			12
Total		$	23		$	12		$	56		$	57

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

The effects of derivative instruments recoverable through the PSCR mechanism when realized on the Consolidated Statements of Financial Position were $3 million and $7 million in unrealized gains related to FTRs recognized in Regulatory liabilities for the three and nine months ended September 30, 2013, respectively.

The following represents the cumulative gross volume of derivative contracts outstanding as of September 30, 2013:

Commodity	Number of Units
Natural Gas (MMBtu)	683,113,433
Electricity (MWh)	59,672,654
Foreign Currency Exchange ($ CAD)	48,741,288
FTR (MWh)	13,005,024

Various subsidiaries of the Company have entered into contracts which contain ratings triggers and are guaranteed by DTE Energy. These contracts contain provisions which allow the counterparties to request that the Company 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 the Company can be asked 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 the Company 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 September 30, 2013, DTE Energy's contractual obligation to post collateral in the form of cash or letter of credit in the event of a downgrade to below investment grade, under both hard trigger and soft trigger provisions, was approximately $327 million.

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Consolidated Statements of Cash Flows (Unaudited) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
Operating Activities
Net Income	$ 542	$ 535
Adjustments to reconcile net income to net cash from operating activities:
Depreciation, depletion and amortization	811	747
Nuclear fuel amortization	25	25
Allowance for equity funds used during construction	(10)	(10)
Deferred income taxes	162	96
Asset (gains) and losses, reserves and impairments, net	5	7
Changes in assets and liabilities:
Accounts receivable, net	177	237
Inventories	35	5
Accounts payable	(16)	(35)
Derivative assets and liabilities	(23)	38
Accrued pension obligation	(44)	(3)
Accrued postretirement obligation	(191)	(143)
Regulatory assets and liabilities	327	286
Other assets	(62)	(2)
Other liabilities	(13)	(40)
Net cash from operating activities	1,715	1,729
Investing Activities
Plant and equipment expenditures — utility	(1,101)	(1,008)
Plant and equipment expenditures — non-utility	(270)	(214)
Proceeds from sale of assets	20	20
Restricted cash for debt redemption, principally Securitization	58	55
Proceeds from sale of nuclear decommissioning trust fund assets	40	48
Investment in nuclear decommissioning trust funds	(52)	(61)
Other	(32)	(24)
Net cash used for investing activities	(1,337)	(1,184)
Financing Activities
Issuance of long-term debt, net	768	495
Redemption of long-term debt	(855)	(447)
Short-term borrowings, net	31	(321)
Issuance of common stock	29	29
Dividends on common stock	(329)	(300)
Other	(16)	(10)
Net cash used for financing activities	(372)	(554)
Net Increase (Decrease) in Cash and Cash Equivalents	6	(9)
Cash and Cash Equivalents at Beginning of Period	65	68
Cash and Cash Equivalents at End of Period	71	59
Supplemental Disclosure of Non-Cash Information
Common stock issued for employee benefit and compensation plans	279	143
Change in capital expenditures not paid	$ 263	$ 184

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Fair Value (Details Textuals) (USD $)	3 Months Ended		9 Months Ended												9 Months Ended	12 Months Ended			3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013 Fair Value, Measurements, Recurring [Member]	Dec. 31, 2012 Fair Value, Measurements, Recurring [Member]	Sep. 30, 2013 Fair Value, Inputs, Level 2 [Member] Fair Value, Measurements, Recurring [Member]	Dec. 31, 2012 Fair Value, Inputs, Level 2 [Member] Fair Value, Measurements, Recurring [Member]	Sep. 30, 2013 Restricted Assets [Member] Fair Value, Inputs, Level 2 [Member] Fair Value, Measurements, Recurring [Member]	Dec. 31, 2012 Restricted Assets [Member] Fair Value, Inputs, Level 2 [Member] Fair Value, Measurements, Recurring [Member]	Sep. 30, 2013 Other Investments [Member] Fair Value, Measurements, Recurring [Member] Equity [Member]	Dec. 31, 2012 Other Investments [Member] Fair Value, Measurements, Recurring [Member] Equity [Member]	Sep. 30, 2013 Other Investments [Member] Fair Value, Inputs, Level 2 [Member] Fair Value, Measurements, Recurring [Member]	Dec. 31, 2012 Other Investments [Member] Fair Value, Inputs, Level 2 [Member] Fair Value, Measurements, Recurring [Member]	Sep. 30, 2013 Nuclear Decommissioning Trust Fund [Member]	Dec. 31, 2012 Nuclear Decommissioning Trust Fund [Member]	Sep. 30, 2013 Fermi 2 [Member]	Dec. 31, 2012 Fermi 2 [Member]	Sep. 30, 2013 Fermi 1 [Member]	Sep. 30, 2012 Fermi 1 [Member]	Sep. 30, 2013 Fermi 1 [Member]	Sep. 30, 2012 Fermi 1 [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Cash and Cash Equivalents, Fair Value Disclosure					$ 68,000,000	$ 123,000,000	$ 68,000,000	$ 123,000,000	$ 51,000,000	$ 109,000,000			$ 17,000,000	$ 14,000,000	$ 12,000,000	$ 7,000,000
Available-for-sale Securities, Fair Value Disclosure											6,000,000	5,000,000
Other investments					124,000,000	110,000,000	48,000,000	44,000,000			124,000,000	110,000,000
Average Maturity of Debt Securities															7 years	6 years
Unrealized losses recognized as regulatory assets																	38,000,000	44,000,000
Fermi I Corresponding Regulatory Asset Treatment																			0		0
Unrealized losses recognized in earnings																			0	0	0	0
Unrealized on Available for Sale Securities	0	0	0	0
Trading Securities, Change in Unrealized Holding Gain (Loss)			$ 14,000,000	$ 11,000,000

XML

Fair Value Fair Value (Details 3) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013 MMBTU	Dec. 31, 2012 MMBTU
Fair Value, Inputs, Level 3 [Member] | Natural Gas Commodity Contract [Member]
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Weighted Average Forward Basis Price	0.10	0.03
Fair Value, Inputs, Level 3 [Member] | Electricity [Member]
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Weighted Average Forward Basis Price	2	3
Minimum [Member] | Fair Value, Inputs, Level 3 [Member] | Natural Gas Commodity Contract [Member]
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price	(1.10)	(0.63)
Minimum [Member] | Fair Value, Inputs, Level 3 [Member] | Electricity [Member]
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price	(8)	(2)
Maximum [Member] | Fair Value, Inputs, Level 3 [Member] | Natural Gas Commodity Contract [Member]
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price	4.22	1.95
Maximum [Member] | Fair Value, Inputs, Level 3 [Member] | Electricity [Member]
Unobservable Inputs Valuation Techniques [Line Items]
Forward basis price	15	16
Fair Value, Measurements, Recurring [Member]
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets	$ 98	$ 147
Derivative Liabilities	(79)	(151)
Fair Value, Measurements, Recurring [Member] | Natural Gas Commodity Contract [Member]
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets	9	40
Derivative Liabilities	(26)	(56)
Fair Value, Measurements, Recurring [Member] | Electricity [Member]
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets	82	102
Derivative Liabilities	(51)	(93)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets	127	160
Derivative Liabilities	(131)	(173)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Natural Gas Commodity Contract [Member]
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets	34	24
Derivative Liabilities	(48)	(62)
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Electricity [Member]
Unobservable Inputs Valuation Techniques [Line Items]
Derivative Assets	88	134
Derivative Liabilities	$ (83)	$ (111)

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Long-Term Debt (Tables)

9 Months Ended

Sep. 30, 2013

Long-term Debt, Unclassified [Abstract]

Schedule of Issued Debt [Table Text Block]

In 2013, the following debt was issued:

Company	Month Issued	Type	Interest Rate		Maturity	Amount
						(In millions)
DTE Electric	March	Mortgage Bonds (a)	4.00	%	2043	$	375
DTE Electric	August	Mortgage Bonds (a)	3.65	%	2024	400
						$	775

_______________________________________

(a) Proceeds were used for the redemption of DTE Electric long-term debt, for the repayment of short-term borrowings, and for general corporate purposes.

Schedule of Extinguishment of Debt [Table Text Block]

In 2013, the following debt was redeemed:

Company	Month	Type	Interest Rate		Maturity	Amount
						(In millions)
DTE Electric	March	Securitization Bonds	6.42	%	2013	$	88
DTE Electric	March	Tax Exempt Revenue Bonds (a)	5.30	%	2030	51
DTE Electric	April	Other Long-Term Debt	Various		2013	13
DTE Gas	April	Senior Notes	5.26	%	2013	60
DTE Energy	Various	Other Long-Term Debt	Various		2013	4
DTE Energy	June	Senior Notes	Variable		2013	300
DTE Electric	September	Securitization Bonds	6.62	%	2015	89
DTE Electric	September	Senior Notes	6.40	%	2013	250
						$	855

_______________________________________

(a) 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.

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Long-Term Debt (Details 1) (USD $) In Millions, unless otherwise specified	9 Months Ended		3 Months Ended
	Sep. 30, 2013	Sep. 30, 2013 DTE Energy [Member] Long-term Debt [Member]	Jun. 30, 2013 DTE Energy [Member] Senior Notes [Member]	Sep. 30, 2013 Electric [Member] Securitization Bonds [Member]	Mar. 31, 2013 Electric [Member] Securitization Bonds [Member]	Mar. 31, 2013 Electric [Member] Tax Exempt Revenue Bonds [Member]	Sep. 30, 2013 Electric [Member] Senior Notes [Member]	Jun. 30, 2013 Electric [Member] Long Term Debt, Other [Member]	Jun. 30, 2013 Gas [Member] Senior Notes [Member]
Extinguishment of Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage				6.62%	6.42%	5.30%	6.40%		5.26%
Extinguishment of Debt, Amount	$ 855	$ 4	$ 300	$ 89	$ 88	$ 51	$ 250	$ 13	$ 60

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Discontinued Operations Discontinued Operations (Details) (Discontinued Operations [Member], USD $) In Millions, unless otherwise specified	3 Months Ended	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2012
Discontinued Operations [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Operating Revenue	$ 16	$ 38
Operation and Maintenance	6	16
Depreciation, Depletion and Amortization	6	17
Taxes, Other	1	2
Operating Income (Loss)	3	3
Other (Income) and Deductions	(1)	(4)
Taxes other than Income	1	(1)
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	$ 1	$ 0

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Short-Term Credit Arrangements and Borrowings (Notes)

9 Months Ended

Sep. 30, 2013

Short-term Debt [Abstract]

Short-Term Credit Arrangements and Borrowings

SHORT-TERM CREDIT ARRANGEMENTS AND BORROWINGS

DTE Energy and its wholly owned subsidiaries, DTE Electric and DTE Gas, have unsecured revolving credit agreements with a syndicate of 19 banks that can be used for general corporate borrowings, but are intended to provide liquidity support for each of the companies’ commercial paper programs. No one bank provides more than 8.7% of the commitment in any facility. Borrowings under the facilities are available at prevailing short-term interest rates. Additionally, DTE Energy has other facilities to support letter of credit issuance.

The agreements require the Company 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 the Company and its 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 stockholders’ equity of the Company and its 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 September 30, 2013, the total funded debt to total capitalization ratios for DTE Energy, DTE Electric and DTE Gas are 0.48 to 1, 0.53 to 1 and 0.44 to 1, respectively, and are in compliance with this financial covenant. The availability under the facilities in place at September 30, 2013 is shown in the following table:

	DTE Energy		DTE Electric		DTE Gas		Total
	(In millions)
Unsecured letter of credit facility, expiring in May 2014	$	50	$	—	$	—	$	50
Unsecured letter of credit facility, expiring in August 2015	125		—		—		125
Unsecured revolving credit facility, expiring April 2018	1,200		300		300		1,800
Total credit facilities at September 30, 2013	1,375		300		300		1,975
Amounts outstanding at September 30, 2013:
Commercial paper issuances	44		11		216		271
Letters of credit	235		—		—		235
	279		11		216		506
Net availability at September 30, 2013	$	1,096	$	289	$	84	$	1,469

The Company has other outstanding letters of credit which are not included in the above described facilities totaling approximately $47 million which are used for various corporate purposes.

In conjunction with maintaining certain exchange traded risk management positions, the Company may be required to post cash collateral with its clearing agent. The Company 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 the Company posts a letter of credit for the incremental amount. At September 30, 2013, a $40 million letter of credit was in place, raising the capacity under this facility to $140 million. The $40 million letter of credit is included in the table above. The amount outstanding under this agreement was $75 million and $65 million at September 30, 2013 and December 31, 2012, respectively.

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Regulatory Matters (Notes)

9 Months Ended

Sep. 30, 2013

Public Utilities, General Disclosures [Abstract]

Regulatory Matters

REGULATORY MATTERS

Transition of the City of Detroit's Public Lighting Department's (PLD) Customers to DTE Electric's Distribution System

Accounting Authority

On June 28, 2013, DTE Electric filed an application for accounting authority to defer certain costs associated with the transition of the City of Detroit's PLD customers to the DTE Electric distribution system over a five to seven year system conversion period. The Company requested authority to defer as a regulatory asset, all net incremental revenue requirement associated with the transition. The net incremental revenue requirement includes costs to install meters and attach customers; system and customer facility upgrades and repairs; and the difference between DTE Electric's tariff rates and any transitional rates approved in the future. On July 11, 2013, the MPSC approved DTE Electric's request to defer, for accounting purposes, the net incremental revenue requirement.

The approval excludes the request to defer the difference between DTE Electric's tariff rates and any transitional rates that might be approved by the MPSC in the future. The MPSC will address proposed rates and recovery matters in a future contested proceeding. As the accounting order did not provide a regulatory recovery mechanism, a regulatory asset will not be recognized until a regulatory recovery mechanism is put into place and the recovery of the regulatory asset becomes probable.

Transitional Reconciliation Mechanism (TRM)

On July 19, 2013, DTE Electric filed its TRM application proposing a transitional tariff option for certain former PLD customers and a modified line extension provision. The application also proposes a recovery mechanism for the deferred incremental revenue requirement described above. The application further discusses that DTE Electric will be requesting recovery, in subsequent PSCR cases, of PLD transmission delivery service costs incurred while DTE Electric is temporarily relying upon PLD to operate and maintain PLD's system during the system conversion period. If the MPSC determines that the transmission costs are not recoverable in the PSCR, the Company requested recovery as part of the TRM.

2009 Electric Rate Case Filing - Court of Appeals Remand to MPSC

In April 2012, the Michigan Court of Appeals (COA) issued a decision relating to an appeal of the January 2010 MPSC rate order in DTE Electric's January 2009 rate case filing. The COA found that the record of evidence in the January 2010 rate order was insufficient to support the MPSC's authorization to recover costs for the advanced metering infrastructure (AMI) program and remanded this matter to the MPSC. On October 17, 2013, the MPSC issued an order affirming the approximately $8 million rate increase authorized in the MPSC's January 2010 rate order for the AMI program and further concluded that the evidence presented after remand supports the authorized cost recovery.

2010 Electric Rate Case Filing - Court of Appeals Decision

In July 2013, the COA issued a decision relating to an appeal of the October 2011 MPSC order in DTE Electric's October 2010 rate case filing. The COA found that the record of evidence in the 2010 rate case order was insufficient to support the MPSC's authorization to recover costs for the AMI program and remanded this matter to the MPSC. The MPSC had approved $55 million of the average rate base related to the AMI program in the October 2011 order. DTE Electric is currently operating its AMI program pursuant to the MPSC's approval set forth in the October 2011 order. On August 29, 2013, the MPSC reopened the 2010 electric rate case for the limited purpose of addressing the COA's opinion on AMI. The Company is unable to predict the outcome of this matter or the timing of its resolution.

Power Supply Cost Recovery 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 and sulfur dioxide emission allowances costs, urea costs, transmission costs and MISO costs. The MPSC reviews these costs, policies and practices for prudence in annual plan and reconciliation filings.

2012 PSCR Year - In March 2013, DTE Electric filed the 2012 PSCR reconciliation calculating a net under-recovery of approximately $87 million that includes an under-recovery of approximately $148 million for the 2011 PSCR year. The reconciliation includes approximately $30 million of purchased power costs related to the manual shutdown of our 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 July 30, 2012 which restored production to nominal 68% of full capacity. In September 2013, the repair to the plant was completed and production was returned to full capacity. We were able to purchase sufficient power from MISO to continue to provide uninterrupted service to our customers. Certain intervenors in the reconciliation case have challenged the recovery of some or all of the Fermi-related purchased power costs. Resolution of this matter is expected in 2014.

Low Income Energy Assistance Fund (LIEAF)

On July 1, 2013, Michigan Public Act 95 was signed into law and created the LIEAF. The legislation allows the use of a LIEAF funding factor to be determined by the MPSC and assessed on all customer classes of Michigan electric utilities to fund the LIEAF. On July 29, 2013, the MPSC adopted a funding factor of $0.99 per meter per month for all Michigan electric utilities that are participating in the program, including DTE Electric, effective with the September 2013 billing month. The surcharge billed by DTE Electric is remitted to the State of Michigan for subsequent distribution through a grant process to social service agencies and utilities to assist low income customers.

DTE Gas Uncollectible Expense True-Up Mechanism (UETM)

In March 2013, DTE Gas filed an application with the MPSC for approval of its UETM reconciliation for 2012 requesting authority to refund approximately $20 million. On September 10, 2013, the MPSC approved a settlement agreement approving the requested 2012 UETM refund over a twelve-month period beginning in October 2013.

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Short-Term Credit Arrangements and Borrowings (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013
Availability under combined facilities
Line of Credit Facility, Maximum Borrowing Capacity	$ 1,975
Amounts Outstanding	506
Net availability	1,469
DTE Energy [Member]
Availability under combined facilities
Line of Credit Facility, Maximum Borrowing Capacity	1,375
Amounts Outstanding	279
Net availability	1,096
DTE Electric [Member]
Availability under combined facilities
Line of Credit Facility, Maximum Borrowing Capacity	300
Amounts Outstanding	11
Net availability	289
DTE Gas [Member]
Availability under combined facilities
Line of Credit Facility, Maximum Borrowing Capacity	300
Amounts Outstanding	216
Net availability	84
Letter of Credit [Member]
Availability under combined facilities
Amounts Outstanding	235
Letter of Credit [Member] | Unsecured letter of credit facility expiring in May 2014 [Member]
Availability under combined facilities
Line of Credit Facility, Maximum Borrowing Capacity	50
Letter of Credit [Member] | Unsecured letter of credit facility expiring in August 2015 [Member]
Availability under combined facilities
Line of Credit Facility, Maximum Borrowing Capacity	125
Letter of Credit [Member] | DTE Energy [Member]
Availability under combined facilities
Amounts Outstanding	235
Letter of Credit [Member] | DTE Energy [Member] | Unsecured letter of credit facility expiring in May 2014 [Member]
Availability under combined facilities
Line of Credit Facility, Maximum Borrowing Capacity	50
Letter of Credit [Member] | DTE Energy [Member] | Unsecured letter of credit facility expiring in August 2015 [Member]
Availability under combined facilities
Line of Credit Facility, Maximum Borrowing Capacity	125
Letter of Credit [Member] | DTE Electric [Member]
Availability under combined facilities
Amounts Outstanding	0
Letter of Credit [Member] | DTE Electric [Member] | Unsecured letter of credit facility expiring in May 2014 [Member]
Availability under combined facilities
Line of Credit Facility, Maximum Borrowing Capacity	0
Letter of Credit [Member] | DTE Electric [Member] | Unsecured letter of credit facility expiring in August 2015 [Member]
Availability under combined facilities
Line of Credit Facility, Maximum Borrowing Capacity	0
Letter of Credit [Member] | DTE Gas [Member]
Availability under combined facilities
Amounts Outstanding	0
Letter of Credit [Member] | DTE Gas [Member] | Unsecured letter of credit facility expiring in May 2014 [Member]
Availability under combined facilities
Line of Credit Facility, Maximum Borrowing Capacity	0
Letter of Credit [Member] | DTE Gas [Member] | Unsecured letter of credit facility expiring in August 2015 [Member]
Availability under combined facilities
Line of Credit Facility, Maximum Borrowing Capacity	0
Revolving Credit Facility [Member] | Unsecured revolving credit facility expiring in April 2018 [Member]
Availability under combined facilities
Line of Credit Facility, Maximum Borrowing Capacity	1,800
Revolving Credit Facility [Member] | DTE Energy [Member] | Unsecured revolving credit facility expiring in April 2018 [Member]
Availability under combined facilities
Line of Credit Facility, Maximum Borrowing Capacity	1,200
Revolving Credit Facility [Member] | DTE Electric [Member] | Unsecured revolving credit facility expiring in April 2018 [Member]
Availability under combined facilities
Line of Credit Facility, Maximum Borrowing Capacity	300
Revolving Credit Facility [Member] | DTE Gas [Member] | Unsecured revolving credit facility expiring in April 2018 [Member]
Availability under combined facilities
Line of Credit Facility, Maximum Borrowing Capacity	300
Commercial Paper [Member]
Availability under combined facilities
Amounts Outstanding	271
Commercial Paper [Member] | DTE Energy [Member]
Availability under combined facilities
Amounts Outstanding	44
Commercial Paper [Member] | DTE Electric [Member]
Availability under combined facilities
Amounts Outstanding	11
Commercial Paper [Member] | DTE Gas [Member]
Availability under combined facilities
Amounts Outstanding	$ 216

XML

Stock-Based Compensation (Notes)

9 Months Ended

Sep. 30, 2013

Share-based Compensation [Abstract]

Stock-based Compensation

STOCK-BASED COMPENSATION

The following table summarizes the components of stock-based compensation:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2013		2012		2013		2012
	(In millions)
Stock-based compensation expense	$	18	$	21	$	81	$	61
Tax benefit	$	7	$	8	$	31	$	23
Stock-based compensation cost capitalized in property, plant and equipment	$	1	$	1	$	5	$	3

Stock Options

The following table summarizes our stock option activity for the nine months ended September 30, 2013:

	Number of Options		Weighted Average Exercise Price		Aggregate Intrinsic Value (In millions)
Options outstanding at December 31, 2012	1,192,670		$	41.86
Exercised	(399,139	)	$	40.54
Forfeited or expired	(10,370	)	$	41.46
Options outstanding at September 30, 2013	783,161		$	42.54	$	20
Options exercisable at September 30, 2013	783,161		$	42.54	$	20

As of September 30, 2013, the weighted average remaining contractual life for the exercisable shares is 4.17 years. During the nine months ended September 30, 2013, 200,844 options vested. As of September 30, 2013, all options were vested.

The intrinsic value of options exercised for the nine months ended September 30, 2013 and 2012 was $11 million and $21 million, respectively. No option expense was recognized for the nine months ended September 30, 2013 and $0.5 million of option expense was recognized for the nine months ended September 30, 2012.

The Company includes both historical and implied share-price volatility in option volatility. Implied volatility is derived from exchange traded options on DTE Energy common stock. The Company’s expected option life estimate is based on historical data.

Restricted Stock Awards

The following table summarizes the Company’s restricted stock awards activity for the nine months ended September 30, 2013:

	Restricted Stock		Weighted Average Grant Date Fair Value
Balance at December 31, 2012	597,648		$	48.33
Grants	127,785		$	64.72
Forfeitures	(5,621	)	$	53.53
Vested and issued	(218,600	)	$	45.39
Balance at September 30, 2013	501,212		$	53.71

Performance Share Awards

The following table summarizes the Company’s performance share activity for the nine months ended September 30, 2013:

	Performance Shares
Balance at December 31, 2012	1,634,364
Grants	549,360
Forfeitures	(36,168	)
Payouts	(548,624	)
Balance at September 30, 2013	1,598,932

Unrecognized Compensation Costs

As of September 30, 2013, there was $72 million of total unrecognized compensation cost related to non-vested stock incentive plan arrangements. That cost is expected to be recognized over a weighted-average period of 1.18 years.

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Commitments and Contingencies (Notes)

9 Months Ended

Sep. 30, 2013

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

COMMITMENTS AND CONTINGENCIES

Environmental

Electric

Air - DTE Electric is subject to the EPA ozone and fine particulate transport and acid rain regulations that limit power plant emissions of sulfur dioxide and nitrogen oxides. Since 2005, the EPA and the State of Michigan have issued additional emission reduction regulations relating to ozone, fine particulate, regional haze, mercury, and other air pollution. These rules have led to additional controls on fossil-fueled power plants to reduce nitrogen oxide, sulfur dioxide, mercury and other emissions. To comply with these requirements, DTE Electric spent approximately $1.9 billion through 2012. The Company estimates DTE Electric will make capital expenditures of approximately $190 million in 2013 and up to approximately $1.8 billion of additional capital expenditures through 2021 based on current regulations. Further, additional rulemakings are expected over the next few years which could require additional controls for sulfur dioxide, nitrogen oxides and hazardous air pollutants. The Cross State Air Pollution Rule (CSAPR), finalized in July 2011, required further reductions of sulfur dioxide and nitrogen oxides emissions beginning in 2012. On December 30, 2011, the U.S. Court of Appeals for the District of Columbia (D.C.) Circuit granted the motions to stay the rule, leaving DTE Electric temporarily subject to the previously existing Clean Air Interstate Rule (CAIR). On August 21, 2012, the Court issued its decision, vacating CSAPR and leaving CAIR in place. The EPA's petition seeking a rehearing of the U.S. Court of Appeals' decision regarding the CSAPR was denied on January 24, 2013. On June 24, 2013, the U.S. Supreme Court granted EPA's petition asking the Court to review the D.C. Circuit Court's decision on CSAPR. A ruling by the Supreme Court is not expected before 2014. Notwithstanding the appeal filed with the Supreme Court, the EPA and a number of states have started working on the framework of revised CSAPR regulations which we anticipate to be proposed in the next few years.

The Mercury and Air Toxics Standard (MATS) rule, formerly known as the Electric Generating Unit Maximum Achievable Control Technology (EGU MACT) Rule was finalized on December 16, 2011. The MATS rule requires reductions of mercury and other hazardous air pollutants beginning in April 2015, with a potential extension to April 2016. DTE Electric has requested and been granted compliance date extensions for some units to April 2016. DTE Electric has tested technologies to determine technological and economic feasibility as MATS compliance alternatives to Flue Gas Desulfurization (FGD) systems. Implementation of Dry Sorbent Injection (DSI) and Activated Carbon Injection (ACI) technologies will allow several units that would not have been economical for FGD installations to continue operation in compliance with MATS.

In July 2009, DTE Energy received a Notice of Violation/Finding of Violation (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. On August 23, 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. On October 20, 2011, the EPA caused to be filed a Notice of Appeal to the U.S. Court of Appeals for the Sixth Circuit. On March 28, 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. On September 3, 2013, the EPA caused to be filed a motion seeking leave to amend their complaint regarding the June 2010 NOV/FOV adding additional claims related to outage work performed at the Trenton Channel and Belle River power plants as well as additional claims related to work performed at the Monroe Power Plant. In addition, the Sierra Club caused to be filed a motion to add a claim regarding the River Rouge Power Plant. The EPA and Sierra Club motions are currently pending with the U. S. District Court Judge.

DTE Energy and DTE Electric believe that the plants identified by the EPA, including Unit 2 of the Monroe Power Plant, have complied with all applicable federal environmental regulations. Depending upon the outcome of discussions with the EPA regarding the two NOVs/FOVs, DTE Electric could be required to install additional pollution control equipment at some or all of the power plants in question, implement early retirement of facilities where control equipment is not economical, engage in supplemental environmental programs, and/or pay fines. The Company cannot predict the financial impact or outcome of this matter, or the timing of its resolution.

On March 13, 2013, the Sierra Club filed suit against DTE Energy and DTE Electric alleging violations of the Clean Air Act at four of DTE Electric's coal-fired power plants. The plaintiffs allege 1,4996-minute periods of excess opacity of air emissions from 2007-2012 at those facilities. The suit asks that the court enjoin DTE Energy and DTE Electric from operating the power plants except in complete compliance with applicable laws and permit requirements, pay civil penalties, conduct beneficial environmental mitigation projects, pay attorney fees and require the installation of any necessary pollution controls or to convert and/or operate the plants' boilers on natural gas to avoid additional violations and to off-set historic unlawful emissions. The resolution of this matter is not expected to have a material effect on the Company's operations or financial statements.

Water — In response to an EPA regulation, DTE Electric would be 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. The initial rule published in 2004 was subsequently remanded and a proposed rule published in 2011. The proposed rule specified an eight year compliance timeline. In July 2012, the EPA announced that a notice of its final action on the rule will be issued in June 2013. On June 27, 2013, the EPA announced an agreement to extend the deadline for issuance of the final rule until November 4, 2013. On April 19, 2013, the EPA proposed revised steam electric effluent guidelines regulating wastewater streams from coal-fired power plants including multiple possible options for compliance. The rules are expected to be finalized by May 2014. DTE Electric has provided comments to the EPA. However, it is not possible at this time to quantify the impacts of these developing requirements.

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 manufactured gas plant (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 site. In addition to the MGP sites, the Company 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 September 30, 2013 and December 31, 2012, the Company had $9 million accrued for remediation. Any change in assumptions, such as remediation techniques, nature and extent of contamination and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect the Company’s financial position and cash flows. The Company believes that the likelihood of a materially greater liability than the accrued amount is remote based on current knowledge of the conditions at each site.

DTE Electric owns and operates a permitted engineered ash storage facility at the Monroe Power Plant to dispose of fly ash from the coal fired power plant. The EPA has published proposed rules to regulate coal ash under the authority of the Resources Conservation and Recovery Act (RCRA). The proposed rule published in June 2010 contains two primary regulatory options to regulate coal ash residue. The EPA is currently considering either designating coal ash as a “Hazardous Waste” as defined by RCRA or regulating coal ash as non-hazardous waste under RCRA. Agencies and legislatures have urged the EPA to regulate coal ash as a non-hazardous waste. If the EPA designates coal ash as a hazardous waste, the agency could apply some, or all, of the disposal and reuse standards that have been applied to other existing hazardous wastes to disposal and reuse of coal ash. Some of the regulatory actions currently being contemplated could have a significant impact on our operations and financial position and the rates we charge our customers. It is not possible to quantify the impact of those expected rulemakings at this time.

Gas

Contaminated Sites — Gas segment, owns or previously owned, 15 former MGP sites. Investigations have revealed contamination related to the by-products of gas manufacturing at each site. In addition to the MGP sites, the Company is also in the process of cleaning up other contaminated sites. Cleanup activities associated with these sites will be conducted 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. Accordingly, Gas segment recognizes a liability and corresponding Regulatory asset for estimated investigation and remediation costs at former MGP sites. As of September 30, 2013 and December 31, 2012, the Company had $29 million accrued for remediation. Any change in assumptions, such as remediation techniques, nature and extent of contamination and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect the Company’s financial position and cash flows. The Company 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 and the cost deferral and rate recovery mechanism for Citizens Fuel Gas approved by the City of Adrian, will prevent environmental costs from having a material adverse impact on the Company’s results of operations.

Non-utility

The Company’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 the Company’s position of demonstrated compliance and has not initiated escalated enforcement. At this time, the Company cannot predict the impact of this issue. Furthermore, the Michigan coke battery facility is the subject of an investigation by the MDEQ concerning visible emissions readings that resulted from the Company self reporting to MDEQ questionable activities by an employee of a contractor hired by the Company to perform the visible emissions readings. At this time, the Company cannot predict the impact of this investigation.

The Company 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. The Company has implemented best management practices to address this issue. The Company recently received a permit to upgrade its existing waste water treatment system and is currently seeking a permit from the PADEP to upgrade its wastewater treatment technology to a biological treatment facility. The Company expects to spend less than $7 million on the existing waste water treatment system to comply with existing water discharge requirements and to upgrade its coal pile storm water runoff management program.

The Company believes that its non-utility businesses are substantially in compliance with all environmental requirements, other than as noted above.

Other

In March 2011, the EPA finalized a new set of regulations regarding the identification of non-hazardous secondary materials that are considered solid waste, industrial boiler and process heater maximum achievable control technologies (IBMACT) for major and area sources, and commercial/industrial solid waste incinerator new source performance standard and emission guidelines (CISWI). The effective dates of the major source IBMACT and CISWI regulations were stayed anda re-proposal was issued by the EPA in December 2011. Final IBMACT and CISWI were issued by the EPA in December 2012. The Company is developing compliance plans to upgrade or convert existing industrial boilers to natural gas and to perform required energy assessments in compliance with the applicable new standards. Capital costs for the boiler conversions and the expenses for the one-time energy assessments are not expected to be material.

In 2010, the EPA finalized a new 1-hour sulfur dioxide ambient air quality standard that requires states to submit plans for non-attainment areas to be in compliance by 2017. Michigan's non-attainment area includes DTE Energy facilities in southwest Detroit and areas of Wayne County. Preliminary modeling runs by the MDEQ suggest that emission reductions may be required by significant sources of sulfur dioxide emissions in these areas, including DTE Electric power plants and our Michigan coke battery. The state implementation plan process is in the information gathering stage and any required emission reductions for DTE Energy sources to meet the standard cannot be estimated currently.

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. The Nuclear Electric Insurance Limited (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 $500 million in primary coverage and $2.25 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, subject to a $1 million deductible. As of April 1, 2013, the total limit for property damage for non-nuclear events is $1.8 billion and an aggregate of $327 million of coverage for extra expenses over a two-year period.

In 2007, the Terrorism Risk Insurance Extension Act of 2005 (TRIA) was extended through December 31, 2014. A major change in the extension is the inclusion of “domestic” acts of terrorism in the definition of covered or “certified” acts. 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 the NEIL policies, DTE Electric could be liable for maximum assessments of up to approximately $34 million per event if the loss associated with any one event at any insured 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 $127.3 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 U.S. Department of Energy (DOE) for the future storage and disposal of spent nuclear fuel from Fermi 2. DTE Electric is obligated to pay the DOE a fee of 1 mill per kWh of Fermi 2 electricity generated and sold. The fee is 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 currently employs a spent nuclear fuel storage strategy utilizing a fuel pool. The Company continues to develop its on-site dry cask storage facility and anticipates initial offload from the spent fuel pool in 2014. 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.

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 provided for a payment of approximately $48 million, received in August 2012, for delay-related costs experienced by DTE Electric through 2010, and a claims process for submittal of delay-related costs from 2011 through 2013. DTE Electric has begun the claims process and all claims submitted have been accepted. The settlement proceeds reduced the cost of the dry cask storage facility assets. In February 2013, the U.S. Court of Appeals for the District of Columbia granted a motion to reopen the fee adequacy litigation to review the DOE's latest fee adequacy report which was released in January 2013. DTE Electric will continue to pay fees to the U.S. government's nuclear waste fund pending further action by the D.C. Circuit. The federal government continues to maintain its legal obligation to accept spent nuclear fuel from Fermi 2 for permanent storage. Issues relating to long-term waste disposal policy and to the disposition of funds contributed by DTE Electric ratepayers to the federal waste fund await future governmental action.

Synthetic Fuel Guarantees

The Company discontinued the operations of its synthetic fuel production facilities throughout the United States as of December 31, 2007. The Company 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 and will survive until 90 days after expiration of all applicable statutes of limitations. The Company estimates that its maximum potential liability under these guarantees at September 30, 2013 is approximately $1.2 billion. Payment under these guarantees is considered remote.

Reduced Emissions Fuel Guarantees

The Company has provided certain guarantees and indemnities in conjunction with the sales of interests in its reduced emissions fuel facilities. The guarantees cover potential commercial, environmental, and tax-related obligations and will survive until 90 days after expiration of all applicable statutes of limitations. The Company estimates that its maximum potential liability under these guarantees at September 30, 2013 is approximately $125 million. Payment under these guarantees is considered remote.

Other Guarantees

In certain limited circumstances, the Company enters into contractual guarantees. The Company may guarantee another entity’s obligation in the event it fails to perform. The Company may provide guarantees in certain indemnification agreements. Finally, the Company may provide indirect guarantees for the indebtedness of others. The Company’s guarantees are not individually material with maximum potential payments totaling $60 million at September 30, 2013. Payment under these guarantees is considered remote.

The Company 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 September 30, 2013, the Company had approximately $41 million of performance bonds outstanding. In the event that such bonds are called for nonperformance, the Company would be obligated to reimburse the issuer of the performance bond. The Company 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

Our contracts with several bargaining units for the majority of our represented employees were due to expire in June 2013, October 2013 and June 2014. Early negotiations resulted in new contracts that became effective in March 2013. The new contracts will expire in March, June and October 2017.

Purchase Commitments

As of September 30, 2013, the Company was party to numerous long-term purchase commitments relating to a variety of goods and services required for the Company’s business. These agreements primarily consist of fuel supply commitments, renewable energy contracts and energy trading contracts. The Company estimates that these commitments will be approximately $6.2 billion from 2013 through 2052.

The Company also estimates that 2013 capital expenditures will be approximately $2.1 billion. The Company has made certain commitments in connection with expected capital expenditures.

Bankruptcies

The Company purchases and sells electricity, natural gas, coal, coke and other energy products from and to governmental entities and numerous companies operating in the steel, automotive, energy, retail, financial and other industries. Certain of its customers have filed for bankruptcy protection under the U.S. Bankruptcy Code. The Company regularly reviews contingent matters relating to these customers and its purchase and sale contracts and records provisions for amounts considered at risk of probable loss. The Company believes its accrued amounts are adequate for probable loss.

The Company's utilities provide services to the city of Detroit, Michigan (Detroit). Detroit filed for Chapter 9 bankruptcy protection on July 18, 2013. The Company had pre-petition accounts receivable of approximately $20 million outstanding as of the bankruptcy filing date. Detroit has been paying amounts owed in a timely manner and its accounts are substantially current. The Company does not expect Detroit's bankruptcy filing to have a material impact on its financial results.

Other Contingencies

The Company is 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 Company cannot predict the final disposition of such proceedings. The Company regularly reviews legal matters and records provisions for claims that it can estimate and are considered probable of loss. The resolution of these pending proceedings is not expected to have a material effect on the Company’s operations or financial statements in the periods they are resolved.

See Notes 4 and 7 for a discussion of contingencies related to derivatives and regulatory matters.

XML

DEI Document	9 Months Ended
	Sep. 30, 2013
Entity Registrant Name	DTE ENERGY CO
Entity Central Index Key	0000936340
Current Fiscal Year End Date	--09-30
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Sep. 30, 2013
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Common Stock, Shares Outstanding	176,797,248

XML

Retirement Benefits and Trusteed Assets (Notes)

9 Months Ended

Sep. 30, 2013

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

Pension and Other Postretirement Benefits Disclosure [Text Block]

RETIREMENT BENEFITS AND TRUSTEED ASSETS

The following table details the components of net periodic benefit costs for pension benefits and other postretirement benefits:

	Pension Benefits						Other Postretirement Benefits
	2013			2012			2013			2012
Three Months Ended September 30	(In millions)
Service cost	$	22		$	20		$	9		$	15
Interest cost	49			51			21			29
Expected return on plan assets	(67		)	(61		)	(28		)	(23		)
Amortization of:
Net actuarial loss	55			48			16			21
Prior service credit	—			—			(36		)	(6		)
Net periodic benefit cost (credit)	$	59		$	58		$	(18	)	$	36

	Pension Benefits						Other Postretirement Benefits
	2013			2012			2013			2012
Nine Months Ended September 30	(In millions)
Service cost	$	71		$	61		$	37		$	51
Interest cost	144			153			66			90
Expected return on plan assets	(200		)	(183		)	(82		)	(69		)
Amortization of:
Net actuarial loss	156			133			48			60
Prior service credit	—			—			(95		)	(20		)
Net transition liability	—			—			—			1
Settlements	—			2			—			—
Net periodic benefit cost (credit)	$	171		$	166		$	(26	)	$	113

Pension and Other Postretirement Contributions

During the first nine months of 2013, the Company contributed $250 million to its pension plans, including contributions of DTE Energy common stock of $200 million. See Note 8. At the discretion of management, and depending upon financial market conditions, the Company may make up to an additional $25 million contribution to its pension plans in 2013.

In January 2013, the Company contributed $145 million to its other postretirement benefit plans. At the discretion of management, the Company may make up to an additional $120 million contribution to its other postretirement benefit plans in 2013.

Re-Measurement of Other Postretirement Benefit Obligation

In March 2013, the Company reached agreements on new four-year labor contracts with certain represented employees under several bargaining units. As a term of the agreements, the Company replaced sponsored retiree medical, prescription drug and dental coverage for future Medicare eligible retirees with a Retiree Health Care Allowance (RHCA) account of $3,250 per year. The modification in retiree health coverage will reduce future postretirement benefit costs.

Based on the impact of such benefit cost savings on the financial statements, the Company re-measured its retiree health plan as of March 31, 2013. In performing the re-measurement, the Company updated its significant actuarial assumptions, including an adjustment to the discount rate from 4.15% at December 31, 2012 to 4.30% at March 31, 2013. Plan assets were also updated to reflect fair value as of the re-measurement date. As a result of the re-measurement, the accumulated postretirement benefit obligation (APBO) was reduced by $258 million. The Company's Accrued postretirement benefit liability at March 31, 2013 was $721 million as compared to $1.2 billion at December 31, 2012, a reduction of $439 million. The reduction reflects the impact of the re-measurement of the plan, January 2013 plan contributions and recognition of first quarter 2013 postretirement benefit costs and benefit payments.

Beginning April 2013, net postretirement benefit costs were recorded based on the updated actuarial assumptions and benefit changes resulting from the new labor contracts. As a result of the re-measurement, fiscal year 2013 postretirement benefit costs are expected to decrease by approximately $69 million to an annual net benefit of approximately $40 million.

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Asset Retirement Obligations (Details) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2013
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations	$ 1,719
Accretion	79
Liabilities Incurred	1
Liabilities Settled	(12)
Revision in estimated cash flows	13
Asset retirement obligations	$ 1,800

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Discontinued Operations Discontinued Operations (Details Textuals)	Dec. 31, 2012
Discontinued Operations and Disposal Groups [Abstract]
Percentage of Equity Sold	100.00%