DTE Energy (DTE) 10-K 14 Feb 14 2013 Q4 Annual report Financial data

DEI_Document

DEI Document (USD $)	12 Months Ended
In Billions, except Share data, unless otherwise specified	Dec. 31, 2013	Jan. 31, 2014	Jun. 30, 2013
Entity Registrant Name	'DTE ENERGY CO	'	'
Entity Central Index Key	'0000936340	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Accelerated Filer	'	'
Document Type	'10-K	'	'
Document Period End Date	31-Dec-13	'	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'Q4	'	'
Amendment Flag	'false	'	'
Entity Common Stock, Shares Outstanding	'	177,086,236	'
Entity Well-known Seasoned Issuer	'No	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Public Float	'	'	$11.70

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Statement [Abstract]	'	'	'
Operating Revenue	$9,661	$8,791	$8,858
Operating Expenses	'	'	'
Fuel, purchased power and gas	4,055	3,296	3,537
Operation and maintenance	2,978	2,892	2,612
Depreciation, depletion and amortization	1,094	995	977
Taxes other than income	340	332	310
Asset (gains) and losses, reserves and impairments, net	-9	-3	1
Total operating expenses	8,458	7,512	7,437
Operating Income	1,203	1,279	1,421
Other (Income) and Deductions	'	'	'
Interest expense	436	440	488
Interest income	-9	-10	-10
Other Income	-201	-173	-117
Other expenses	55	62	69
Total Other (Income) and Deductions	281	319	430
Income Before Income Taxes	922	960	991
Income Tax Expense	254	286	268
Income from Continuing Operations	668	674	723
Discontinued Operations Income (Loss), net of tax	0	-56	-3
Net Income	668	618	720
Less: Net Income Attributable to Noncontrolling Interests	7	8	9
Net Income Attributable to DTE Energy Company	$661	$610	$711
Basic Earnings per Common Share	'	'	'
Income from continuing operations	$3.76	$3.89	$4.21
Income (Loss) from Discontinued Operations, Net of Tax, Per Basic Share	$0	($0.33)	($0.02)
Total Basic Earnings per Common Share	$3.76	$3.56	$4.19
Diluted Earnings per Common Share	'	'	'
Income from continuing operations	$3.76	$3.88	$4.20
Income (Loss) from Discontinued Operations, Net of Tax, Per Diluted Share	$0	($0.33)	($0.02)
Total Diluted Earnings per Common Share	$3.76	$3.55	$4.18
Weighted Average Common Shares Outstanding	'	'	'
Basic	175	171	169
Weighted Average Number Diluted Shares Outstanding Adjustment	175	172	170
Dividends Declared per Common Share	$2.59	$2.42	$2.32

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Statement of Income and Comprehensive Income [Abstract]	'	'	'
Net Income	$668	$618	$720
Other comprehensive income (loss), net of tax:	'	'	'
Benefit obligations, net of taxes of $13, $(1) and $(5)	22	-2	-9
Net unrealized gains on investments during the period, net of taxes of $1, $1 and $—	2	1	0
Foreign currency translation, net of taxes of $(1), $— and $—	-2	1	0
Other Comprehensive Income (Loss), Net of Tax	22	0	-9
Comprehensive income	690	618	711
Less: Comprehensive income attributable to noncontrolling interests	7	8	9
Comprehensive income attributable to DTE Energy Company	$683	$610	$702

Consolidated_Statements_of_Com1

Consolidated Statements of Comprehensive Income (Parenthetical) (Parentheticals) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Tax	$13	($1)	($5)
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Tax	0	0	0
Other Comprehensive Income (Loss), Unrealized Holding Gain (Loss) on Securities Arising During Period, Tax	1	1	0
Other Comprehensive Income (Loss), Foreign Currency Translation Gain (Loss) Arising During Period, Tax	($1)	$0	$0

Consolidated_Statements_of_Fin

Consolidated Statements of Financial Position (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Current Assets	'	'
Cash and cash equivalents	$52	$65
Restricted cash, principally Securitization	123	122
Accounts receivable (less allowance for doubtful accounts of $55 and $62, respectively)	'	'
Customer	1,542	1,336
Other	127	126
Inventories	'	'
Fuel and gas	363	527
Materials and supplies	265	234
Derivative assets	99	108
Regulatory assets	26	182
Other	209	215
Total Current Assets	2,806	2,915
Investments	'	'
Nuclear decommissioning trust funds	1,191	1,037
Other	603	554
Total Investments	1,794	1,591
Property	'	'
Property, plant and equipment	25,123	23,631
Less accumulated depreciation, depletion and amortization	-9,323	-8,947
Property, plant and equipment, net	15,800	14,684
Other Assets	'	'
Goodwill	2,018	2,018
Regulatory assets	2,837	4,235
Securitized regulatory assets	231	413
Intangible assets	122	135
Notes receivable	102	112
Derivative assets	27	39
Other	198	197
Total Noncurrent Assets	5,535	7,149
Total Assets	25,935	26,339
Current Liabilities	'	'
Accounts payable	962	848
Accrued interest	90	93
Dividends payable	116	107
Short-term borrowings	131	240
Current portion long-term debt, including capital leases	898	817
Derivative liabilities	195	125
Regulatory liabilities	302	89
Other	495	449
Total Current Liabilities	3,189	2,768
Long-Term Debt (net of current portion)	'	'
Mortgage bonds, notes and other	6,618	6,220
Securitization bonds	105	302
Junior subordinated debentures	480	480
Capital lease obligations	11	12
Total Long-Term Debt (net of current portion)	7,214	7,014
Other Liabilities	'	'
Deferred income taxes	3,321	3,191
Regulatory liabilities	862	1,031
Asset retirement obligations	1,827	1,719
Unamortized investment tax credit	47	56
Derivative liabilities	43	26
Accrued pension liability	653	1,498
Accrued postretirement liability	350	1,160
Nuclear decommissioning	178	159
Other	297	306
Total Noncurrent Liabilities	7,578	9,146
Equity	'	'
Common stock, without par value, 400,000,000 shares authorized, 177,087,230 and 172,351,680 shares issued and outstanding, respectively	3,907	3,587
Retained earnings	4,150	3,944
Accumulated other comprehensive loss	-136	-158
Total DTE Energy Company Equity	7,921	7,373
Noncontrolling interests	33	38
Total Equity	7,954	7,411
Total Liabilities and Equity	$25,935	$26,339

Consolidated_Statements_of_Fin1

Consolidated Statements of Financial Position (Parenthetical) (Parentheticals) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, except Share data, unless otherwise specified
Allowance for doubtful accounts	$55	$62
Common stock, par value	$0	$0
Common stock, shares authorized	400,000,000	400,000,000
Common stock, shares issued	177,087,230	172,351,680
Common stock, shares outstanding	177,087,230	172,351,680

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating Activities	'	'	'
Net Income	$668	$618	$720
Adjustments to reconcile net income to net cash from operating activities:	'	'	'
Depreciation, depletion and amortization	1,094	1,018	995
Nuclear fuel amortization	38	29	46
Allowance for equity funds used during construction	-15	-13	-6
Deferred income taxes	164	47	220
Loss on sale of non-utility business	0	83	0
Asset (gains) and losses, reserves and impairments, net	-8	1	-21
Changes in assets and liabilities:	'	'	'
Accounts receivable, net	-154	52	71
Inventories	123	35	-129
Accounts payable	14	40	-23
Derivative assets and liabilities	107	53	-94
Accrued pension obligation	-644	280	432
Accrued postretirement obligation	-526	-323	209
Regulatory assets and liabilities	1,269	278	-662
Other assets	-24	55	44
Other liabilities	48	-44	206
Net cash from operating activities	2,154	2,209	2,008
Investing Activities	'	'	'
Plant and equipment expenditures b utility	-1,534	-1,451	-1,382
Plant and equipment expenditures b non-utility	-342	-369	-102
Proceeds from sale of non-utility business	0	255	0
Proceeds from sale of assets	36	38	18
Restricted cash for debt redemption, principally Securitization	-1	2	-5
Acquisition, Net of Cash Acquired	0	-198	0
Proceeds from sale of nuclear decommissioning trust fund assets	1,118	759	833
Investment in nuclear decommissioning trust funds	-1,134	-764	-850
Other	-49	-41	-72
Net cash used for investing activities	-1,906	-1,769	-1,560
Financing Activities	'	'	'
Issuance of long-term debt, net of issuance costs	1,234	759	1,179
Redemption of long-term debt	-961	-639	-1,455
Short-term borrowings, net	-109	-179	269
Issuance of common stock	39	39	0
Repurchase of common stock	0	0	-18
Dividends on common stock	-445	-407	-389
Other	-19	-16	-31
Net cash used for financing activities	-261	-443	-445
Net Increase (Decrease) in Cash and Cash Equivalents	-13	-3	3
Cash and Cash Equivalents at Beginning of Period	65	68	65
Cash and Cash Equivalents at End of Period	52	65	68
Supplemental disclosure of cash information	'	'	'
Cash paid (received) for interest (net of interest capitalized)	418	438	485
Cash paid (received) for Income Taxes	121	173	-205
Supplemental disclosure of non-cash information	'	'	'
Common stock issued for employee benefit and compensation plans	293	155	15
Plant and equipment expenditures in accounts payable	$329	$235	$212

Consolidated_Statements_of_Cha

Consolidated Statements of Changes in Equity (USD $)	Total	Common Stock [Member]	Retained Earnings	Accumulated Translation Adjustment [Member]	Other Postretirement Benefit Plan, Defined Benefit [Member]	Accumulated Net Unrealized Investment Gain (Loss) [Member]	Accumulated Other Comprehensive Loss	Non-controlling Interest
In Millions, except Share data
Beginning Balance at Dec. 31, 2010	$6,767	$3,440	$3,431	'	'	'	($149)	$45
Beginning Balance, shares at Dec. 31, 2010	'	169,428,000	'	'	'	'	'	'
Net Income	720	'	711	'	'	'	'	9
Dividends declared on common stock	-392	'	-392	'	'	'	'	'
Repurchase of common stock, Shares	'	-1,184,000	'	'	'	'	'	'
Repurchase of Common Stock, Value	-58	-58	'	'	'	'	'	'
Other Comprehensive Income (Loss), Net of Tax	-9	'	'	'	-9	'	'	'
Stock-based compensation, distributions to noncontrolling interests and other, Shares	'	1,003,000	'	'	'	'	'	'
Stock-based compensation, distributions to noncontrolling interests and other	25	35	'	'	'	'	'	-10
Ending Balance at Dec. 31, 2011	7,053	3,417	3,750	'	'	'	-158	44
Ending Balance, shares at Dec. 31, 2011	'	169,247,000	'	'	'	'	'	'
Net Income	618	'	610	'	'	'	'	8
Dividends declared on common stock	-414	'	-414	'	'	'	'	'
Issuance of common stock, Shares	'	684,000	'	'	'	'	'	'
Issuance of common stock, Value	39	39	'	'	'	'	'	'
Contribution of Common Stock to Pension Plan Shares	'	1,335,000	'	'	'	'	'	'
Contribution of Common Stock to Pension Plan	80	80	'	'	'	'	'	'
Other Comprehensive Income (Loss), Net of Tax	0	'	'	1	-2	1	'	'
Stock-based compensation, distributions to noncontrolling interests and other, Shares	'	1,086,000	'	'	'	'	'	'
Stock-based compensation, distributions to noncontrolling interests and other	35	51	-2	'	'	'	'	-14
Ending Balance at Dec. 31, 2012	7,411	3,587	3,944	'	'	'	-158	38
Ending Balance, shares at Dec. 31, 2012	172,351,680	172,352,000	'	'	'	'	'	'
Net Income	668	'	661	'	'	'	'	7
Dividends declared on common stock	-454	'	-454	'	'	'	'	'
Issuance of common stock, Shares	'	589,000	'	'	'	'	'	'
Issuance of common stock, Value	39	39	'	'	'	'	'	'
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	22	'	'	-2	22	2	'	'
Stock-based compensation, distributions to noncontrolling interests and other, Shares	'	1,120,000	'	'	'	'	'	'
Stock-based compensation, distributions to noncontrolling interests and other	68	81	-1	'	'	'	'	-12
Ending Balance at Dec. 31, 2013	$7,954	$3,907	$4,150	'	'	'	($136)	$33
Ending Balance, shares at Dec. 31, 2013	177,087,230	177,087,000	'	'	'	'	'	'

Organization_and_Basis_of_Pres

Organization and Basis of Presentation (Notes)	12 Months Ended
	Dec. 31, 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, the MDEQ and CFTC.
	References in this Report to “Company” or “DTE” are to DTE Energy and its subsidiaries, collectively.
	Basis of Presentation
	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.
	Certain prior year balances were reclassified to match the current year’s financial statement presentation. Such revisions included an increase in the Consolidated Statements of Cash Flows line items for (i) Proceeds from sale of nuclear decommissioning trust funds, and (ii) Investment in nuclear decommissioning trust funds by $662 million and $753 million for the years ended December 31, 2012 and 2011, respectively. These revisions were needed to properly state the gross purchases and sales activity in the nuclear decommissioning trust fund for the respective years. The totals of Net cash used in investing activities for both 2012 and 2011 were unchanged by these revisions. The revisions noted above are not deemed material, individually or in the aggregate, to the prior period consolidated financial statements.
	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 plant. 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 are 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 December 31, 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 December 31, 2013 and 2012. All assets and liabilities of a consolidated VIE are presented where it has been determined that a consolidated VIE has either (1) assets that can be used only to settle obligations of the VIE or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary. 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.
		31-Dec-13						31-Dec-12
		Securitization		Other		Total		Securitization		Other		Total
		(In millions)
	ASSETS
	Cash and cash equivalents	$	—	$	12	$	12	$	—	$	10	$	10
	Restricted cash	100		8		108		102		7		109
	Accounts receivable	34		16		50		34		7		41
	Inventories	—		118		118		—		141		141
	Other current assets	—		1		1		—		1		1
	Property, plant and equipment	—		99		99		—		93		93
	Securitized regulatory assets	231		—		231		413		—		413
	Other assets	4		8		12		7		11		18
		$	369	$	262	$	631	$	556	$	270	$	826
	LIABILITIES
	Accounts payable and accrued current liabilities	$	7	$	23	$	30	$	11	$	14	$	25
	Current portion long-term debt, including capital leases	196		9		205		177		8		185
	Current regulatory liabilities	43		—		43		50		—		50
	Other current liabilities	—		4		4		—		4		4
	Mortgage bonds, notes and other	—		21		21		—		25		25
	Securitization bonds	105		—		105		302		—		302
	Capital lease obligations	—		7		7		—		11		11
	Other long-term liabilities	8		2		10		7		2		9
		$	359	$	66	$	425	$	547	$	64	$	611
	Amounts for non-consolidated VIEs as of December 31, 2013 and 2012 are as follows:
		December 31,		December 31,
		2013		2012
		(In millions)
	Other investments	$	141	$	130
	Notes receivable	$	8	$	6

Significant_Accounting_Policie

Significant Accounting Policies (Notes)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Significant Accounting Policies	'
	SIGNIFICANT ACCOUNTING POLICIES
	Revenues
	Revenues from the sale and delivery of electricity, and the sale, delivery and storage of natural gas are recognized as services are provided. DTE Electric and DTE Gas record revenues for electricity and gas provided but unbilled at the end of each month. Rates for DTE Electric and DTE Gas include provisions to adjust billings for fluctuations in fuel and purchased power costs, cost of natural gas and certain other costs. Revenues are adjusted for differences between actual costs subject to reconciliation and the amounts billed in current rates. Under or over recovered revenues related to these cost recovery mechanisms are recorded on the Consolidated Statements of Financial Position and are recovered or returned to customers through adjustments to the billing factors.
	See Note 11 for further discussion of recovery mechanisms authorized by the MPSC.
	Non-utility businesses recognize revenues as services are provided and products are delivered. See Note 4 for discussion of derivative contracts.
	Other Income
	Other income is recognized for non-operating income such as equity earnings, interest and dividends, allowance for funds using during construction and contract services. Power & Industrial Projects also recognizes Other income in connection with the sale of membership interests in reduced emissions fuel facilities to investors. In exchange for the cash received, the investors will receive a portion of the economic attributes of the facilities, including income tax attributes. The transactions are not treated as a sale of membership interests for financial reporting purposes. Other income is considered earned when refined coal is produced and tax credits are generated. Power & Industrial Projects recognized approximately $81 million, $63 million, and $15 million of Other income for the years ended December 31, 2013, 2012, and 2011, respectively.
	Accounting for ISO Transactions
	DTE Electric participates in the energy market through MISO. MISO requires that we submit hourly day-ahead, real- time and FTR bids and offers for energy at locations across the MISO region. DTE Electric accounts for MISO transactions on a net hourly basis in each of the day-ahead, real-time and FTR markets and net transactions across all MISO energy market locations. In any single hour DTE Electric records net purchases in Fuel, purchased power and gas and net sales in Operating revenues on the Consolidated Statements of Operations.
	Energy Trading participates in the energy markets through various independent system operators and regional transmission organizations (ISOs and RTOs). These markets require that Energy Trading submits hourly day-ahead, real-time bids and offers for energy at locations across each region. Energy Trading submits bids in the annual and monthly auction revenue rights and FTR auctions to the regional transmission organizations. Energy Trading accounts for these transactions on a net hourly basis for the day-ahead, real-time and FTR markets. These transactions are related to trading contracts which are presented on a net basis in Operating Revenues in the Consolidated Statements of Operations.
	DTE Electric and Energy Trading record accruals for future net purchases adjustments based on historical experience, and reconcile accruals to actual costs when invoices are received from MISO, and other ISOs and RTOs.
	Comprehensive Income (Loss)
	Comprehensive income (loss) is the change in common shareholders’ equity during a period from transactions and events from non-owner sources, including net income. As shown in the following tables, amounts recorded to accumulated other comprehensive loss for the year ended December 31, 2013 include unrealized gains and losses from derivatives accounted for as cash flow hedges, unrealized gains and losses on available-for-sale securities, 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 Year Ended December 31, 2013
		Net			Net			Benefit			Foreign			Total
		Unrealized			Unrealized			Obligations			Currency
		Gain/(Loss)			Gain/(Loss)			(b)			Translation
		on Derivatives			on Investments
		(In millions)
	Beginning balances December 31, 2012	$	(4	)	$	(8	)	$	(148	)	$	2		$	(158	)
	Other comprehensive income (loss) before reclassifications	—			2			13			(2		)	13
	Amounts reclassified from accumulated other comprehensive income (loss)	—			—			9			—			9
	Net current-period other comprehensive income (loss)	—			2			22			(2		)	22
	Ending balances December 31, 2013	$	(4	)	$	(6	)	$	(126	)	$	—		$	(136	)
	______________________________________
	(a)	All amounts are net of tax.
	(b)	The amounts reclassified from accumulated other comprehensive income (loss) are included in the computation of the net periodic pension and other postretirement benefit costs (see Note 20).
	Cash Equivalents and Restricted Cash
	Cash and cash equivalents include cash on hand, cash in banks and temporary investments purchased with remaining maturities of three months or less. Restricted cash consists of funds held to satisfy requirements of certain debt, primarily Securitization bonds, and partnership operating agreements. Restricted cash designated for interest and principal payments within one year is classified as a current asset.
	Receivables
	Accounts receivable are primarily composed of trade receivables and unbilled revenue. Our accounts receivable are stated at net realizable value.
	The allowance for doubtful accounts for DTE Electric and DTE Gas is generally calculated using the aging approach that utilizes rates developed in reserve studies. We establish an allowance for uncollectible accounts based on historical losses and management’s assessment of existing economic conditions, customer trends, and other factors. Customer accounts are generally considered delinquent if the amount billed is not received by the due date, which is typically in 21 days, however, factors such as assistance programs may delay aggressive action. We assess late payment fees on trade receivables based on past-due terms with customers. Customer accounts are written off when collection efforts have been exhausted. The time period for write-off is 150 days after service has been terminated.
	The customer allowance for doubtful accounts for our other businesses is calculated based on specific review of probable future collections based on receivable balances in excess of 30 days.
	Unbilled revenues of $815 million and $686 million are included in customer accounts receivable at December 31, 2013 and 2012, respectively.
	Notes Receivable
	Notes receivable, or financing receivables, are primarily comprised of capital lease receivables and loans and are included in Notes receivable and Other current assets on the Company’s Consolidated Statements of Financial Position.
	Notes receivable are typically considered delinquent when payment is not received for periods ranging from 60 to 120 days. The Company ceases accruing interest (nonaccrual status), considers a note receivable impaired, and establishes an allowance for credit loss when it is probable that all principal and interest amounts due will not be collected in accordance with the contractual terms of the note receivable. Cash payments received on nonaccrual status notes receivable, that do not bring the account contractually current, are first applied to contractually owed past due interest, with any remainder applied to principal. Accrual of interest is generally resumed when the note receivable becomes contractually current.
	In determining the allowance for credit losses for notes receivable, we consider the historical payment experience and other factors that are expected to have a specific impact on the counterparty’s ability to pay. In addition, the Company monitors the credit ratings of the counterparties from which we have notes receivable.
	Inventories
	The Company generally values inventory at average cost.
	Natural gas inventory of $4 million and $37 million as of December 31, 2013 and 2012, respectively, at DTE Gas is determined using the last-in, first-out (LIFO) method. At December 31, 2013, the replacement cost of gas remaining in storage exceeded the LIFO cost by $170 million. At December 31, 2012, the replacement cost of gas remaining in storage exceeded the LIFO cost by $113 million.
	Property, Retirement and Maintenance, and Depreciation, Depletion and Amortization
	Property is stated at cost and includes construction-related labor, materials, overheads and, for utility property, an allowance for funds used during construction (AFUDC). The cost of utility properties retired is charged to accumulated depreciation. Expenditures for maintenance and repairs are charged to expense when incurred, except for Fermi 2.
	Utility property at DTE Electric and DTE Gas is depreciated over its estimated useful life using straight-line rates approved by the MPSC.
	Non-utility property is depreciated over its estimated useful life using the straight-line and units of production methods.
	Depreciation, depletion and amortization expense also includes the amortization of certain regulatory assets.
	Approximately $26 million and $12 million of expenses related to Fermi 2 refueling outages were accrued at December 31, 2013 and 2012, respectively. Amounts are accrued on a pro-rata basis, generally over an 18-month period, that coincides with scheduled refueling outages at Fermi 2. This accrual of outage costs matches the regulatory recovery of these costs in rates set by the MPSC. See Note 11.
	The cost of nuclear fuel is capitalized. The amortization of nuclear fuel is included within Fuel, purchased power, and gas in the Consolidated Statements of Operations and is recorded using the units-of-production method.
	Long-Lived Assets
	Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of an asset may not be recoverable. If the carrying amount of the asset exceeds the expected discounted future cash flows generated by the asset, an impairment loss is recognized resulting in the asset being written down to its estimated fair value. Assets to be disposed of are reported at the lower of the carrying amount or fair value, less costs to sell.
	Intangible Assets
	The Company has certain intangible assets relating to emission allowances, renewable energy credits and non-utility contracts as shown below:
		December 31,			December 31,
		2013			2012
		(In millions)
	Emission allowances	$	2		$	6
	Renewable energy credits	51			44
	Contract intangible assets	126			139
		179			189
	Less accumulated amortization	45			34
	Intangible assets, net	134			155
	Less current intangible assets	12			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 1 to 28 years. Intangible assets amortization expense was $14 million in 2013, $6 million in 2012 and $5 million in 2011.
The following table summarizes the estimated amortization expense expected to be recognized during each year through 2018:
Estimated amortization expense	(In millions)
2014	$	13
2015	$	12
2016	$	11
2017	$	8
2018	$	8
Excise and Sales Taxes
The Company records the billing of excise and sales taxes as a receivable with an offsetting payable to the applicable taxing authority, with no net impact on the Consolidated Statements of Operations.
Deferred Debt Costs
The costs related to the issuance of long-term debt are deferred and amortized over the life of each debt issue. In accordance with MPSC regulations applicable to the Company’s electric and gas utilities, the unamortized discount, premium and expense related to utility debt redeemed with a refinancing are amortized over the life of the replacement issue. Discount, premium and expense on early redemptions of debt associated with non-utility operations are charged to earnings.
Investments in Debt and Equity Securities
The Company generally classifies investments in debt and equity securities as either trading or available-for-sale and has recorded such investments at market value with unrealized gains or losses included in earnings or in other comprehensive income or loss, respectively. Changes in the fair value of Fermi 2 nuclear decommissioning investments are recorded as adjustments to regulatory assets or liabilities, due to a recovery mechanism from customers. The Company’s equity investments are reviewed for impairment each reporting period. If the assessment indicates that the impairment is other than temporary, a loss is recognized resulting in the equity investment being written down to its estimated fair value. See Note 3.
Government Grants
Grants are recognized when there is reasonable assurance that the grant will be received and that any conditions associated with the grant will be met. When grants are received related to Property, Plant and Equipment, the Company reduces the cost of the assets on the Consolidated Statements of Financial Position, resulting in lower depreciation expense over the life of the associated asset. Grants received related to expenses are reflected as a reduction of the associated expense in the period in which the expense is incurred.
DTE Energy Foundation
Charitable contributions to the DTE Energy Foundation were $18 million, $21 million, and $21 million for the years ended December 31, 2013, 2012 and 2011, respectively. The DTE Energy Foundation is a non-consolidated not-for-profit private foundation, the purpose of which is to contribute to and assist charitable organizations and does not serve a direct business or political purpose of DTE.
Other Accounting Policies
See the following notes for other accounting policies impacting the Company’s consolidated financial statements:
Note		Title
3		Fair Value
4		Financial and Other Derivative Instruments
10		Asset Retirement Obligations
11		Regulatory Matters
12		Income Taxes
21		Stock-based Compensation

Fair_Value_Notes

Fair Value (Notes)	12 Months Ended
	Dec. 31, 2013
Fair Value Disclosures [Abstract]	'
Fair Value	'
	FAIR VALUE
	Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated or generally unobservable inputs. The 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 December 31, 2013 and 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 December 31, 2013 and 2012:
		31-Dec-13																				31-Dec-12
		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)	$	10			$	115			$	—			$	—			$	125			$	—			$	123		$	—		$	—		$	123
	Nuclear decommissioning trusts	779				412				—				—				1,191				694				343			—			—			1,037
	Other investments (c) (d)	92				44				—				—				136				66				44			—			—			110
	Derivative assets:
	Commodity Contracts:
	Natural Gas	273				89				34				(382		)		14				555				66			24			(605		)	40
	Electricity	—				261				139				(291		)		109				—				226			134			(258		)	102
	Other	33				1				3				(34		)		3				6				3			2			(6		)	5
	Total derivative assets	306				351				176				(707		)		126				561				295			160			(869		)	147
	Total	$	1,187			$	922			$	176			$	(707	)		$	1,578			$	1,321			$	805		$	160		$	(869	)	$	1,417
	Liabilities:
	Derivative liabilities:
	Commodity Contracts:
	Natural Gas	$	(277	)		$	(140	)		$	(86	)		$	395			$	(108	)		$	(526	)		$	(73	)	$	(62	)	$	605		$	(56	)
	Electricity	—				(272		)		(126		)		269				(129		)		—				(240		)	(111		)	258			(93		)
	Other	(32		)		(2		)		—				34				—				(6		)		(1		)	—			6			(1		)
	Other derivative contracts (f)	—				(1		)		—				—				(1		)		—				(1		)	—			—			(1		)
	Total derivative liabilities	(309		)		(415		)		(212		)		698				(238		)		(532		)		(315		)	(173		)	869			(151		)
	Total	$	(309	)		$	(415	)		$	(212	)		$	698			$	(238	)		$	(532	)		$	(315	)	$	(173	)	$	869		$	(151	)
	Net Assets (liabilities) at the end of the period	$	878			$	507			$	(36	)		$	(9	)		$	1,340			$	789			$	490		$	(13	)	$	—		$	1,266
	Assets:
	Current	$	277			$	400			$	139			$	(592	)		$	224			$	493			$	372		$	120		$	(754	)	$	231
	Noncurrent (e)	910				522				37				(115		)		1,354				828				433			40			(115		)	1,186
	Total Assets	$	1,187			$	922			$	176			$	(707	)		$	1,578			$	1,321			$	805		$	160		$	(869	)	$	1,417
	Liabilities:
	Current	$	(268	)		$	(328	)		$	(177	)		$	578			$	(195	)		$	(466	)		$	(269	)	$	(144	)	$	754		$	(125	)
	Noncurrent	(41		)		(87		)		(35		)		120				(43		)		(66		)		(46		)	(29		)	115			(26		)
	Total Liabilities	$	(309	)		$	(415	)		$	(212	)		$	698			$	(238	)		$	(532	)		$	(315	)	$	(173	)	$	869		$	(151	)
	Net Assets (liabilities) at the end of the period	$	878			$	507			$	(36	)		$	(9	)		$	1,340			$	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 December 31, 2013, available-for-sale securities of $125 million included $109 million and $16 million of cash equivalents included in Restricted cash and Other investments on the Consolidated Statements of Financial Position, respectively. 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 on the Consolidated Statements of Financial Position, respectively.
	(c)	Excludes cash surrender value of life insurance investments.
	(d)	Available-for-sale equity securities of $7 million at December 31, 2013 and $5 million at December 31, 2012 are included in Other investments on the Consolidated Statements of Financial Position.
	(e)	Includes $136 million and $110 million of Other investments that are included in the Consolidated Statements of Financial Position in Other investments at December 31, 2013 and 2012, respectively.
	(f)	Includes Interest rate contracts and Foreign currency exchange contracts.
	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 years ended December 31, 2013 and 2012:
		Year Ended December 31, 2013																Year Ended December 31, 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				—				—				1				1				—				—			1
	Total gains (losses):
	Included in earnings	(32		)		75				—				43				(41		)		101				—			60
	Recorded in regulatory assets/liabilities	—				—				5				5				—				—				15			15
	Purchases, issuances and settlements:
Purchases	(8		)		1				—				(7		)		—				2				—			2
Issuances	—				(1		)		—				(1		)		—				—				—			—
Settlements	25				(85		)		(4		)		(64		)		(4		)		(112		)		(19		)	(135		)
Net Assets (Liabilities) as of December 31	$	(52	)		$	13			$	3			$	(36	)		$	(38	)		$	23			$	2		$	(13	)
The amount of total gains (losses) included in net income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2013 and 2012 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations	$	(49	)		$	48			$	—			$	(1	)		$	(33	)		$	91			$	—		$	58
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 years ended December 31, 2013 and 2012:
	Year Ended December 31, 2013											Year Ended December 31, 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				—				—			N/A				—
Transfers into Level 3 from	—			1				N/A				—			1				N/A
The following table presents the unobservable inputs related to Level 3 assets and liabilities as of December 31, 2013 and 2012:
		31-Dec-13
Commodity Contracts		Derivative Assets				Derivative Liabilities				Valuation Techniques		Unobservable Input		Range								Weighted Average
		(In millions)
Natural Gas		$	34			$	(86	)		Discounted Cash Flow		Forward basis price (per MMBtu)		$	(0.88	)	—	$	5.07	/MMBtu		$	(0.16	)/MMBtu
Electricity		$	139			$	(126	)		Discounted Cash Flow		Forward basis price (per MWh)		$	(7	)	—	$	15	/MWh		$	3	/MWh
		31-Dec-12
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 consists 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 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 December 31, 2013 and 2012:
	31-Dec-13																31-Dec-12
	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	$	41			$	—			$	—			$	41			$	39			$	—			$	—		$	39
Dividends payable	$	116			$	116			$	—			$	—			$	107			$	107			$	—		$	—
Short-term borrowings	$	131			$	—			$	131			$	—			$	240			$	—			$	240		$	—
Long-term debt	$	8,094			$	425			$	7,551			$	499			$	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. See Note 10.
The following table summarizes the fair value of the nuclear decommissioning trust fund assets:
	December 31,				December 31,
	2013				2012
	(In millions)
Fermi 2	$	1,172			$	1,021
Fermi 1	3				3
Low level radioactive waste	16				13
Total	$	1,191			$	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:
	Year Ended December 31
	2013				2012				2011
	(In millions)
Realized gains	$	83			$	37			$	46
Realized losses	$	(41	)		$	(31	)		$	(38	)
Proceeds from sales of securities	$	1,118			$	759			$	833
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:
	31-Dec-13								31-Dec-12
	Fair				Unrealized				Fair				Unrealized
	Value				Gains				Value				Gains
	(In millions)
Equity securities	$	730			$	201			$	631			$	122
Debt securities	442				12				399				27
Cash and cash equivalents	19				—				7				—
	$	1,191			$	213			$	1,037			$	149
At December 31, 2013, investments in the nuclear decommissioning trust funds consisted of approximately 61% in publicly traded equity securities, 37% in fixed debt instruments and 2% in cash equivalents. At December 31, 2012, investments in the nuclear decommissioning trust funds consisted of approximately 61% in publicly traded equity securities, 38% in fixed debt instruments and 1% in cash equivalents.
The debt securities at December 31, 2013 and 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 $31 million and $44 million of unrealized losses as Regulatory assets at December 31, 2013 and 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 2013, 2012 and 2011 for Fermi 1.
Other Securities
At December 31, 2013 and 2012, the securities were comprised primarily of money-market and equity securities. During the years ended December 31, 2013 and 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 December 31, 2013, 2012, and 2011 were $22 million, $11 million and $4 million, respectively.

Financial_and_Other_Derivative

Financial and Other Derivative Instruments (Notes)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedges, Assets [Abstract]	'
Financial and Other Derivative Instruments	'
	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 the 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 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 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 2014, 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 December 31, 2013 and 2012 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 December 31, 2013 and 2012:
		31-Dec-13								31-Dec-12
		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:
	Foreign currency exchange contracts	$	—			$	(1	)		$	—		$	—
	Commodity Contracts:
	Natural Gas	396				(503		)		645			(661		)
	Electricity	400				(398		)		360			(351		)
	Other	37				(34		)		11			(7		)
	Total derivatives not designated as hedging instruments:	$	833			$	(936	)		$	1,016		$	(1,019	)
	Total derivatives:
	Current	$	691			$	(773	)		$	862		$	(879	)
	Noncurrent	142				(163		)		154			(141		)
	Total derivatives	$	833			$	(936	)		$	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 $19 million and $63 million at December 31, 2013 and 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 December 31, 2013, the total cash collateral posted, net of cash collateral received, was $12 million. As of December 31, 2012, the total cash collateral received, net of cash collateral posted, was $20 million. As of December 31, 2013, derivative assets and derivative liabilities are shown net of cash collateral of $26 million and $17 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 $34 million and cash collateral received of $13 million not related to unrealized derivative positions as of December 31, 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 December 31, 2013 and 2012:
		31-Dec-13											31-Dec-12
		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	$	396			$	(382	)		$	14		$	645		$	(605	)	$	40
	Electricity	400				(291		)		109			360			(258		)	102
	Other	37				(34		)		3			11			(6		)	5
	Total derivative assets	$	833			$	(707	)		$	126		$	1,016		$	(869	)	$	147
	Derivative liabilities:
	Commodity Contracts:
	Natural Gas	$	(503	)		$	395			$	(108	)	$	(661	)	$	605		$	(56	)
	Electricity	(398		)		269				(129		)	(351		)	258			(93		)
	Other	(34		)		34				—			(7		)	6			(1		)
	Other derivative liabilities	(1		)		—				(1		)	(1		)	—			(1		)
	Total derivative liabilities	$	(936	)		$	698			$	(238	)	$	(1,020	)	$	869		$	(151	)
	The following table presents the netting offsets of derivative assets and liabilities at December 31, 2013 and 2012:
		31-Dec-13														31-Dec-12
		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	$	691			$	142			$	(773	)	$	(163	)	$	862		$	154		$	(879	)	$	(141	)
	Counterparty netting	(566		)		(115		)		566			115			(754		)	(115		)	754			115
Collateral adjustment	(26		)		—				12			5			—			—			—			—
Total derivatives as reported	$	99			$	27			$	(195	)	$	(43	)	$	108		$	39		$	(125	)	$	(26	)
The effect of derivatives not designated as hedging instruments on the Consolidated Statements of Operations for years ended December 31, 2013 and 2012 is as follows:
		Location of Gain		Gain (Loss)
		(Loss) Recognized		Recognized in
		in Income on Derivatives		Income on
				Derivatives for
				Years Ended
				December 31
Derivatives not Designated as Hedging Instruments				2013				2012
				(In millions)
Foreign currency exchange contracts		Operating Revenue		$	(1	)		$	—
Commodity Contracts:
Natural Gas		Operating Revenue		(48		)		(29		)
Natural Gas		Fuel, purchased power and gas		(44		)		25
Electricity		Operating Revenue		82				64
Other		Operating Revenue		—				5
Total				$	(11	)		$	65
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 $5 million in unrealized gains related to FTRs recognized in Regulatory liabilities for the year ended December 31, 2013, and $15 million in unrealized gains related to FTRs recognized in Regulatory liabilities, for the year ended December 31, 2012.
The following represents the cumulative gross volume of derivative contracts outstanding as of December 31, 2013:
Commodity		Number of Units
Natural Gas (MMBtu)		795,553,773
Electricity (MWh)		55,658,483
Foreign Currency Exchange ($ CAD)		65,074,206
FTR (MWh)		10,485,618
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 December 31, 2013, DTE Energy's contractual obligation 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 $406 million.
As of December 31, 2013, the Company had approximately $1,176 million of derivatives in net liability positions, for which hard triggers exist. Collateral of approximately $25 million has been posted against such liabilities, including cash and letters of credit. Associated derivative net asset positions for which contractual offset exists were approximately $902 million. The net remaining amount of approximately $249 million is derived from the $406 million noted above.

Goodwill_Notes

Goodwill (Notes)	12 Months Ended
	Dec. 31, 2013
Goodwill and Intangible Assets Disclosure [Abstract]	'
Goodwill Disclosure	'
	GOODWILL
	The Company has goodwill resulting from purchase business combinations.
	The change in the carrying amount of goodwill for the fiscal years ended December 31, 2013 and 2012 is as follows:
		2013		2012
		(In millions)
	Balance as of January 1	$	2,018	$	2,020
	Goodwill attributable to sale of Unconventional Gas Production business	—		(2		)
	Balance at December 31	$	2,018	$	2,018

Acquisition_Notes

Acquisition (Notes)	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Business Combination Disclosure [Text Block]	'
	ACQUISITION
	In the fourth quarter of 2012, the Company closed on the purchase of a portfolio of fourteen on-site energy projects from subsidiaries of Duke Energy Corporation and GDF Suez Energy North America, Inc. This acquisition provided a growth opportunity for the Company's Power and Industrial Projects segment that leverages its extensive energy-related operating experience and project management capabilities.
	The purchase of equity interests ranged from 46 percent to 100 percent of the project companies for a total purchase price of approximately $294 million, which consisted of $220 million paid in cash and assumption of approximately $74 million of debt. The debt assumed related to two project companies which have been deemed variable interest entities. DTE, however, was determined not to be the primary beneficiary and thus the VIEs' assets and liabilities are not included in the Company's Consolidated Statements of Financial Position. Therefore, the assumed debt was not included in the purchase price allocation table below. There was no exposure to loss related to the debt assumed as the customer of the project companies is obligated to pay the loans in the event of default or termination. The following table summarizes the fair value of the assets acquired and liabilities assumed as of the closing date:
		(In millions)
	Cash	$	22
	Accounts receivable	14
	Other current assets	8
	Property, plant and equipment	100
	Intangible assets	75
	Other noncurrent assets	9
	Current liabilities	(7		)
	Non-controlling interest	(1		)
	Total purchase price	$	220
	The intangible assets recorded as a result of the acquisition pertained to existing contracts and agreements, which were valued at approximately $75 million as of the closing date. The intangible assets are amortized on a straight line basis over a weighted-average amortization period of approximately eight years. The Company did not record any goodwill due to the acquisition.
	The Company's 2012 results of operations included revenue of $30 million and net income of $2 million associated with the acquired project companies for the approximate three-month period following the closing date. The pro forma results of operations have not been presented for DTE Energy because the effects of the acquisition were not material to our consolidated results of operations.

Discontinued_Operations_Notes

Discontinued Operations (Notes)	12 Months Ended
	Dec. 31, 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 sale resulted in gross proceeds of approximately $255 million, which resulted in a pre-tax loss of approximately $83 million ($55 million after tax). The activity of the discontinued business is shown below. The amounts exclude general corporate overhead costs, and related tax effects, and no portion of corporate interest costs were allocated to discontinued operations.
		2012			2011
		(In millions)
	Operating Revenues	$	55		$	39
	Operation and Maintenance	24			16
	Depreciation, Depletion and Amortization	23			18
	Taxes Other Than Income	4			3
	Asset (Gains) and Losses, Net	83			—
		134			37
	Operating Income (Loss)	(79		)	2
	Other (Income) and Deductions	6			6
	Loss Before Income Taxes	(85		)	(4		)
	Income Tax Expense (Benefit)	(29		)	(1		)
	Net Loss Attributable to DTE Energy Company	$	(56	)	$	(3	)

Property_Plant_and_Equipment_N

Property, Plant and Equipment (Notes)	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment Disclosure	'
	PROPERTY, PLANT AND EQUIPMENT
	Summary of property by classification as of December 31:
		2013				2012
	Property, Plant and Equipment	(In millions)
	DTE Electric
	Generation	$	11,127			$	10,383
	Distribution	7,603				7,306
	Total DTE Electric	18,730				17,689
	DTE Gas
	Distribution	2,834				2,704
	Storage	431				426
	Other	836				852
	Total DTE Gas	4,101				3,982
	Non-utility and other	2,292				1,960
	Total	25,123				23,631
	Less Accumulated Depreciation, Depletion and Amortization
	DTE Electric
	Generation	(4,004		)		(3,880		)
	Distribution	(2,947		)		(2,837		)
	Total DTE Electric	(6,951		)		(6,717		)
	DTE Gas
	Distribution	(1,129		)		(1,057		)
	Storage	(138		)		(132		)
	Other	(338		)		(365		)
	Total DTE Gas	(1,605		)		(1,554		)
	Non-utility and other	(767		)		(676		)
	Total	(9,323		)		(8,947		)
	Net Property, Plant and Equipment	$	15,800			$	14,684
	The Allowance for Funds used During Construction (AFUDC) capitalized was approximately $23 million and $20 million during 2013 and 2012, respectively.
	The composite depreciation rate for DTE Electric was approximately 3.4% in 2013 and 3.3% in 2012 and 2011. The composite depreciation rate for DTE Gas was 2.4% in 2013 and 2012, and 2.3% in 2011.
	The average estimated useful life for each major class of utility property, plant and equipment as of December 31, 2013 follows:
			Estimated Useful Lives in Years
	Utility		Generation		Distribution		Storage
	Electric		40		41		N/A
	Gas		N/A		50		53
	The estimated useful lives for major classes of non-utility assets and facilities ranges from 3 to 55 years.
	Capitalized software costs are classified as Property, plant and equipment and the related amortization is included in Accumulated depreciation, depletion and amortization on the Consolidated Statements of Financial Position. The Company capitalizes the costs associated with computer software it develops or obtains for use in its business. The Company amortizes capitalized software costs on a straight-line basis over the expected period of benefit, ranging from 3 to 15 years.
	Capitalized software costs amortization expense was $71 million in 2013, $68 million in 2012 and $65 million in 2011. The gross carrying amount and accumulated amortization of capitalized software costs at December 31, 2013 were $668 million and $384 million, respectively. The gross carrying amount and accumulated amortization of capitalized software costs at December 31, 2012 were $608 million and $313 million, respectively.
	Gross property under capital leases was $35 million and $32 million at December 31, 2013 and 2012, respectively. Accumulated amortization of property under capital leases was $21 million and $20 million at December 31, 2013 and 2012, respectively.

Jointly_Owned_Utility_Plant_No

Jointly Owned Utility Plant (Notes)	12 Months Ended
	Dec. 31, 2013
Jointly Owned Utility Plant, Net Ownership Amount [Abstract]	'
Jointly Owned Utility Plant [Text Block]	'
	JOINTLY OWNED UTILITY PLANT
	DTE Electric has joint ownership interest in two power plants, Belle River and Ludington Hydroelectric Pumped Storage. DTE Electric’s share of direct expenses of the jointly owned plants are included in Fuel, purchased power and gas and Operation and maintenance expenses in the Consolidated Statements of Operations. Ownership information of the two utility plants as of December 31, 2013 was as follows:
		Belle River			Ludington
					Hydroelectric
					Pumped Storage
	In-service date	1984-1985			1973
	Total plant capacity	1,270		MW	1,872		MW
	Ownership interest	(a)			49		%
	Investment in property, plant and equipment (in millions)	$	1,702		$	354
	Accumulated depreciation (in millions)	$	969		$	170
	_______________________________________
	(a)	DTE Electric's ownership interest is 63% in Unit No. 1, 81% of the facilities applicable to Belle River used jointly by the Belle River and St. Clair Power Plants and 75% in common facilities used at Unit No. 2.
	Belle River
	The Michigan Public Power Agency (MPPA) has an ownership interest in Belle River Unit No. 1 and other related facilities. The MPPA is entitled to 19% of the total capacity and energy of the plant and is responsible for the same percentage of the plant’s operation, maintenance and capital improvement costs.
	Ludington Hydroelectric Pumped Storage
	Consumers Energy Company has an ownership interest in the Ludington Hydroelectric Pumped Storage Plant. Consumers Energy is entitled to 51% of the total capacity and energy of the plant and is responsible for the same percentage of the plant’s operation, maintenance and capital improvement costs.

Asset_Retirement_Obligations_N

Asset Retirement Obligations (Notes)	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation [Abstract]	'
Asset Retirement Obligations	'
	ASSET RETIREMENT OBLIGATIONS
	The Company has a legal retirement obligation for the decommissioning costs for its Fermi 1 and Fermi 2 nuclear plants, dismantlement of facilities located on leased property and various other operations. The Company has conditional retirement obligations for gas pipelines, asbestos and PCB removal at certain of its power plants and various distribution equipment. The Company recognizes such obligations as liabilities at fair market value when they are incurred, which generally is at the time the associated assets are placed in service. Fair value is measured using expected future cash outflows discounted at our credit-adjusted risk-free rate. In its regulated operations, the Company recognizes regulatory assets or liabilities for timing differences in expense recognition for legal asset retirement costs that are currently recovered in rates.
	If a reasonable estimate of fair value cannot be made in the period in which the retirement obligation is incurred, such as for assets with indeterminate lives, the liability is recognized when a reasonable estimate of fair value can be made. Natural gas storage system assets, substations, manholes and certain other distribution assets have an indeterminate life. Therefore, no liability has been recorded for these assets.
	A reconciliation of the asset retirement obligations for 2013 follows:
		(In millions)
	Asset retirement obligations at December 31, 2012	$	1,719
	Accretion	106
	Liabilities incurred	5
	Liabilities settled	(13		)
	Revision in estimated cash flows	10
	Asset retirement obligations at December 31, 2013	$	1,827
	In 2001, DTE Electric began the final decommissioning of Fermi 1, with the goal of removing the remaining radioactive material and terminating the Fermi 1 license. In 2011, based on management decisions revising the timing and estimate of cash flows, DTE Electric accrued an additional $19 million with respect to the decommissioning of Fermi 1. Management has suspended decommissioning activities and placed the facility in safe storage status. The expense amount has been recorded in Asset (gains) and losses, reserves and impairments, net on the Consolidated Statements of Operations. In addition, in 2011, based on updated studies revising the timing and estimate of cash flows, a reduction of approximately $20 million was made to the DTE Electric asset retirement obligation for asbestos removal with approximately $6 million of the decrease associated with Fermi 1 recorded in Asset (gains) and losses, reserves and impairments, net on the Consolidated Statements of Operations.
	In October 2011, the MPSC approved DTE Electric's request for a reduction to the nuclear decommissioning surcharge under the assumption that it would request an extension of the Fermi 2 license for an additional 20 years beyond the term of the existing license which expires in 2025. DTE Electric expects to request the license extension in 2014. This proposed extension of the license, including the associated impact on spent nuclear fuel, resulted in a revision in estimated cash flows for the Fermi 2 asset retirement obligation of approximately $22 million in 2011. It is estimated that the cost of decommissioning Fermi 2 is $1.6 billion in 2013 dollars and $10 billion in 2045 dollars, using a 6% inflation rate. Approximately $1.6 billion of the asset retirement obligations represent nuclear decommissioning liabilities that are funded through a surcharge to electric customers over the life of the Fermi 2 nuclear plant.
	The NRC has jurisdiction over the decommissioning of nuclear power plants and requires minimum decommissioning funding based upon a formula. The MPSC and FERC regulate the recovery of costs of decommissioning nuclear power plants and both require the use of external trust funds to finance the decommissioning of Fermi 2. Rates approved by the MPSC provide for the recovery of decommissioning costs of Fermi 2 and the disposal of low-level radioactive waste. DTE Electric is continuing to fund FERC jurisdictional amounts for decommissioning even though explicit provisions are not included in FERC rates. The Company believes the MPSC and FERC collections will be adequate to fund the estimated cost of decommissioning. The decommissioning assets, anticipated earnings thereon and future revenues from decommissioning collections will be used to decommission Fermi 2. The Company expects the liabilities to be reduced to zero at the conclusion of the decommissioning activities. If amounts remain in the trust funds for Fermi 2 following the completion of the decommissioning activities, those amounts will be disbursed based on rulings by the MPSC and FERC.
	A portion of the funds recovered through the Fermi 2 decommissioning surcharge and deposited in external trust accounts is designated for the removal of non-radioactive assets and returning the site to greenfield. This removal and greenfielding is not considered a legal liability. Therefore, it is not included in the asset retirement obligation, but is reflected as the nuclear decommissioning liability. The decommissioning of Fermi 1 is funded by DTE Electric. Contributions to the Fermi 1 trust are discretionary. See Note 3 for additional discussion of Nuclear decommissioning trust fund assets.

Regulatory_Matters_Notes

Regulatory Matters (Notes)	12 Months Ended
	Dec. 31, 2013
Regulatory Assets and Liabilities Disclosure [Abstract]	'
Regulatory Matters	'
	REGULATORY MATTERS
	Regulation
	DTE Electric and DTE Gas are subject to the regulatory jurisdiction of the MPSC, which issues orders pertaining to rates, recovery of certain costs, including the costs of generating facilities and regulatory assets, conditions of service, accounting and operating-related matters. DTE Electric is also regulated by the FERC with respect to financing authorization and wholesale electric activities. Regulation results in differences in the application of generally accepted accounting principles between regulated and non-regulated businesses.
	The Company is unable to predict the outcome of the unresolved regulatory matters discussed herein. Resolution of these matters is dependent upon future MPSC orders and appeals, which may materially impact the financial position, results of operations and cash flows of the Company.
	Regulatory Assets and Liabilities
	DTE Electric and DTE Gas are required to record regulatory assets and liabilities for certain transactions that would have been treated as revenue or expense in non-regulated businesses. Continued applicability of regulatory accounting treatment requires that rates be designed to recover specific costs of providing regulated services and be charged to and collected from customers. Future regulatory changes or changes in the competitive environment could result in the discontinuance of this accounting treatment for regulatory assets and liabilities for some or all of our businesses and may require the write-off of the portion of any regulatory asset or liability that was no longer probable of recovery through regulated rates. Management believes that currently available facts support the continued use of regulatory assets and liabilities and that all regulatory assets and liabilities are recoverable or refundable in the current regulatory environment.
	The following are balances and a brief description of the regulatory assets and liabilities at December 31:
		2013			2012
		(In millions)
	Assets
	Recoverable pension and other postretirement costs:
	Pension	$	1,660		$	2,420
	Other postretirement costs	—			426
	Asset retirement obligation	394			424
	Recoverable Michigan income taxes	286			304
	Recoverable income taxes related to securitized regulatory assets	126			226
	Cost to achieve Performance Excellence Process	75			96
	Other recoverable income taxes	71			76
	Unamortized loss on reacquired debt	63			63
	Deferred environmental costs	59			58
	Enterprise Business Systems costs	13			16
	Recoverable revenue decoupling	9			28
	Choice incentive mechanism	3			66
	Accrued PSCR/GCR revenue	—			87
	Recoverable restoration expense	—			49
	Other	104			78
		2,863			4,417
	Less amount included in current assets	(26		)	(182		)
		$	2,837		$	4,235
	Securitized regulatory assets	$	231		$	413
		2013			2012
		(In millions)
	Liabilities
	Asset removal costs	$	351		$	439
	Renewable energy	277			230
	Refundable revenue decoupling/deferred gain	127			127
	Negative pension offset	84			105
	Over recovery of Securitization	72			54
	Refundable other postretirement costs	72			—
	Accrued PSCR/GCR	65			16
	Refundable income taxes	45			56
	Energy optimization	31			34
	Fermi 2 refueling outage	26			12
	Refundable uncollectible expense	12			37
	Other	2			10
		$	1,164		$	1,120
	Less amount included current liabilities	(302		)	(89		)
		$	862		$	1,031
	As noted below, certain regulatory assets for which costs have been incurred have been included (or are expected to be included, for costs incurred subsequent to the most recently approved rate case) in DTE Electric or DTE Gas’s rate base, thereby providing a return on invested costs (except as noted). Certain other regulatory assets are not included in rate base but accrue recoverable carrying charges until surcharges to collect the assets are billed. Certain regulatory assets do not result from cash expenditures and therefore do not represent investments included in rate base or have offsetting liabilities that reduce rate base.
	ASSETS
	•	Recoverable pension and other postretirement costs — Accounting rules for pension and other postretirement benefit costs require, among other things, the recognition in other comprehensive income of the actuarial gains or losses and the prior service costs that arise during the period but that are not immediately recognized as components of net periodic benefit costs. DTE Electric and DTE Gas record the impact of actuarial gains or losses and prior services costs as a regulatory asset since the traditional rate setting process allows for the recovery of pension and other postretirement costs. The asset will reverse as the deferred items are amortized and recognized as components of net periodic benefit costs. (a)
	•	Asset retirement obligation — This obligation is primarily for Fermi 2 decommissioning costs. The asset captures the timing differences between expense recognition and current recovery in rates and will reverse over the remaining life of the related plant. (a)
	•	Recoverable Michigan income taxes — In July 2007, the Michigan Business Tax (MBT) was enacted by the State of Michigan. State deferred tax liabilities were established for the Company’s utilities, and offsetting regulatory assets were recorded as the impacts of the deferred tax liabilities will be reflected in rates as the related taxable temporary differences reverse and flow through current income tax expense. In May 2011, the MBT was repealed and the Michigan Corporate Income Tax (MCIT) was enacted. The regulatory asset was remeasured to reflect the impact of the MCIT tax rate. (a)
	•	Recoverable income taxes related to securitized regulatory assets — Receivable for the recovery of income taxes to be paid on the non-bypassable securitization bond surcharge. A non-bypassable securitization tax surcharge recovers the income tax over a fourteen-year period ending 2015. (a)
	•	Cost to achieve Performance Excellence Process (PEP) — The MPSC authorized the deferral of costs to implement the PEP. These costs consist of employee severance, project management and consultant support. These costs are amortized over a ten-year period beginning with the year subsequent to the year the costs were deferred.
	•	Other recoverable income taxes — Income taxes receivable from DTE Electric’s customers representing the difference in property-related deferred income taxes and amounts previously reflected in DTE Electric’s rates. This asset will reverse over the remaining life of the related plant. (a)
	•	Unamortized loss on reacquired debt — The unamortized discount, premium and expense related to debt redeemed with a refinancing are deferred, amortized and recovered over the life of the replacement issue.
	•	Deferred environmental costs — The MPSC approved the deferral of investigation and remediation costs associated with DTE Gas's former MGP sites. Amortization of deferred costs is over a ten-year period beginning in the year after costs were incurred, with recovery (net of any insurance proceeds) through base rate filings. (a)
	•	Enterprise Business Systems (EBS) costs — The MPSC approved the deferral and amortization over ten years beginning in January 2009 of EBS costs that would otherwise be expensed.
	•	Recoverable revenue decoupling — Amounts recoverable from DTE Gas customers for the change in revenue resulting from the difference in weather-adjusted average sales per customer compared to the base level of average sales per customer established by the MPSC. The December 2012 order in DTE Gas's rate case required the RDM be discontinued effective November 1, 2012. The order provided for a new RDM, which began in November 2013.
	•	Choice incentive mechanism (CIM) — DTE Electric receivable for non-fuel revenues lost as a result of fluctuations in electric Customer Choice sales. The CIM was terminated in the October 20, 2011 MPSC order issued to DTE Electric.
	•	Accrued PSCR/GCR revenue — Receivable for the temporary under-recovery of and carrying costs on fuel and purchased power costs incurred by DTE Electric which are recoverable through the PSCR mechanism and temporary under-recovery of and carrying costs on gas costs incurred by DTE Gas which are recoverable through the GCR mechanism.
	•	Recoverable restoration expense — Receivable for the MPSC approved restoration expense tracking mechanism that tracked the difference between actual restoration expense and the amount provided for in base rates, recognized pursuant to the MPSC authorization. The restoration expense tracking mechanism was terminated in the October 20, 2011 MPSC order issued to DTE Electric.
•	Securitized regulatory assets — The net book balance of the Fermi 2 nuclear plant was written off in 1998 and an equivalent regulatory asset was established. In 2001, the Fermi 2 regulatory asset and certain other regulatory assets were securitized pursuant to PA 142 and an MPSC order. A non-bypassable securitization bond surcharge recovers the securitized regulatory asset over a fourteen-year period ending in 2015.
_________________________________
(a)	Regulatory assets not earning a return or accruing carrying charges.
LIABILITIES
•	Asset removal costs — The amount collected from customers for the funding of future asset removal activities.
•	Renewable energy — Amounts collected in rates in excess of renewable energy expenditures.
•	Refundable revenue decoupling / deferred gain — Amounts were originally accrued as refundable to DTE Electric customers for the change in revenue resulting from the difference between actual average sales per customer compared to the base level of average sales per customer established by the MPSC. In 2012, the Michigan Court of Appeals issued a decision reversing the MPSC's decision to authorize a RDM for DTE Electric. The revenue decoupling liability was reversed and, after receiving an order from the MPSC to defer the resulting gain for future amortization, DTE Electric created a regulatory liability representing its obligation to refund the gain. The deferred gain will be amortized into earnings in 2014.
•	Negative pension offset — DTE Gas's negative pension costs are not included as a reduction to its authorized rates; therefore, the Company is accruing a regulatory liability to eliminate the impact on earnings of the negative pension expense accrued. This regulatory liability will reverse to the extent DTE Gas’s pension expense is positive in future years.
•	Over recovery of Securitization — Over recovery of securitization bond expenses.
•	Refundable other postretirement costs — Accounting rules for other postretirement benefit costs require, among other things, the recognition in other comprehensive income of the actuarial gains or losses and the prior service costs or credits that arise during the period but that are not immediately recognized as components of net periodic benefit costs. DTE Electric and DTE Gas record the favorable impact of actuarial gains or losses and prior service credits as a regulatory liability since the impact will reduce expense in a future rate setting process as the deferred items are recognized as a component of net periodic benefit costs.
•	Accrued PSCR/GCR refund — Liability for the temporary over-recovery of and a return on power supply costs and transmission costs incurred by DTE Electric which are recoverable through the PSCR mechanism and temporary over-recovery of and a return on gas costs incurred by DTE Gas which are recoverable through the GCR mechanism.
•	Refundable income taxes — Income taxes refundable to DTE Gas’s customers representing the difference in property-related deferred income taxes payable and amounts recognized pursuant to MPSC authorization.
•	Energy optimization (EO) — Amounts collected in rates in excess of energy optimization expenditures.
•	Fermi 2 refueling outage — Accrued liability for refueling outage at Fermi 2 pursuant to MPSC authorization.
•	Refundable uncollectible expense (UETM) — DTE Electric and DTE Gas liability for the MPSC approved uncollectible expense tracking mechanism that tracks the difference in the fluctuation in uncollectible accounts and amounts recognized pursuant to the MPSC authorization. The UETM was terminated for DTE Electric in the October 20, 2011 MPSC rate case order and terminated for DTE Gas in the December 20, 2012 MPSC approval of the partial settlement agreement.
2009 Electric Rate Case Filing - Court of Appeals Decision
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 an approximately $11 million rate increase 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.
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 proposed a recovery mechanism for the deferred net incremental revenue requirement described above. The application further discussed 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.
Energy Optimization (EO) Plans
The EO plan is designed to help customers reduce their electric usage by: 1) building customer awareness of energy efficiency options and 2) offering a diverse set of programs and participation options that result in energy savings for each customer class.
In May 2013, DTE Electric and DTE Gas filed separate applications for approval of their respective reconciliations of their 2012 EO plan expenses. DTE Electric’s EO reconciliation included a cumulative $26 million net over-recovery and DTE Gas’s EO reconciliation included a cumulative $7 million net over-recovery for their 2012 EO plans. DTE Electric and DTE Gas proposed that the calculated over-recoveries for 2012 be carried forward into 2013 and used as beginning balances for the 2013 reconciliations. On December 6, 2013, the MPSC approved settlement agreements of the DTE Electric and DTE Gas 2012 EO reconciliations that carried forward to 2013 the 2012 over-recoveries. In addition, the MPSC authorized performance incentive surcharges, over a 12-month period effective January 1, 2014, of approximately $10 million and $4 million for DTE Electric and DTE Gas, respectively.
In July 2013, DTE Electric and DTE Gas filed separate applications with the MPSC for the biennial review of their EO plans. On December 19, 2013, the MPSC approved settlement agreements for the EO plans of DTE Electric and DTE Gas.
DTE Electric Restoration Expense Tracker Mechanism (RETM) and Line Clearance Tracker (LCT) Reconciliation
In January 2012, DTE Electric filed an application with the MPSC for approval of the reconciliation of its 2011 RETM and LCT. The Company's 2011 restoration expenses were higher than the amount provided in rates. Accordingly, DTE Electric requested net recovery of approximately $44 million. On February 28, 2013, the MPSC approved a settlement agreement and authorized a $44 million net surcharge to recover the costs over a three-month period beginning April 1, 2013.
DTE Electric Uncollectible Expense True-Up Mechanism (UETM)
In February 2012, DTE Electric filed an application with the MPSC for approval of its UETM for 2011 requesting authority to refund approximately $9 million consisting of costs related to 2011 uncollectible expense. On February 28, 2013, the MPSC approved a settlement agreement and authorized a $9 million credit to refund the over-recovery over a one month period beginning April 1, 2013.
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.
Renewable Energy Plan (REP)
In June 2013, DTE Electric filed an application for the biennial review and approval of its amended REP with the MPSC requesting authority to reduce its annual surcharge revenue recovery from approximately $100 million to $15 million. The proposed level is appropriate to continue to properly implement DTE Electric’s 20-year REP, designed to deliver cleaner, renewable electric generation to its customers, to further diversify DTE Electric’s and the State of Michigan’s sources of electric supply, and to address the state and national goals of increasing energy independence. On December 19, 2013, the MPSC approved DTE Electric’s amended REP.
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.
2010 PSCR Year - On April 25, 2013, the MPSC approved the 2010 PSCR net under-recovery of $52.6 million and the recovery of this amount as part of the 2011 PSCR reconciliation. The order also approved DTE Electric's Pension Equalization Mechanism reconciliation and authorized a one month surcharge in June 2013 and approved the recovery of the over-refund of the self-implemented rate increase related to the 2009 electric rate case filing as part of the 2011 PSCR reconciliation.
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 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. DTE Electric was 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 up to $32 million of the Fermi-related purchased power costs. Resolution of this matter is expected in 2014.
2012 Gas Rate Case Filing
DTE Gas filed a rate case on April 20, 2012 based on a projected test year for the twelve-month period ending October 31, 2013. On December 20, 2012, the MPSC approved a partial settlement agreement and authorized the Company to increase its annual gas revenues by $19.9 million for service rendered on and after January 1, 2013. The partial settlement agreement did not resolve the proposal for an infrastructure recovery mechanism (IRM) designed to recover DTE Gas' projected costs over a five-year period related to its gas main renewal, pipeline integrity and meter move out programs. On April 16, 2013, the MPSC issued an order approving the IRM and authorized the recovery of the cost of service related to $77 million of annual investment in the programs beginning in May 2013. The IRM will adjust annually in July for the incremental investment each year, after a limited hearing on the reconciliation of the prior year capital expenditures. When DTE Gas files a rate case, all capital invested as part of the IRM will be rolled into rate base and recovery would continue through base rates as part of a base rate case filing. As part of any future rate case, DTE Gas may propose to implement an updated IRM to address the recovery of future infrastructure investments.
DTE Gas 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.
DTE Gas Revenue Decoupling Mechanism (RDM)
In October 2012, DTE Gas filed an application with the MPSC for approval of its RDM reconciliation for the period July 1, 2011 through June 30, 2012. The application requests authority to adjust existing retail gas rates so as to collect a net amount of approximately $9 million, plus interest. On March 15, 2013, the MPSC approved a settlement agreement and authorized the implementation of surcharges during the billing months of April 2013 through March 2014.
In May 2013, DTE Gas filed an application with the MPSC for approval of its RDM reconciliation for the period July 1, 2012 through October 31, 2012. DTE Gas's RDM application proposed the recovery of a net under-recovery of approximately $5.2 million. On November 14, 2013, the MPSC approved a settlement agreement and authorized the implementation of surcharges during the billing months of December 2013 through March 2014.
The December 2012 order in DTE Gas's rate case required the RDM be discontinued effective November 1, 2012. The order also provided for a new RDM for the period November 1, 2013 through October 31, 2014. The new RDM decouples weather normalized distribution revenue inside caps. The caps are tied to expected conservation targets: 1.125% in the first reconciliation period and 2.25% for the second and future periods.
DTE Gas Depreciation Filing
In compliance with an MPSC order, DTE Gas filed a depreciation case in June 2012. On May 15, 2013, the MPSC approved a settlement agreement increasing DTE Gas’s composite depreciation rates from 2.29% to 2.51%, effective on the same date as the MPSC-approved rates are effective in DTE Gas’s next general rate case. The Company cannot predict when DTE Gas will file its next rate case.

Income_Taxes_Notes

Income Taxes (Notes)	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	INCOME TAXES
	Income Tax Summary
	The Company files a consolidated federal income tax return. Total income tax expense varied from the statutory federal income tax rate for the following reasons:
		2013			2012			2011
		(In millions)
	Income before income taxes	$	922		$	960		$	991
	Income tax expense at 35% statutory rate	$	323		$	336		$	347
	Production tax credits	(68		)	(49		)	(6		)
	Investment tax credits	(6		)	(6		)	(6		)
	Depreciation	(4		)	(4		)	(4		)
	AFUDC - Equity	(5		)	(4		)	(1		)
	Employee Stock Ownership Plan dividends	(4		)	(4		)	(4		)
	Domestic production activities deduction	(14		)	(14		)	(7		)
	State and local income taxes, net of federal benefit	37			37			37
	Enactment of Michigan Corporate Income Tax, net of federal expense	—			—			(87		)
	Other, net	(5		)	(6		)	(1		)
	Income tax expense	$	254		$	286		$	268
	Effective income tax rate	27.5		%	29.8		%	27		%
	Components of income tax expense were as follows:
		2013			2012			2011
		(In millions)
	Current income tax expense (benefit)
	Federal	$	74		$	190		$	27
	State and other income tax	16			49			21
	Total current income taxes	90			239			48
	Deferred income tax expense (benefit)
	Federal	122			39			318
	State and other income tax	42			8			(98		)
	Total deferred income taxes	164			47			220
	Total income taxes from continuing operations	254			286			268
	Discontinued operations	—			(29		)	(1		)
	Total	$	254		$	257		$	267
	Deferred tax assets and liabilities are recognized for the estimated future tax effect of temporary differences between the tax basis of assets or liabilities and the reported amounts in the financial statements. Deferred tax assets and liabilities are classified as current or noncurrent according to the classification of the related assets or liabilities. Deferred tax assets and liabilities not related to assets or liabilities are classified according to the expected reversal date of the temporary differences. Consistent with rate making treatment, deferred taxes are offset in the table below for temporary differences which have related regulatory assets and liabilities.
	Deferred tax assets (liabilities) were comprised of the following at December 31:
		2013			2012
		(In millions)
	Property, plant and equipment	$	(3,372	)	$	(3,389	)
	Securitized regulatory assets	(127		)	(256		)
	Alternative minimum tax credit carry-forwards	266			254
	Merger basis differences	18			42
	Pension and benefits	(30		)	(33		)
	Other comprehensive loss	—			101
	Derivative assets and liabilities	—			66
	State net operating loss and credit carry-forwards	43			37
	Other	(110		)	41
		(3,312		)	(3,137		)
	Less valuation allowance	(37		)	(33		)
		$	(3,349	)	$	(3,170	)
	Current deferred income tax assets (liabilities)	$	(28	)	$	21
	Long-term deferred income tax liabilities	(3,321		)	(3,191		)
		$	(3,349	)	$	(3,170	)
	Deferred income tax assets	$	1,808		$	1,038
	Deferred income tax liabilities	(5,157		)	(4,208		)
		$	(3,349	)	$	(3,170	)
	Production tax credits earned in prior years but not utilized totaled $266 million and are carried forward indefinitely as alternative minimum tax credits. The majority of the production tax credits earned in prior years but not utilized, including all of those from our synfuel projects, were generated from projects that had received a private letter ruling (PLR) from the Internal Revenue Service (IRS). These PLRs provide assurance as to the appropriateness of using these credits to offset taxable income, however, these tax credits are subject to IRS audit and adjustment.
	The above table excludes deferred tax liabilities associated with unamortized investment tax credits that are shown separately on the Consolidated Statements of Financial Position. Investment tax credits are deferred and amortized to income over the average life of the related property.
	The Company has state deferred tax assets related to net operating loss and credit carry-forwards of $43 million and $37 million at December 31, 2013 and 2012, respectively. The state net operating loss and credit carry-forwards expire from 2014 through 2033. The Company has recorded valuation allowances at December 31, 2013 and 2012 of approximately $37 million and $33 million, respectively, with respect to these deferred tax assets. In assessing the realizability of deferred tax assets, the Company considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible.
	Uncertain Tax Positions
	A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows:
		2013			2012			2011
		(In millions)
	Balance at January 1	$	11		$	48		$	28
	Additions for tax positions of prior years	—			—			27
Reductions for tax positions of prior years	—			(2		)	(4		)
Additions for tax positions of current year	—			1			1
Settlements	—			(30		)	(3		)
Lapse of statute of limitations	(1		)	(6		)	(1		)
Balance at December 31	$	10		$	11		$	48
The Company had $2 million and $3 million of unrecognized tax benefits at December 31, 2013 and at 2012, respectively, that, if recognized, would favorably impact its effective tax rate. During the next twelve months, it is reasonably possible that the statute of limitation will expire on various state tax returns. As a result, the Company believes that it is possible that there will be a decrease in unrecognized tax benefits of up to $1 million within the next twelve months.
The Company recognizes interest and penalties pertaining to income taxes in Interest expense and Other expenses, respectively, on its Consolidated Statements of Operations. Accrued interest pertaining to income taxes totaled $1 million and $1 million at December 31, 2013 and 2012, respectively. The Company had no accrued penalties pertaining to income taxes. The Company recognized interest expense (income) related to income taxes of a nominal amount, $(1) million and $(2) million in 2013, 2012 and 2011, respectively.
In 2013, the Company settled a federal tax audit for the 2011 tax year, which resulted in the recognition of a nominal amount of unrecognized tax benefits. The Company's federal income tax returns for 2012 and subsequent years remain subject to examination by the IRS. The Company's Michigan Business Tax and Michigan Corporate Income Tax returns for the year 2008 and subsequent years remain subject to examination by the State of Michigan. The Company also files tax returns in numerous state and local jurisdictions with varying statutes of limitation.
Michigan Corporate Income Tax (MCIT)
In May 2011, the Michigan Business Tax (MBT) was repealed and the MCIT was enacted and became effective January 1, 2012. The MCIT subjects corporations with business activity in Michigan to a 6% tax rate on an apportioned income tax base and eliminates the modified gross receipts tax and nearly all credits available under the MBT. The MCIT also eliminated the future deductions allowed under MBT that enabled companies to establish a one-time deferred tax asset upon enactment of the MBT to offset deferred tax liabilities that resulted from enactment of the MBT.
As a result of the enactment of the MCIT, the net state deferred tax liability was remeasured to reflect the impact of the MCIT tax rate on cumulative temporary differences expected to reverse after the effective date. The net impact of this remeasurement was a reduction of the net deferred tax assets attributable to our regulated utilities, partially offset by a decrease in deferred tax liabilities attributable to our non-utilities of $87 million primarily due to a lower apportionment factor from inclusion of non-utility entities in DTE Energy's unitary Michigan tax return and was recognized as a reduction to income tax expense in 2011.
No recognition of these non-cash transactions have been reflected in the Consolidated Statements of Cash Flows.

Common_Stock_Notes

Common Stock (Notes)	12 Months Ended
	Dec. 31, 2013
Stockholders' Equity Note [Abstract]	'
Schedule of Stock by Class [Table Text Block]	'
	COMMON STOCK
	Common Stock
	During 2013 and 2012, 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)
	12-Mar-13	750,075	$	66.66	$	50
	12-Jun-13	753,579	$	66.35	50
	12-Sep-13	1,522,301	$	65.69	100
					$	200
	18-Jun-12	1,334,668	$	59.94	$	80
	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.
	Under the DTE Energy Company Long-Term Incentive Plan, the Company grants non-vested stock awards to key employees, primarily management. As a result of a stock award, a settlement of an award of performance shares, or by exercise of a participant’s stock option, the Company may deliver common stock from the Company’s authorized but unissued common stock and/or from outstanding common stock acquired by or on behalf of the Company in the name of the participant.
	Dividends
	Certain of the Company’s credit facilities contain a provision requiring the Company to maintain a total funded debt to capitalization ratio, as defined in the agreements, of no more than 0.65 to 1, which has the effect of limiting the amount of dividends the Company can pay in order to maintain compliance with this provision. See Note 17 for a definition of this ratio. The effect of this provision was to restrict the payment of approximately $166 million at December 31, 2013 of total retained earnings of approximately $4 billion. There are no other effective limitations with respect to the Company’s ability to pay dividends.

Earnings_Per_Share_Notes

Earnings Per Share (Notes)	12 Months Ended
	Dec. 31, 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 as of December 31:
		2013		2012		2011
		(In millions, expect per share amounts)
	Basic Earnings per Share
	Net income attributable to DTE Energy Company	$	661	$	610	$	711
	Average number of common shares outstanding	175		171		169
	Weighted average net restricted shares outstanding	1		1		1
	Dividends declared — common shares	$	453	$	413	$	392
	Dividends declared — net restricted shares	1		1		1
	Total distributed earnings	$	454	$	414	$	393
	Net income less distributed earnings	$	207	$	196	$	318
	Distributed (dividends per common share)	$	2.59	$	2.42	$	2.32
	Undistributed	1.17		1.14		1.87
	Total Basic Earnings per Common Share	$	3.76	$	3.56	$	4.19
	Diluted Earnings per Share
	Net income attributable to DTE Energy Company	$	661	$	610	$	711
	Average number of common shares outstanding	175		171		169
	Average incremental shares from assumed exercise of options	—		1		1
	Common shares for dilutive calculation	175		172		170
	Weighted average net restricted shares outstanding	1		1		1
	Dividends declared — common shares	$	453	$	413	$	392
	Dividends declared — net restricted shares	1		1		1
	Total distributed earnings	$	454	$	414	$	393
	Net income less distributed earnings	$	207	$	196	$	318
	Distributed (dividends per common share)	$	2.59	$	2.42	$	2.32
	Undistributed	1.17		1.13		1.86
	Total Diluted Earnings per Common Share	$	3.76	$	3.55	$	4.18

LongTerm_Debt_Notes

Long-Term Debt (Notes)	12 Months Ended
	Dec. 31, 2013
Long-term Debt, Unclassified [Abstract]	'
Long-Term Debt	'
	LONG-TERM DEBT
	Long-Term Debt
	The Company’s long-term debt outstanding and weighted average interest rates (a) of debt outstanding at December 31 were:
		2013				2012
		(In millions)
	Mortgage bonds, notes, and other
	DTE Energy Debt, Unsecured
	6.1% due 2014 to 2033	$	1,297			$	1,298
	DTE Electric Taxable Debt, Principally Secured
	4.7% due 2014 to 2043	4,286				3,777
	DTE Electric Tax-Exempt Revenue Bonds (b)
	5.1% due 2014 to 2036	558				707
	DTE Gas Taxable Debt, Principally Secured
	5.6% due 2014 to 2042	1,029				919
	Other Long-Term Debt, Including Non-Recourse Debt	142				153
		7,312				6,854
	Less amount due within one year	(694		)		(634		)
		$	6,618			$	6,220
	Securitization bonds
	6.6% due 2015	$	302			$	479
	Less amount due within one year	(197		)		(177		)
		$	105			$	302
	Junior Subordinated Debentures
	6.5% due 2061	$	280			$	280
	5.25% due 2062	200				200
		$	480			$	480
	_______________________________________
	(a)	Weighted average interest rates as of December 31, 2013 are shown below the description of each category of debt.
	(b)	DTE Electric Tax-Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds.
	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	%	2043		$	375
	DTE Electric		August		Mortgage Bonds (a)		3.65	%	2024		400
	DTE Energy		November		Senior Notes (a)		3.85	%	2023		300
	DTE Gas		December		Mortgage Bonds (a)		3.64	%	2023		50
	DTE Gas		December		Mortgage Bonds (a)		3.74	%	2025		70
	DTE Gas		December		Mortgage Bonds (a)		3.94	%	2028		50
											$	1,245
	_______________________________________
	(a)	Proceeds were used for the redemption of long-term debt, repayment of short-term borrowings and 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)		5.3	%	2030		51
	DTE Electric		April		Other Long-Term Debt		Various		2013		13
	DTE Gas		April		Senior Notes		5.26	%	2013		60
	DTE Energy		June		Senior Notes		Variable		2013		300
	DTE Electric		September		Securitization Bonds		6.62	%	2013		89
	DTE Electric		September		Senior Notes		6.4	%	2013		250
	DTE Electric		December		Tax Exempt Revenue Bonds (a)		5.5	%	2030		49
	DTE Electric		December		Tax Exempt Revenue Bonds (a)		6.75	%	2038		50
	DTE Energy		Various		Other Long-Term Debt		Various		2013		11
											$	961
	_______________________________________
	(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.
	The following table shows the scheduled debt maturities:
		2014				2015			2016				2017		2018		2019 and		Total
																	Thereafter
		(In millions)
Amount to mature	$	891			$	476		$	465			$	9	$	407	$	5,846	$	8,094
Junior Subordinated Debentures
At December 31, 2013, the Company had $280 million of 6.5% Junior Subordinated Debentures due 2061 and $200 million of 5.25% Junior Subordinated Debentures due 2062. The Company has the right to defer interest payments on the debt securities. Should the Company exercise this right, it cannot declare or pay dividends on, or redeem, purchase or acquire, any of its capital stock during the deferral period. Any deferred interest payments will bear additional interest at the rate associated with the related debt issue.
Cross Default Provisions
Substantially all of the net utility properties of DTE Electric and DTE Gas are subject to the lien of mortgages. Should DTE Electric or DTE Gas fail to timely pay their indebtedness under these mortgages, such failure may create cross defaults in the indebtedness of DTE Energy.

Preferred_and_Preferenced_Secu

Preferred and Preferenced Securities (Notes)	12 Months Ended
	Dec. 31, 2013
Preferred Stock, Number of Shares, Par Value and Other Disclosures [Abstract]	'
Preferred and Preference Securities	'
	PREFERRED AND PREFERENCE SECURITIES
	As of December 31, 2013, the amount of authorized and unissued stock is as follows:
	Company	Type of Stock	Par Value		Shares Authorized
	DTE Energy	Preferred	$	—	5,000,000
	DTE Electric	Preferred	$	100	6,747,484
	DTE Electric	Preference	$	1	30,000,000
	DTE Gas	Preferred	$	1	7,000,000
	DTE Gas	Preference	$	1	4,000,000

ShortTerm_Credit_Arrangements_

Short-Term Credit Arrangements and Borrowings (Notes)	12 Months Ended
	Dec. 31, 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 December 31, 2013, the total funded debt to total capitalization ratios for DTE Energy, DTE Electric and DTE Gas are 0.48 to 1, 0.50 to 1 and 0.48 to 1, respectively, and are in compliance with this financial covenant. The availability under the facilities in place at December 31, 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
		1,375		300		300		1,975
	Amounts outstanding at December 31, 2013:
	Commercial paper issuances	35		—		96		131
	Letters of credit	244		—		—		244
		279		—		96		375
	Net availability at December 31, 2013	$	1,096	$	300	$	204	$	1,600
	The Company has other outstanding letters of credit which are not included in the above described facilities totaling approximately $53 million which are used for various corporate purposes.
	The weighted average interest rate for short-term borrowings was 0.2% and 0.4% at December 31, 2013 and 2012, respectively.
	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 December 31, 2013, a $50 million letter of credit was in place, raising the capacity under this facility to $150 million. The $50 million letter of credit is included in the table above. The amount outstanding under this agreement was $138 million and $65 million at December 31, 2013 and 2012, respectively.

Capital_and_Operating_Leases_N

Capital and Operating Leases (Notes)	12 Months Ended
	Dec. 31, 2013
Capital and Operating Leases [Abstract]	'
Capital and Operating Leases	'
	CAPITAL AND OPERATING LEASES
	Lessee — The Company leases various assets under capital and operating leases, including coal railcars, office buildings, a warehouse, computers, vehicles and other equipment. The lease arrangements expire at various dates through 2046.
	Future minimum lease payments under non-cancelable leases at December 31, 2013 were:
		Capital			Operating
		Leases			Leases
		(In millions)
	2014	$	8		$	35
	2015	8			31
	2016	3			27
	2017	—			25
	2018	—			20
	Thereafter	—			92
	Total minimum lease payments	$	19		$	230
	Less imputed interest	1
	Present value of net minimum lease payments	18
	Less current portion	7
	Non-current portion	$	11
	Rental expense for operating leases was $34 million in 2013, $36 million in 2012, and $40 million in 2011.
	Lessor - Capital Lease — The Company leases a portion of its pipeline system to the Vector Pipeline through a capital lease contract that expires in 2020, with renewal options extending for five years. The Company owns a 40% interest in the Vector Pipeline. In addition, the Company has an energy services agreement, a portion of which is accounted for as a capital lease. The agreement expires in 2019, with a three or five year renewal option. The components of the net investment in the capital leases at December 31, 2013, were as follows:
		(In millions)
	2014	$	12
	2015	12
	2016	12
	2017	12
	2018	12
	Thereafter	19
	Total minimum future lease receipts	79
	Residual value of leased pipeline	40
	Less unearned income	(40		)
	Net investment in capital lease	79
	Less current portion	(5		)
		$	74

Commitments_and_Contingencies_

Commitments and Contingencies (Notes)	12 Months Ended
	Dec. 31, 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 has spent approximately $2 billion through 2013. The Company estimates DTE Electric will make capital expenditures of approximately $280 million in 2014 and up to approximately $1.2 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 other hazardous air pollutants. The Cross State Air Pollution Rule (CSAPR), finalized in July 2011, requires 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 the EPA's petition asking the Court to review the D.C. Circuit Court's decision on CSAPR. A ruling by the Supreme Court is expected in 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 1,499 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. In December 2013, a U.S. District Court judge issued an order dismissing, without prejudice, the plaintiff's complaint allowing them to file an amended complaint by January 17, 2014. The order dismissing the complaint resulted from a considerable number of plaintiff's claims being time barred based on the statute of limitations. On January 17, 2014, the plaintiffs filed an amended complaint for the period January 13, 2008 - June 30, 2012, reducing the total number of 6-minute periods from 1,499 to 1,139. DTE Energy and DTE Electric plan to file an answer to the amended complaint in the first quarter of 2014. 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. Final action on this rule has been delayed and is expected in 2014. Depending on final regulations, its requirements may require modifications to some existing intake structures and could impact the rates we charge our customers. It is not possible to quantify the impact of those expected rulemakings at this time.
	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 December 31, 2013 and 2012, the Company had $8 million and $9 million, respectively, accrued for remediation. Any change in assumptions, such as remediation techniques, nature and extent of contamination and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect 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 three permitted engineered ash storage facilities to dispose of fly ash from coal fired power plants. 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, owned 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. As of December 31, 2013 and 2012, the Company had $28 million and $29 million, accrued for remediation, respectively. Any change in assumptions, such as remediation techniques, nature and extent of contamination and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect 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 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 $3 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 and a 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 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 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 has scheduled the 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 claims are being settled on a timely basis. The settlement proceeds reduced the cost of the dry cask storage facility assets. In January 2014, the settlement agreement was extended through 2016. 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.
	In February 2013, the U.S. Court of Appeals for the District of Columbia (COA) granted a motion to reopen the fee adequacy litigation to review the DOE's latest fee adequacy report which was released in January 2013. In November 2013, the COA issued a decision ordering the DOE to submit a proposal to Congress to reduce the nuclear waste fee to zero until the DOE enacts an alternative nuclear waste management plan. In January 2014, the DOE submitted such a proposal to Congress that will take effect in 90 legislative calendar days, absent legislative action to the contrary. Simultaneously, the DOE filed a petition for rehearing of the November 2013 decision with the COA. DTE Electric continues to pay fees to the U.S. government's nuclear waste fund pending further developments in this proceeding.
	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 December 31, 2013 is approximately $1.1 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 December 31, 2013 is approximately $144 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 December 31, 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 December 31, 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
	There are several bargaining units for the Company's approximately 4,900 represented employees. The majority of the represented employees are under contracts that expire in 2016 and 2017.
	Purchase Commitments
	As of December 31, 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 $8.6 billion from 2014 through 2051 as detailed in the following table:
		(In millions)
	2014	$	2,617
	2015	1,195
	2016	643
	2017	345
	2018	311
	2019 — 2051	3,487
		$	8,598
	The Company also estimates that 2014 capital expenditures will be approximately $2.3 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 11 for a discussion of contingencies related to derivatives and regulatory matters.

Retirement_Benefits_and_Truste

Retirement Benefits and Trusteed Assets (Notes)	12 Months Ended
	Dec. 31, 2013
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]	'
Retirement Benefits and Trusteed Assets	'
	RETIREMENT BENEFITS AND TRUSTEED ASSETS
	Pension Plan Benefits
	The Company has qualified defined benefit retirement plans for eligible represented and non-represented employees. The plans are noncontributory and cover most employees. The plans provide traditional retirement benefits based on the employees’ years of benefit service, average final compensation and age at retirement. In addition, certain represented and non-represented employees are covered under cash balance provisions that determine benefits on annual employer contributions and interest credits. The Company also maintains supplemental nonqualified, noncontributory, retirement benefit plans for selected management employees. These plans provide for benefits that supplement those provided by DTE Energy’s other retirement plans.
	Effective January 1, 2012 for non-represented employees, and in June 2011 and March 2013 for the majority of represented employees, the Company discontinued offering a defined benefit retirement plan. In its place, the Company will annually contribute an amount equivalent to 4% (8% for certain DTE Gas represented employees) of an employee's eligible pay to the employee's defined contribution retirement savings plan.
	The Company’s policy is to fund pension costs by contributing amounts consistent with the provisions of the Pension Protection Act of 2006 and additional amounts when it deems appropriate. The Company contributed $277 million to its qualified pension plans in 2013. At the discretion of management, and depending upon financial market conditions, we anticipate making up to $345 million in contributions to the pension plans in 2014.
	Net pension cost includes the following components:
		2013				2012				2011
		(In millions)
	Service cost	$	94			$	82			$	69
	Interest cost	192				204				202
	Expected return on plan assets	(266		)		(244		)		(246		)
	Amortization of:
	Net loss	208				176				142
	Prior service cost	—				—				3
	Special termination benefits	—				2				2
	Net pension cost	$	228			$	220			$	172
		2013				2012
		(In millions)
	Other changes in plan assets and benefit obligations recognized in Regulatory assets and Other comprehensive income
	Net actuarial (gain) loss	$	(581	)		$	395
	Amortization of net actuarial loss	(208		)		(178		)
	Total recognized Regulatory assets and Other comprehensive income	$	(789	)		$	217
	Total recognized in net periodic pension cost, Regulatory assets and Other comprehensive income	$	(561	)		$	437
	Estimated amounts to be amortized from Regulatory assets and Accumulated other comprehensive income into net periodic benefit cost during next fiscal year
	Net actuarial loss	$	151			$	202
	The following table reconciles the obligations, assets and funded status of the plans as well as the amounts recognized as prepaid pension cost or pension liability in the Consolidated Statements of Financial Position at December 31:
		2013				2012
		(In millions)
	Accumulated benefit obligation, end of year	$	4,068			$	4,349
	Change in projected benefit obligation
	Projected benefit obligation, beginning of year	$	4,729			$	4,195
	Service cost	94				82
	Interest cost	192				204
	Plan amendments	(3		)		—
	Actuarial (gain) loss	(400		)		474
	Special termination benefits	—				2
	Benefits paid	(232		)		(228		)
	Projected benefit obligation, end of year	$	4,380			$	4,729
	Change in plan assets
	Plan assets at fair value, beginning of year	$	3,223			$	2,886
	Actual return on plan assets	445				325
	Company contributions	284				240
	Benefits paid	(232		)		(228		)
	Plan assets at fair value, end of year	$	3,720			$	3,223
	Funded status of the plans	$	(660	)		$	(1,506	)
	Amount recorded as:
	Current liabilities	$	(7	)		$	(8	)
	Noncurrent liabilities	(653		)		(1,498		)
		$	(660	)		$	(1,506	)
	Amounts recognized in Accumulated other comprehensive loss, pre-tax
	Net actuarial loss	$	174			$	205
	Prior service (credit)	(1		)		(2		)
		$	173			$	203
	Amounts recognized in Regulatory assets (see Note 11)
	Net actuarial loss	$	1,654			$	2,413
	Prior service cost	6				7
		$	1,660			$	2,420
	At December 31, 2013, the benefits related to the Company’s qualified and nonqualified pension plans expected to be paid in each of the next five years and in the aggregate for the five fiscal years thereafter are as follows:
		(In millions)
	2014	$	242
	2015	250
	2016	258
	2017	268
2018	280
2019-2023	1,529
	$	2,827
Assumptions used in determining the projected benefit obligation and net pension costs are listed below:
	2013			2012			2011
Projected benefit obligation
Discount rate	4.95	%		4.15	%		5	%
Rate of compensation increase	4.2	%		4.2	%		4.2	%
Net pension costs
Discount rate	4.15	%		5	%		5.5	%
Rate of compensation increase	4.2	%		4.2	%		4	%
Expected long-term rate of return on plan assets	8.25	%		8.25	%		8.5	%
The Company employs a formal process in determining the long-term rate of return for various asset classes. Management reviews historic financial market risks and returns and long-term historic relationships between the asset classes of equities, fixed income and other assets, consistent with the widely accepted capital market principle that asset classes with higher volatility generate a greater return over the long-term. Current market factors such as inflation, interest rates, asset class risks and asset class returns are evaluated and considered before long-term capital market assumptions are determined. The long-term portfolio return is also established employing a consistent formal process, with due consideration of diversification, active investment management and rebalancing. Peer data is reviewed to check for reasonableness. As a result of this process, the Company has long-term rate of return assumptions for its pension plans of 7.75% and other postretirement benefit plans of 8.00%, for 2014. The Company believes these rates are a reasonable assumption for the long-term rate of return on its plan assets for 2014 given its investment strategy.
The Company employs a total return investment approach whereby a mix of equities, fixed income and other investments are used to maximize the long-term return on plan assets consistent with prudent levels of risk, with consideration given to the liquidity needs of the plan. Risk tolerance is established through consideration of future plan cash flows, plan funded status, and corporate financial considerations. The investment portfolio contains a diversified blend of equity, fixed income and other investments. Furthermore, equity investments are diversified across U.S. and non-U.S. stocks, growth and value stocks, and large and small market capitalizations. Fixed income securities generally include market and long duration bonds of companies from diversified industries, mortgage-backed securities, non-US securities, bank loans and U.S. Treasuries. Other assets such as private markets and hedge funds are used to enhance long-term returns while improving portfolio diversification. Derivatives may be utilized in a risk controlled manner, to potentially increase the portfolio beyond the market value of invested assets and/or reduce portfolio investment risk. Investment risk is measured and monitored on an ongoing basis through annual liability measurements, periodic asset/liability studies, and quarterly investment portfolio reviews.
Target allocations for pension plan assets as of December 31, 2013 are listed below:
U.S. Large Cap Equity Securities	22	%
U.S. Small Cap and Mid Cap Equity Securities	5
Non U.S. Equity Securities	20
Fixed Income Securities	25
Hedge Funds and Similar Investments	20
Private Equity and Other	8
	100	%
Fair Value Measurements for pension plan assets at December 31, 2013 and 2012 (a):
	31-Dec-13														31-Dec-12
	Level 1				Level 2				Level 3			Total			Level 1			Level 2			Level 3		Total
	(In millions)
Asset Category:
Short-term investments (b)	$	22			$	—			$	—		$	22		$	—		$	24		$	—	$	24
Equity securities
U.S. Large Cap (c)	896				—				—			896			688			44			—		732
U.S. Small/Mid Cap (d)	221				—				—			221			153			5			—		158
Non U.S. (e)	611				130				—			741			530			120			—		650
Fixed income securities (f)	16				921				—			937			87			765			—		852
Hedge Funds and Similar Investments (g)	268				70				395			733			209			80			339		628
Private Equity and Other (h)	—				—				170			170			—			—			179		179
Total	$	2,034			$	1,121			$	565		$	3,720		$	1,667		$	1,038		$	518	$	3,223
_______________________________________
(a)	See Note 3 — Fair Value for a description of levels within the fair value hierarchy.
(b)	This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category are obtained from quoted prices in actively traded markets or valuations from brokers or pricing services.
(c)	This category comprises both actively and not actively managed portfolios that track the S&P 500 low cost equity index funds. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
(d)	This category represents portfolios of small and medium capitalization domestic equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
(e)	This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
(f)	This category includes corporate bonds from diversified industries, U.S. Treasuries, and mortgage-backed securities. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. Non-exchange traded securities and exchange-traded securities held in commingled funds are classified as Level 2 assets.
(g)	This category utilizes a diversified group of strategies that attempt to capture financial market inefficiencies and includes publicly traded debt and equity, publicly traded mutual funds, commingled and limited partnership funds and non-exchange traded securities. Pricing for Level 1 and Level 2 assets in this category is obtained from quoted prices in actively traded markets and quoted prices from broker or pricing services. Non-exchange traded securities held in commingled funds are classified as Level 2 assets. Valuations for some Level 3 assets in this category may be based on limited observable inputs as there may be little, if any, publicly available pricing.
(h)	This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in timber and private mezzanine debt. Pricing for investments in this category is based on limited observable inputs as there is little, if any, publicly available pricing. Valuations for assets in this category may be based on discounted cash flow analyses, relevant publicly-traded comparables and comparable transactions.
The pension trust holds debt and equity securities directly and indirectly through commingled funds and institutional mutual funds. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. The commingled funds and institutional mutual funds hold exchange-traded equity or debt securities and are valued based on stated net asset values (NAV). Non-exchange traded fixed income securities are valued by the trustee based upon quotations available from brokers or pricing services. A primary price source is identified by asset type, class or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustees challenge an assigned price and determine 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 values of securities by comparison of market-based price sources.
Fair Value Measurements Using Significant Unobservable Inputs (Level 3):
	Year Ended December 31, 2013											Year Ended December 31, 2012
	Hedge Funds				Private Equity				Total			Hedge Funds			Private Equity			Total
	and Similar				and Other							and Similar			and Other
	Investments											Investments
	(In millions)
Beginning Balance at January 1	$	339			$	179			$	518		$	296		$	168		$	464
Total realized/unrealized gains (losses):
Realized gains (losses)	—				18				18			18			(6		)	12
Unrealized gains (losses)	40				(14		)		26			(5		)	12			7
Purchases, sales and settlements:
Purchases	16				15				31			250			33			283
Sales	—				(28		)		(28		)	(220		)	(28		)	(248		)
Ending Balance at December 31	$	395			$	170			$	565		$	339		$	179		$	518
The amount of total gains for the period attributable to the change in unrealized gains or losses related to assets still held at the end of the period	$	38			$	3			$	41		$	16		$	6		$	22
There were no transfers between Level 3 and Level 2 and there were no significant transfers between Level 2 and Level 1 in the years ended December 31, 2013 and 2012.
Other Postretirement Benefits
The Company provides certain other postretirement health care and life insurance benefits for employees who are eligible for these benefits. The Company’s policy is to fund certain trusts to meet its other postretirement benefit obligations. Separate qualified Voluntary Employees Beneficiary Association (VEBA) and 401(h) trusts exist for represented and non-represented employees. The Company contributed $264 million to its other postretirement medical and life insurance benefit plans during 2013. At the discretion of management, we anticipate making up to $145 million of contributions to the VEBA trusts in 2014.
Starting in 2012, in lieu of offering future employees post-employment health care and life insurance benefits, the Company allocates a fixed amount per year to an account in a tax-exempt trust for each employee. These trusts are managed either by the Company (for non-represented and certain represented groups), or by the Utility Workers of America (UWUA) for Local 223 employees. The cost of these plans was $2 million in 2013 and less than $1 million in 2012.
Beginning in 2013, the Company replaced sponsored retiree medical, prescription drug and dental coverage with a Retiree Health Care Allowance (RHCA). This change applies to both current and future Medicare eligible non-represented retirees, spouses, surviving spouses or same sex domestic partners; as well as future Medicare eligible represented retirees, spouses, surviving spouses or same sex domestic partners. The 2013 RHCA allowance ranged between $3,250 and $3,500 depending on an employee’s date of hire and will increase each year at the lower of the rate of medical inflation or 2%.
Net other postretirement cost includes the following components:
	2013				2012				2011
	(In millions)
Service cost	$	47			$	68			$	64
Interest cost	88				120				121
Expected return on plan assets	(110		)		(92		)		(94		)
Amortization of:
Net loss	64				80				55
Prior service credit	(131		)		(27		)		(26		)
Net transition asset	—				2				2
Net other postretirement cost (benefit)	$	(42	)		$	151			$	122
	2013				2012
	(In millions)
Other changes in plan assets and APBO recognized in Regulatory assets (liabilities) and Other comprehensive income
Net actuarial gain	$	(353	)		$	(34	)
Amortization of net actuarial loss	(64		)		(80		)
Prior service credit	(218		)		(264		)
Amortization of prior service credit	131				27
Amortization of transition asset	—				(2		)
Total recognized in Regulatory assets (liabilities) and Other comprehensive income	$	(504	)		$	(353	)
Total recognized in net periodic benefit cost, Regulatory assets (liabilities) and Other comprehensive income	$	(546	)		$	(202	)
Estimated amounts to be amortized from Regulatory assets (liabilities) and Accumulated other comprehensive income into net periodic benefit cost during next fiscal year
Net actuarial loss	$	21			$	69
Prior service credit	$	(144	)		$	(91	)
The following table reconciles the obligations, assets and funded status of the plans including amounts recorded as Accrued postretirement liability in the Consolidated Statements of Financial Position at December 31:
	2013				2012
	(In millions)
Change in accumulated postretirement benefit obligation
Accumulated postretirement benefit obligation, beginning of year	$	2,315			$	2,470
Service cost	47				68
Interest cost	88				120
Plan amendments	(218		)		(264		)
Actuarial (gain) loss	(267		)		5
Medicare Part D subsidy	1				6
Benefits paid	(88		)		(90		)
Accumulated postretirement benefit obligation, end of year	$	1,878			$	2,315
Change in plan assets
Plan assets at fair value, beginning of year	$	1,153			$	985
Actual return on plan assets	196				131
Company contributions	264				140
Benefits paid	(86		)		(103		)
Plan assets at fair value, end of year	$	1,527			$	1,153
Funded status, end of year	$	(351	)		$	(1,162	)
Amount recorded as:
Current liabilities	$	(1	)		$	(2	)
Noncurrent liabilities	(350		)		(1,160		)
	$	(351	)		$	(1,162	)
Amounts recognized in Accumulated other comprehensive loss, pre-tax
Net actuarial loss	$	29			$	40
Prior service credit	(10		)		(14		)
Net transition asset	—				(1		)
	$	19			$	25
Amounts recognized in Regulatory assets (liabilities) (See Note 11)
Net actuarial loss	$	321			$	727
Prior service credit	(393		)		(302		)
Net transition obligation	—				1
	$	(72	)		$	426
At December 31, 2013, the benefits expected to be paid, including prescription drug benefits, in each of the next five years and in the aggregate for the five fiscal years thereafter are as follows:
	(In millions)
2014	$	103
2015	110
2016	115
2017	123
2018	130
2019 — 2023	724
	$	1,305
Assumptions used in determining the accumulated postretirement benefit obligation and net other postretirement benefit costs are listed below:
	2013			2012			2011
Accumulated postretirement benefit obligation
Discount rate	4.95	%		4.15	%		5	%
Health care trend rate pre- and post- 65	7.5	/ 6.50%		7	%		7	%
Ultimate health care trend rate	4.5	%		5	%		5	%
Year in which ultimate reached pre- and post- 65	2025 / 2024			2021			2020
Other postretirement benefit costs
Discount rate (prior to interim remeasurement)	4.15	%		5	%		5.5	%
Discount rate (post interim remeasurement)	4.3	%		N/A			N/A
Expected long-term rate of return on plan assets	8.25	%		8.25	%		8.75	%
Health care trend rate pre- and post- 65	7	%		7	%		7	%
Ultimate health care trend rate	5	%		5	%		5	%
Year in which ultimate reached	2021			2020			2019
A one percentage point increase in health care cost trend rates would have increased the total service cost and interest cost components of benefit costs by $9 million in 2013 and increased the accumulated benefit obligation by $124 million at December 31, 2013. A one percentage point decrease in the health care cost trend rates would have decreased the total service and interest cost components of benefit costs by $8 million in 2013 and would have decreased the accumulated benefit obligation by $108 million at December 31, 2013.
The process used in determining the long-term rate of return for assets and the investment approach for the Company’s other postretirement benefits plans is similar to those previously described for its pension plans.
Target allocations for other postretirement benefit plan assets as of December 31, 2013 are listed below:
U.S. Large Cap Equity Securities	17	%
U.S. Small Cap and Mid Cap Equity Securities	4
Non U.S. Equity Securities	20
Fixed Income Securities	25
Hedge Funds and Similar Investments	20
Private Equity and Other	14
	100	%
Fair Value Measurements for other postretirement benefit plan assets at December 31, 2013 and 2012 (a):
	31-Dec-13														31-Dec-12
	Level 1				Level 2				Level 3			Total			Level 1			Level 2			Level 3		Total
Asset Category:	(In millions)
Short-term investments (b)	$	5			$	—			$	—		$	5		$	1		$	2		$	—	$	3
Equity securities:
U.S. Large Cap (c)	302				—				—			302			189			3			—		192
U.S. Small/Mid Cap (d)	147				—				—			147			105			—			—		105
Non U.S. (e)	282				9				—			291			230			7			—		237
Fixed income securities (f)	17				350				—			367			38			247			—		285
Hedge Funds and Similar Investments (g)	130				25				159			314			102			24			119		245
Private Equity and Other (h)	—				—				101			101			—			—			86		86
Total	$	883			$	384			$	260		$	1,527		$	665		$	283		$	205	$	1,153
_______________________________________
(a)	See Note 3 — Fair Value for a description of levels within the fair value hierarchy.
(b)	This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category are obtained from quoted prices in actively traded markets or valuations from brokers or pricing services.
(c)	This category comprises both actively and not actively managed portfolios that track the S&P 500 low cost equity index funds. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
(d)	This category represents portfolios of small and medium capitalization domestic equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
(e)	This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
(f)	This category includes corporate bonds from diversified industries, U.S. Treasuries, bank loans and mortgage backed securities. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. Non-exchange traded securities and exchange-traded securities held in commingled funds are classified as Level 2 assets.
(g)	This category utilizes a diversified group of strategies that attempt to capture financial market inefficiencies and includes publicly traded debt and equity, publicly traded mutual funds, commingled and limited partnership funds and non-exchange traded securities. Pricing for Level 1 and Level 2 assets in this category is obtained from quoted prices in actively traded markets and quoted prices from broker or pricing services. Non-exchange traded securities held in commingled funds are classified as Level 2 assets. Valuations for some Level 3 assets in this category may be based on limited observable inputs as there may be little, if any, publicly available pricing.
(h)	This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in timber and private mezzanine debt. Pricing for investments in this category is based on limited observable inputs as there is little, if any, publicly available pricing. Valuations for assets in this category may be based on discounted cash flow analyses, relevant publicly-traded comparables and comparable transactions.
The VEBA trusts hold debt and equity securities directly and indirectly through commingled funds and institutional mutual funds. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. The commingled funds and institutional mutual funds hold exchange-traded equity or debt securities and are valued based on net asset values (NAV). Non-exchange traded fixed income securities are valued by the trustee based upon quotations available from brokers or pricing services. A primary price source is identified by asset type, class or issue for each security. The trustees monitor prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustees challenge an assigned price and determine 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 values of securities by comparison of market-based price sources.
Fair Value Measurements Using Significant Unobservable Inputs (Level 3):
	Year Ended December 31, 2013											Year Ended December 31, 2012
	Hedge Funds				Private Equity				Total			Hedge Funds			Private Equity			Total
	and Similar				and Other							and Similar			and Other
	Investments											Investments
	(In millions)
Beginning Balance at January 1	$	119			$	86			$	205		$	95		$	60		$	155
Total realized/unrealized gains (losses):
Realized gains (losses)	—				2				2			6			(11		)	(5		)
Unrealized gains	14				7				21			—			14			14
Purchases, sales and settlements:
Purchases	26				15				41			86			36			122
Sales	—				(9		)		(9		)	(68		)	(13		)	(81		)
Ending Balance at December 31	$	159			$	101			$	260		$	119		$	86		$	205
The amount of total gains for the period attributable to the change in unrealized gains or losses related to assets still held at the end of the period	$	14			$	9			$	23		$	6		$	2		$	8
There were no transfers between Level 3 and Level 2 and there were no significant transfers between Level 2 and Level 1 in the years ended December 31, 2013 and 2012.
Interim 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 other postretirement benefit costs.
Based on the impact of such benefit cost savings on the consolidated 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. Beginning April 2013, net other postretirement benefit costs were recorded based on the updated actuarial assumptions and benefit changes resulting from the new labor contracts.
Healthcare Legislation
In December 2003, the Medicare Act was signed into law which provides for a non-taxable federal subsidy to sponsors of retiree health care benefit plans that provide a benefit that is at least “actuarially equivalent” to the benefit established by law. The effects of the subsidy reduced net periodic other postretirement benefit costs by $1 million in 2013, $6 million in 2012 and $6 million in 2011.
Grantor Trust
DTE Gas maintains a Grantor Trust to fund other postretirement benefit obligations that invests in life insurance contracts and income securities. Employees and retirees have no right, title or interest in the assets of the Grantor Trust, and DTE Gas can revoke the trust subject to providing the MPSC with prior notification. The Company accounts for its investment at fair value, approximately $17 million and $14 million at December 31, 2013 and 2012, respectively, with unrealized gains and losses recorded to earnings. The Grantor Trust investment is included in Other investments on the Consolidated Statements of Financial Position.
Defined Contribution Plans
The Company also sponsors defined contribution retirement savings plans. Participation in one of these plans is available to substantially all represented and non-represented employees. The Company matches employee contributions up to certain predefined limits based upon eligible compensation, the employee’s contribution rate and, in some cases, years of credited service. The cost of these plans was $41 million, $37 million, and $35 million in each of the years 2013, 2012, and 2011, respectively.

StockBased_Compensation_Notes

Stock-Based Compensation (Notes)	12 Months Ended
	Dec. 31, 2013
Share-based Compensation [Abstract]	'
Stock-based Compensation	'
	STOCK-BASED COMPENSATION
	The Company’s stock incentive program permits the grant of incentive stock options, non-qualifying stock options, stock awards, performance shares and performance units to employees and members of its Board of Directors. Key provisions of the stock incentive program are:
	•	Authorized limit is 11,500,000 shares of common stock;
	•	Prohibits the grant of a stock option with an exercise price that is less than the fair market value of the Company’s stock on the date of the grant; and
	•	Imposes the following award limits to a single participant in a single calendar year, (1) options for more than 500,000 shares of common stock; (2) stock awards for more than 150,000 shares of common stock; (3) performance share awards for more than 300,000 shares of common stock (based on the maximum payout under the award); or (4) more than 1,000,000 performance units, which have a face amount of $1.00 each.
	The Company records compensation expense at fair value over the vesting period for all awards it grants.
	Stock-based compensation for the reporting periods is as follows:
		2013				2012			2011
		(In millions)
	Stock-based compensation expense	$	99			$	83		$	66
	Tax benefit	38				33			25
	Stock-based compensation cost capitalized in property, plant and equipment	15				5			4
	Stock Options
	Options are exercisable according to the terms of the individual stock option award agreements and expire 10 years after the date of the grant. The option exercise price equals the fair value of the stock on the date that the option was granted. Stock options vest ratably over a 3-year period.
	Stock option activity was as follows:
		Number of			Weighted			Aggregate
		Options			Average			Intrinsic
					Exercise Price			Value (In millions)
	Options outstanding at December 31, 2012	1,192,670			$	41.86
	Granted	—			$	—
	Exercised	(458,603	)		$	40.71
	Forfeited or expired	(10,370	)		$	41.46
	Options outstanding and exercisable at December 31, 2013	723,697			$	42.6		$	18
	As of December 31, 2013, the weighted average remaining contractual life for the exercisable shares is 3.83 years. As of December 31, 2013, all options were vested. During 2013, 200,844 options vested.
	There were no options granted during 2013, 2012 or 2011. The intrinsic value of options exercised for the years ended December 31, 2013, 2012 and 2011 was $12 million, $25 million, and $20 million, respectively. Total option expense recognized during 2013, 2012 and 2011 was zero, $0.7 million and $2 million, respectively.
	The number, weighted average exercise price and weighted average remaining contractual life of options outstanding were as follows:
											Weighted Average		Weighted Average
								Number of Options			Exercise Price		Remaining Contractual Life (Years)
	Range of Exercise Prices
	$	27		—	$	38		67,257			$	28.3	5.15
	$	38.01		—	$	42		167,447			$	41.23	3.21
	$	42.01		—	$	45		351,893			$	44.02	4.16
	$	45.01		—	$	50		137,100			$	47.67	3.08
								723,697			$	42.6	3.83
	Restricted Stock Awards
	Stock awards granted under the plan are restricted for varying periods, generally for three years. Participants have all rights of a shareholder with respect to a stock award, including the right to receive dividends and vote the shares. Prior to vesting in stock awards, the participant: (i) may not sell, transfer, pledge, exchange or otherwise dispose of shares; (ii) shall not retain custody of the share certificates; and (iii) will deliver to the Company a stock power with respect to each stock award upon request.
	The stock awards are recorded at cost that approximates fair value on the date of grant. The cost is amortized to compensation expense over the vesting period.
	Stock award activity for the years ended December 31 was:
		2013				2012			2011
	Fair value of awards vested (in millions)	$	8			$	9		$	13
	Restricted common shares awarded	127,785				167,320			381,840
	Weighted average market price of shares awarded	$	64.72			$	53.71		$	47.98
	Compensation cost charged against income (in millions)	$	23			$	12		$	12
	The following table summarizes the Company’s stock awards activity for the period ended December 31, 2013:
		Restricted			Weighted Average
		Stock			Grant Date
					Fair Value
	Balance at December 31, 2012	597,648			$	48.33
	Grants	127,785			$	64.72
	Forfeitures	(7,155	)		$	54.61
	Vested and issued	(225,949	)		$	45.54
	Balance at December 31, 2013	492,329			$	53.76
	Performance Share Awards
	Performance shares awarded under the plan are for a specified number of shares of common stock that entitle the holder to receive a cash payment, shares of common stock or a combination thereof. The final value of the award is determined by the achievement of certain performance objectives and market conditions. The awards vest at the end of a specified period, usually three years. The Company accounts for performance share awards by accruing compensation expense over the vesting period based on: (i) the number of shares expected to be paid which is based on the probable achievement of performance objectives; and (ii) the closing stock price market value. The settlement of the award is based on the closing price at the settlement date.
	The Company recorded compensation expense for performance share awards as follows:
		2013				2012			2011
		(In millions)
	Compensation expense	$	77			$	71		$	53
	Cash settlements (a)	$	9			$	4		$	3
	Stock settlements (a)	$	56			$	41		$	25
	_______________________________________
	(a)	Sum of cash and stock settlements approximates the intrinsic value of the liability.
	During the vesting period, the recipient of a performance share award has no shareholder rights. During the period beginning on the date the performance shares are awarded and ending on the certification date of the performance objectives, the number of performance shares awarded will be increased, assuming full dividend reinvestment at the fair market value on the dividend payment date. The cumulative number of performance shares will be adjusted to determine the final payment based on the performance objectives achieved. Performance share awards are nontransferable and are subject to risk of forfeiture.
The following table summarizes the Company’s performance share activity for the period ended December 31, 2013:
	Performance Shares
Balance at December 31, 2012	1,634,364
Grants	564,561
Forfeitures	(41,512	)
Payouts	(548,624	)
Balance at December 31, 2013	1,608,789
Unrecognized Compensation Costs
As of December 31, 2013, there was $55 million of total unrecognized compensation cost related to non-vested stock-based compensation arrangements. That cost is expected to be recognized over a weighted-average period of 0.93 years.
	Unrecognized				Weighted Average
	Compensation				to be Recognized
	Cost
	(In millions)				(In years)
Stock awards	$	10			0.93
Performance shares	45				0.93
	$	55			0.93

Segment_Information_Notes

Segment Information (Notes)	12 Months Ended
	Dec. 31, 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:
		2013			2012			2011
		(In millions)
	Electric	$	26		$	29		$	33
	Gas	4			4			2
	Gas Storage and Pipelines	3			6			8
	Power and Industrial Projects	816			801			238
	Energy Trading	43			43			70
	Corporate and Other	(24		)	(37		)	(50		)
	Discontinued Operations	—			2			—
		$	868		$	848		$	301
	Financial data of the business segments follows:
		Operating			Depreciation,			Interest			Interest			Income			Net Income (Loss)			Total			Goodwill		Capital
		Revenue			Depletion &			Income			Expense			Taxes			Attributable			Assets					Expenditures
					Amortization												to DTE
																	Energy
																	Company
		(In millions)
	2013
	Electric	$	5,199		$	902		$	(1	)	$	268		$	252		$	484		$	17,508		$	1,208	$	1,325
	Gas	1,474			95			(7		)	58			77			143			3,938			743		209
	Gas Storage and Pipelines	132			23			(7		)	18			45			70			824			24		245
	Power and Industrial Projects	1,950			72			(6		)	27			(45		)	66			1,067			26		93
	Energy Trading	1,771			1			—			8			(38		)	(58		)	623			17		3
	Corporate and Other	3			1			(51		)	120			(37		)	(44		)	2,945			—		1
	Reclassifications and Eliminations	(868		)	—			63			(63		)	—			—			(970		)	—		—
	Total	$	9,661		$	1,094		$	(9	)	$	436		$	254		$	661		$	25,935		$	2,018	$	1,876
		Operating			Depreciation,			Interest			Interest			Income			Net Income (Loss)			Total			Goodwill		Capital
		Revenue			Depletion &			Income			Expense			Taxes			Attributable			Assets					Expenditures
					Amortization												to DTE
																	Energy
																	Company
		(In millions)
	2012
	Electric	$	5,293		$	827		$	(1	)	$	272		$	280		$	483		$	17,755		$	1,208	$	1,230
	Gas	1,315			92			(7		)	59			50			115			4,059			745		221
	Gas Storage and Pipelines	96			8			(8		)	8			39			61			668			22		233
	Power and Industrial Projects	1,823			65			(7		)	37			(44		)	42			991			26		83
	Energy Trading	1,109			2			—			8			7			12			629			17		1
	Corporate and Other	3			1			(52		)	121			(46		)	(47		)	3,074			—		3
	Reclassifications and Eliminations	(848		)	—			65			(65		)	—			—			(837		)	—		—
	Total from Continuing Operations	$	8,791		$	995		$	(10	)	$	440		$	286		$	666		$	26,339		$	2,018	$	1,771
	Discontinued Operations (Note 7)																(56		)	—			—		49
	Total																$	610		$	26,339		$	2,018	$	1,820
		Operating			Depreciation,			Interest			Interest			Income			Net Income (Loss)			Total			Goodwill		Capital
		Revenue			Depletion &			Income			Expense			Taxes			Attributable			Assets					Expenditures
					Amortization												to DTE
																	Energy
																	Company
		(In millions)
	2011
	Electric	$	5,154		$	818		$	(1	)	$	289		$	265		$	434		$	17,567		$	1,208	$	1,203
	Gas	1,505			89			(7		)	64			60			110			4,065			745		179
	Gas Storage and Pipelines	91			6			(5		)	7			35			57			538			22		16
Power and Industrial Projects	1,129			60			(8		)	32			11			38			789			26		56
Energy Trading	1,276			3			—			9			34			52			612			17		1
Corporate & Other	4			1			(47		)	145			(136		)	23			2,605			—		—
Reclassifications and Eliminations	(301		)	—			58			(58		)	(1		)	—			(485		)	—		—
Total from Continuing Operations	$	8,858		$	977		$	(10	)	$	488		$	268		$	714		$	25,691		$	2,018	$	1,455
Discontinued Operations (Note 7)																(3		)	318			2		29
Total																$	711		$	26,009		$	2,020	$	1,484

Supplementary_Quarterly_Financ

Supplementary Quarterly Financial Information (Unaudited)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Quarterly Financial Information [Text Block]	'
	SUPPLEMENTARY QUARTERLY FINANCIAL INFORMATION (UNAUDITED)
	Quarterly earnings per share may not equal full year totals, since quarterly computations are based on weighted average common shares outstanding during each quarter.
		First		Second			Third		Fourth			Year
		Quarter		Quarter			Quarter		Quarter
		(In millions, except per share amounts)
	2013
	Operating Revenues	$	2,516	$	2,225		$	2,387	$	2,533		$	9,661
	Operating Income	$	410	$	223		$	329	$	241		$	1,203
	Net Income Attributable to DTE Energy Company	$	234	$	105		$	198	$	124		$	661
	Basic Earnings per Share	$	1.35	$	0.6		$	1.13	$	0.7		$	3.76
	Diluted Earnings per Share	$	1.34	$	0.6		$	1.13	$	0.7		$	3.76
	2012
	Operating Revenues	$	2,239	$	2,013		$	2,190	$	2,349		$	8,791
	Operating Income	$	312	$	294		$	406	$	267		$	1,279
	Net Income Attributable to DTE Energy Company
	Continuing Operations	$	156	$	147		$	226	$	137		$	666
	Discontinued Operations	—		(1		)	1		(56		)	(56		)
	Net Income Attributable to DTE Energy Company	$	156	$	146		$	227	$	81		$	610
	Basic Earnings per Share
	Continuing Operations	$	0.91	$	0.87		$	1.31	$	0.79		$	3.89
	Discontinued Operations	—		(0.01		)	0.01		(0.32		)	(0.33		)
	Total	$	0.91	$	0.86		$	1.32	$	0.47		$	3.56
	Diluted Earnings per Share
	Continuing Operations	$	0.91	$	0.87		$	1.3	$	0.79		$	3.88
	Discontinued Operations	—		(0.01		)	0.01		(0.32		)	(0.33		)
	Total	$	0.91	$	0.86		$	1.31	$	0.47		$	3.55

Valuation_and_Qualifying_Accou

Valuation and Qualifying Accounts (Notes)	12 Months Ended
	Dec. 31, 2013
Valuation and Qualifying Accounts [Abstract]	'
Schedule of Valuation and Qualifying Accounts Disclosure [Text Block]	'
	Valuation and Qualifying Accounts
		Year Ending December 31,
		2013			2012			2011
		(In millions)
	Allowance for Doubtful Accounts (shown as deduction from Accounts Receivable in the Consolidated Statements of Financial Position)
	Balance at Beginning of Period	$	62		$	162		$	196
	Additions:
	Charged to costs and expenses	94			79			94
	Charged to other accounts (a)	23			16			18
	Deductions (b)	(124		)	(195		)	(146		)
	Balance at End of Period	$	55		$	62		$	162
	_______________________________________
	(a)	Collection of accounts previously written off.
	(b)	Uncollectible accounts written off.

Significant_Accounting_Policie1

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Basis of Accounting, Policy [Policy Text Block]	'
	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.
Consolidation, Variable Interest Entity, Policy [Policy Text Block]	'
	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 plant. 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 are 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 December 31, 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 December 31, 2013 and 2012. All assets and liabilities of a consolidated VIE are presented where it has been determined that a consolidated VIE has either (1) assets that can be used only to settle obligations of the VIE or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary. 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.
Revenues Policy [Policy Text Block]	'
	Revenues
	Revenues from the sale and delivery of electricity, and the sale, delivery and storage of natural gas are recognized as services are provided. DTE Electric and DTE Gas record revenues for electricity and gas provided but unbilled at the end of each month. Rates for DTE Electric and DTE Gas include provisions to adjust billings for fluctuations in fuel and purchased power costs, cost of natural gas and certain other costs. Revenues are adjusted for differences between actual costs subject to reconciliation and the amounts billed in current rates. Under or over recovered revenues related to these cost recovery mechanisms are recorded on the Consolidated Statements of Financial Position and are recovered or returned to customers through adjustments to the billing factors.
	See Note 11 for further discussion of recovery mechanisms authorized by the MPSC.
	Non-utility businesses recognize revenues as services are provided and products are delivered. See Note 4 for discussion of derivative contracts.
Accounting For ISO Transactions [Policy Text Block]	'
	Accounting for ISO Transactions
	DTE Electric participates in the energy market through MISO. MISO requires that we submit hourly day-ahead, real- time and FTR bids and offers for energy at locations across the MISO region. DTE Electric accounts for MISO transactions on a net hourly basis in each of the day-ahead, real-time and FTR markets and net transactions across all MISO energy market locations. In any single hour DTE Electric records net purchases in Fuel, purchased power and gas and net sales in Operating revenues on the Consolidated Statements of Operations.
	Energy Trading participates in the energy markets through various independent system operators and regional transmission organizations (ISOs and RTOs). These markets require that Energy Trading submits hourly day-ahead, real-time bids and offers for energy at locations across each region. Energy Trading submits bids in the annual and monthly auction revenue rights and FTR auctions to the regional transmission organizations. Energy Trading accounts for these transactions on a net hourly basis for the day-ahead, real-time and FTR markets. These transactions are related to trading contracts which are presented on a net basis in Operating Revenues in the Consolidated Statements of Operations.
	DTE Electric and Energy Trading record accruals for future net purchases adjustments based on historical experience, and reconcile accruals to actual costs when invoices are received from MISO, and other ISOs and RTOs.
Comprehensive Income [Policy Text Block]	'
	Comprehensive Income (Loss)
	Comprehensive income (loss) is the change in common shareholders’ equity during a period from transactions and events from non-owner sources, including net income. As shown in the following tables, amounts recorded to accumulated other comprehensive loss for the year ended December 31, 2013 include unrealized gains and losses from derivatives accounted for as cash flow hedges, unrealized gains and losses on available-for-sale securities, 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.
Cash and Cash Equivalents [Policy Text Block]	'
	Cash Equivalents and Restricted Cash
	Cash and cash equivalents include cash on hand, cash in banks and temporary investments purchased with remaining maturities of three months or less. Restricted cash consists of funds held to satisfy requirements of certain debt, primarily Securitization bonds, and partnership operating agreements. Restricted cash designated for interest and principal payments within one year is classified as a current asset.
Receivables [Policy Text Block]	'
	Receivables
	Accounts receivable are primarily composed of trade receivables and unbilled revenue. Our accounts receivable are stated at net realizable value.
	The allowance for doubtful accounts for DTE Electric and DTE Gas is generally calculated using the aging approach that utilizes rates developed in reserve studies. We establish an allowance for uncollectible accounts based on historical losses and management’s assessment of existing economic conditions, customer trends, and other factors. Customer accounts are generally considered delinquent if the amount billed is not received by the due date, which is typically in 21 days, however, factors such as assistance programs may delay aggressive action. We assess late payment fees on trade receivables based on past-due terms with customers. Customer accounts are written off when collection efforts have been exhausted. The time period for write-off is 150 days after service has been terminated.
	The customer allowance for doubtful accounts for our other businesses is calculated based on specific review of probable future collections based on receivable balances in excess of 30 days.
	Unbilled revenues of $815 million and $686 million are included in customer accounts receivable at December 31, 2013 and 2012, respectively.
	Notes Receivable
	Notes receivable, or financing receivables, are primarily comprised of capital lease receivables and loans and are included in Notes receivable and Other current assets on the Company’s Consolidated Statements of Financial Position.
	Notes receivable are typically considered delinquent when payment is not received for periods ranging from 60 to 120 days. The Company ceases accruing interest (nonaccrual status), considers a note receivable impaired, and establishes an allowance for credit loss when it is probable that all principal and interest amounts due will not be collected in accordance with the contractual terms of the note receivable. Cash payments received on nonaccrual status notes receivable, that do not bring the account contractually current, are first applied to contractually owed past due interest, with any remainder applied to principal. Accrual of interest is generally resumed when the note receivable becomes contractually current.
	In determining the allowance for credit losses for notes receivable, we consider the historical payment experience and other factors that are expected to have a specific impact on the counterparty’s ability to pay. In addition, the Company monitors the credit ratings of the counterparties from which we have notes receivable.
Inventories [Policy Text Block]	'
	Inventories
	The Company generally values inventory at average cost.
	Natural gas inventory of $4 million and $37 million as of December 31, 2013 and 2012, respectively, at DTE Gas is determined using the last-in, first-out (LIFO) method. At December 31, 2013, the replacement cost of gas remaining in storage exceeded the LIFO cost by $170 million. At December 31, 2012, the replacement cost of gas remaining in storage exceeded the LIFO cost by $113 million.
Property, Retirement and Maintenance, Depreciation, Depletion and Amortization [Policy Text Block]	'
	Property, Retirement and Maintenance, and Depreciation, Depletion and Amortization
	Property is stated at cost and includes construction-related labor, materials, overheads and, for utility property, an allowance for funds used during construction (AFUDC). The cost of utility properties retired is charged to accumulated depreciation. Expenditures for maintenance and repairs are charged to expense when incurred, except for Fermi 2.
	Utility property at DTE Electric and DTE Gas is depreciated over its estimated useful life using straight-line rates approved by the MPSC.
	Non-utility property is depreciated over its estimated useful life using the straight-line and units of production methods.
	Depreciation, depletion and amortization expense also includes the amortization of certain regulatory assets.
	Approximately $26 million and $12 million of expenses related to Fermi 2 refueling outages were accrued at December 31, 2013 and 2012, respectively. Amounts are accrued on a pro-rata basis, generally over an 18-month period, that coincides with scheduled refueling outages at Fermi 2. This accrual of outage costs matches the regulatory recovery of these costs in rates set by the MPSC. See Note 11.
	The cost of nuclear fuel is capitalized. The amortization of nuclear fuel is included within Fuel, purchased power, and gas in the Consolidated Statements of Operations and is recorded using the units-of-production method.
	Capitalized software costs are classified as Property, plant and equipment and the related amortization is included in Accumulated depreciation, depletion and amortization on the Consolidated Statements of Financial Position. The Company capitalizes the costs associated with computer software it develops or obtains for use in its business. The Company amortizes capitalized software costs on a straight-line basis over the expected period of benefit
Long-Lived Assets [Policy Text Block]	'
	Long-Lived Assets
	Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of an asset may not be recoverable. If the carrying amount of the asset exceeds the expected discounted future cash flows generated by the asset, an impairment loss is recognized resulting in the asset being written down to its estimated fair value. Assets to be disposed of are reported at the lower of the carrying amount or fair value, less costs to sell.
Intangible Assets	'
	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 1 to 28 years. Intangible assets amortization expense was $14 million in 2013, $6 million in 2012 and $5 million in 2011.
Deferred Debt Costs [Policy Text Block]	'
	Deferred Debt Costs
	The costs related to the issuance of long-term debt are deferred and amortized over the life of each debt issue. In accordance with MPSC regulations applicable to the Company’s electric and gas utilities, the unamortized discount, premium and expense related to utility debt redeemed with a refinancing are amortized over the life of the replacement issue. Discount, premium and expense on early redemptions of debt associated with non-utility operations are charged to earnings.
Investments in Debt and Equity Securities [Policy Text Block]	'
	Investments in Debt and Equity Securities
	The Company generally classifies investments in debt and equity securities as either trading or available-for-sale and has recorded such investments at market value with unrealized gains or losses included in earnings or in other comprehensive income or loss, respectively. Changes in the fair value of Fermi 2 nuclear decommissioning investments are recorded as adjustments to regulatory assets or liabilities, due to a recovery mechanism from customers. The Company’s equity investments are reviewed for impairment each reporting period. If the assessment indicates that the impairment is other than temporary, a loss is recognized resulting in the equity investment being written down to its estimated fair value. See Note 3.
Government Grants [Policy Text Block]	'
	Government Grants
	Grants are recognized when there is reasonable assurance that the grant will be received and that any conditions associated with the grant will be met. When grants are received related to Property, Plant and Equipment, the Company reduces the cost of the assets on the Consolidated Statements of Financial Position, resulting in lower depreciation expense over the life of the associated asset. Grants received related to expenses are reflected as a reduction of the associated expense in the period in which the expense is incurred.
Foundation Related Party [Policy Text Block]	'
	DTE Energy Foundation
	Charitable contributions to the DTE Energy Foundation were $18 million, $21 million, and $21 million for the years ended December 31, 2013, 2012 and 2011, respectively. The DTE Energy Foundation is a non-consolidated not-for-profit private foundation, the purpose of which is to contribute to and assist charitable organizations and does not serve a direct business or political purpose of DTE.
Fair Value Measurement, Policy [Policy Text Block]	'
	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 December 31, 2013 and 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.
Nuclear Decommissioning Trust and Other Investments, Policy [Policy Text Block]	'
	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.
Derivatives, Reporting of Derivative Activity [Policy Text Block]	'
	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.
Fair Value Transfer, Policy [Policy Text Block]	'
	Derivatives are transferred between levels primarily due to changes in the source data used to construct price curves as a result of changes in market liquidity. Transfers in and transfers out are reflected as if they had occurred at the beginning of the period.
Fair Value of Financial Instruments, Policy [Policy Text Block]	'
	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 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.
Derivatives, Policy [Policy Text Block]	'
	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 the 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.
Derivatives, Offsetting Fair Value Amounts, Policy [Policy Text Block]	'
	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 $19 million and $63 million at December 31, 2013 and 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.
Derivatives, Methods of Accounting, Derivatives Not Designated or Qualifying as Hedges [Policy Text Block]	'
	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.
Asset Retirement Obligations, Policy [Policy Text Block]	'
	The Company has a legal retirement obligation for the decommissioning costs for its Fermi 1 and Fermi 2 nuclear plants, dismantlement of facilities located on leased property and various other operations. The Company has conditional retirement obligations for gas pipelines, asbestos and PCB removal at certain of its power plants and various distribution equipment. The Company recognizes such obligations as liabilities at fair market value when they are incurred, which generally is at the time the associated assets are placed in service. Fair value is measured using expected future cash outflows discounted at our credit-adjusted risk-free rate. In its regulated operations, the Company recognizes regulatory assets or liabilities for timing differences in expense recognition for legal asset retirement costs that are currently recovered in rates.
	If a reasonable estimate of fair value cannot be made in the period in which the retirement obligation is incurred, such as for assets with indeterminate lives, the liability is recognized when a reasonable estimate of fair value can be made. Natural gas storage system assets, substations, manholes and certain other distribution assets have an indeterminate life. Therefore, no liability has been recorded for these assets.
Public Utilities, Policy [Policy Text Block]	'
	DTE Electric and DTE Gas are required to record regulatory assets and liabilities for certain transactions that would have been treated as revenue or expense in non-regulated businesses. Continued applicability of regulatory accounting treatment requires that rates be designed to recover specific costs of providing regulated services and be charged to and collected from customers. Future regulatory changes or changes in the competitive environment could result in the discontinuance of this accounting treatment for regulatory assets and liabilities for some or all of our businesses and may require the write-off of the portion of any regulatory asset or liability that was no longer probable of recovery through regulated rates. Management believes that currently available facts support the continued use of regulatory assets and liabilities and that all regulatory assets and liabilities are recoverable or refundable in the current regulatory environment.
Income Tax, Policy [Policy Text Block]	'
	Excise and Sales Taxes
	The Company records the billing of excise and sales taxes as a receivable with an offsetting payable to the applicable taxing authority, with no net impact on the Consolidated Statements of Operations.
	Deferred tax assets and liabilities are recognized for the estimated future tax effect of temporary differences between the tax basis of assets or liabilities and the reported amounts in the financial statements. Deferred tax assets and liabilities are classified as current or noncurrent according to the classification of the related assets or liabilities. Deferred tax assets and liabilities not related to assets or liabilities are classified according to the expected reversal date of the temporary differences. Consistent with rate making treatment, deferred taxes are offset in the table below for temporary differences which have related regulatory assets and liabilities.
	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.
Compensation Related Costs, Policy [Policy Text Block]	'
	The Company records compensation expense at fair value over the vesting period for all awards it grants.

Organization_and_Basis_of_Pres1

Organization and Basis of Presentation (Tables)	12 Months Ended
	Dec. 31, 2013
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]	'
Schedule of Variable Interest Entities [Table Text Block]	'
		31-Dec-13						31-Dec-12
		Securitization		Other		Total		Securitization		Other		Total
		(In millions)
	ASSETS
	Cash and cash equivalents	$	—	$	12	$	12	$	—	$	10	$	10
	Restricted cash	100		8		108		102		7		109
	Accounts receivable	34		16		50		34		7		41
	Inventories	—		118		118		—		141		141
	Other current assets	—		1		1		—		1		1
	Property, plant and equipment	—		99		99		—		93		93
	Securitized regulatory assets	231		—		231		413		—		413
	Other assets	4		8		12		7		11		18
		$	369	$	262	$	631	$	556	$	270	$	826
	LIABILITIES
	Accounts payable and accrued current liabilities	$	7	$	23	$	30	$	11	$	14	$	25
	Current portion long-term debt, including capital leases	196		9		205		177		8		185
	Current regulatory liabilities	43		—		43		50		—		50
	Other current liabilities	—		4		4		—		4		4
	Mortgage bonds, notes and other	—		21		21		—		25		25
	Securitization bonds	105		—		105		302		—		302
	Capital lease obligations	—		7		7		—		11		11
	Other long-term liabilities	8		2		10		7		2		9
		$	359	$	66	$	425	$	547	$	64	$	611
Summary of amounts for non-consolidated VIEs [Table Text Block	'
		December 31,		December 31,
		2013		2012
		(In millions)
	Other investments	$	141	$	130
	Notes receivable	$	8	$	6

Significant_Accounting_Policie2

Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Schedule of Comprehensive Income (Loss) [Table Text Block]	'
		Changes in Accumulated Other Comprehensive Loss by Component (a)
		For The Year Ended December 31, 2013
		Net			Net			Benefit			Foreign			Total
		Unrealized			Unrealized			Obligations			Currency
		Gain/(Loss)			Gain/(Loss)			(b)			Translation
		on Derivatives			on Investments
		(In millions)
	Beginning balances December 31, 2012	$	(4	)	$	(8	)	$	(148	)	$	2		$	(158	)
	Other comprehensive income (loss) before reclassifications	—			2			13			(2		)	13
	Amounts reclassified from accumulated other comprehensive income (loss)	—			—			9			—			9
	Net current-period other comprehensive income (loss)	—			2			22			(2		)	22
	Ending balances December 31, 2013	$	(4	)	$	(6	)	$	(126	)	$	—		$	(136	)
	______________________________________
	(a)	All amounts are net of tax.
	(b)	The amounts reclassified from accumulated other comprehensive income (loss) are included in the computation of the net periodic pension and other postretirement benefit costs (see Note 20).
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:
		December 31,			December 31,
		2013			2012
		(In millions)
	Emission allowances	$	2		$	6
	Renewable energy credits	51			44
	Contract intangible assets	126			139
		179			189
	Less accumulated amortization	45			34
	Intangible assets, net	134			155
	Less current intangible assets	12			20
		$	122		$	135
Schedule of Finite-Lived Intangible Assets, Future Amortization Expense [Table Text Block]	'
	The following table summarizes the estimated amortization expense expected to be recognized during each year through 2018:
	Estimated amortization expense	(In millions)
	2014	$	13
	2015	$	12
	2016	$	11
	2017	$	8
	2018	$	8

Fair_Value_Tables

Fair Value (Tables)	12 Months Ended
	Dec. 31, 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 December 31, 2013 and 2012:
		31-Dec-13																				31-Dec-12
		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)	$	10			$	115			$	—			$	—			$	125			$	—			$	123		$	—		$	—		$	123
	Nuclear decommissioning trusts	779				412				—				—				1,191				694				343			—			—			1,037
	Other investments (c) (d)	92				44				—				—				136				66				44			—			—			110
	Derivative assets:
	Commodity Contracts:
	Natural Gas	273				89				34				(382		)		14				555				66			24			(605		)	40
	Electricity	—				261				139				(291		)		109				—				226			134			(258		)	102
	Other	33				1				3				(34		)		3				6				3			2			(6		)	5
	Total derivative assets	306				351				176				(707		)		126				561				295			160			(869		)	147
	Total	$	1,187			$	922			$	176			$	(707	)		$	1,578			$	1,321			$	805		$	160		$	(869	)	$	1,417
	Liabilities:
	Derivative liabilities:
	Commodity Contracts:
	Natural Gas	$	(277	)		$	(140	)		$	(86	)		$	395			$	(108	)		$	(526	)		$	(73	)	$	(62	)	$	605		$	(56	)
	Electricity	—				(272		)		(126		)		269				(129		)		—				(240		)	(111		)	258			(93		)
	Other	(32		)		(2		)		—				34				—				(6		)		(1		)	—			6			(1		)
	Other derivative contracts (f)	—				(1		)		—				—				(1		)		—				(1		)	—			—			(1		)
	Total derivative liabilities	(309		)		(415		)		(212		)		698				(238		)		(532		)		(315		)	(173		)	869			(151		)
	Total	$	(309	)		$	(415	)		$	(212	)		$	698			$	(238	)		$	(532	)		$	(315	)	$	(173	)	$	869		$	(151	)
	Net Assets (liabilities) at the end of the period	$	878			$	507			$	(36	)		$	(9	)		$	1,340			$	789			$	490		$	(13	)	$	—		$	1,266
	Assets:
	Current	$	277			$	400			$	139			$	(592	)		$	224			$	493			$	372		$	120		$	(754	)	$	231
	Noncurrent (e)	910				522				37				(115		)		1,354				828				433			40			(115		)	1,186
	Total Assets	$	1,187			$	922			$	176			$	(707	)		$	1,578			$	1,321			$	805		$	160		$	(869	)	$	1,417
	Liabilities:
	Current	$	(268	)		$	(328	)		$	(177	)		$	578			$	(195	)		$	(466	)		$	(269	)	$	(144	)	$	754		$	(125	)
	Noncurrent	(41		)		(87		)		(35		)		120				(43		)		(66		)		(46		)	(29		)	115			(26		)
	Total Liabilities	$	(309	)		$	(415	)		$	(212	)		$	698			$	(238	)		$	(532	)		$	(315	)	$	(173	)	$	869		$	(151	)
	Net Assets (liabilities) at the end of the period	$	878			$	507			$	(36	)		$	(9	)		$	1,340			$	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 December 31, 2013, available-for-sale securities of $125 million included $109 million and $16 million of cash equivalents included in Restricted cash and Other investments on the Consolidated Statements of Financial Position, respectively. 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 on the Consolidated Statements of Financial Position, respectively.
	(c)	Excludes cash surrender value of life insurance investments.
	(d)	Available-for-sale equity securities of $7 million at December 31, 2013 and $5 million at December 31, 2012 are included in Other investments on the Consolidated Statements of Financial Position.
	(e)	Includes $136 million and $110 million of Other investments that are included in the Consolidated Statements of Financial Position in Other investments at December 31, 2013 and 2012, respectively.
	(f)	Includes Interest rate contracts and Foreign currency exchange contracts.
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 years ended December 31, 2013 and 2012:
		Year Ended December 31, 2013																Year Ended December 31, 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				—				—				1				1				—				—			1
	Total gains (losses):
	Included in earnings	(32		)		75				—				43				(41		)		101				—			60
	Recorded in regulatory assets/liabilities	—				—				5				5				—				—				15			15
	Purchases, issuances and settlements:
	Purchases	(8		)		1				—				(7		)		—				2				—			2
	Issuances	—				(1		)		—				(1		)		—				—				—			—
	Settlements	25				(85		)		(4		)		(64		)		(4		)		(112		)		(19		)	(135		)
	Net Assets (Liabilities) as of December 31	$	(52	)		$	13			$	3			$	(36	)		$	(38	)		$	23			$	2		$	(13	)
	The amount of total gains (losses) included in net income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2013 and 2012 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations	$	(49	)		$	48			$	—			$	(1	)		$	(33	)		$	91			$	—		$	58
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 years ended December 31, 2013 and 2012:
		Year Ended December 31, 2013											Year Ended December 31, 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				—				—			N/A				—
	Transfers into Level 3 from	—			1				N/A				—			1				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 December 31, 2013 and 2012:
			31-Dec-13
	Commodity Contracts		Derivative Assets				Derivative Liabilities				Valuation Techniques		Unobservable Input		Range								Weighted Average
			(In millions)
	Natural Gas		$	34			$	(86	)		Discounted Cash Flow		Forward basis price (per MMBtu)		$	(0.88	)	—	$	5.07	/MMBtu		$	(0.16	)/MMBtu
	Electricity		$	139			$	(126	)		Discounted Cash Flow		Forward basis price (per MWh)		$	(7	)	—	$	15	/MWh		$	3	/MWh
			31-Dec-12
	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 December 31, 2013 and 2012:
		31-Dec-13																31-Dec-12
		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	$	41			$	—			$	—			$	41			$	39			$	—			$	—		$	39
	Dividends payable	$	116			$	116			$	—			$	—			$	107			$	107			$	—		$	—
	Short-term borrowings	$	131			$	—			$	131			$	—			$	240			$	—			$	240		$	—
	Long-term debt	$	8,094			$	425			$	7,551			$	499			$	7,813			$	507			$	7,453		$	933
Fair Value of Nuclear Decommissioning Trust Fund Assets Text Block [Table]	'
	The following table summarizes the fair value of the nuclear decommissioning trust fund assets:
		December 31,				December 31,
		2013				2012
		(In millions)
	Fermi 2	$	1,172			$	1,021
	Fermi 1	3				3
	Low level radioactive waste	16				13
	Total	$	1,191			$	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:
		Year Ended December 31
		2013				2012				2011
		(In millions)
	Realized gains	$	83			$	37			$	46
	Realized losses	$	(41	)		$	(31	)		$	(38	)
	Proceeds from sales of securities	$	1,118			$	759			$	833
Fair Value and Unrealized Gains for Nuclear Decommissioning Trust Fund Table [Table Text Block]	'
	The following table sets forth the fair value and unrealized gains for the nuclear decommissioning trust funds:
		31-Dec-13								31-Dec-12
		Fair				Unrealized				Fair				Unrealized
		Value				Gains				Value				Gains
		(In millions)
	Equity securities	$	730			$	201			$	631			$	122
	Debt securities	442				12				399				27
	Cash and cash equivalents	19				—				7				—
		$	1,191			$	213			$	1,037			$	149

Financial_and_Other_Derivative1

Financial and Other Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 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 December 31, 2013 and 2012:
		31-Dec-13								31-Dec-12
		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:
	Foreign currency exchange contracts	$	—			$	(1	)		$	—		$	—
	Commodity Contracts:
	Natural Gas	396				(503		)		645			(661		)
	Electricity	400				(398		)		360			(351		)
	Other	37				(34		)		11			(7		)
	Total derivatives not designated as hedging instruments:	$	833			$	(936	)		$	1,016		$	(1,019	)
	Total derivatives:
	Current	$	691			$	(773	)		$	862		$	(879	)
	Noncurrent	142				(163		)		154			(141		)
	Total derivatives	$	833			$	(936	)		$	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 December 31, 2013 and 2012:
		31-Dec-13											31-Dec-12
		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	$	396			$	(382	)		$	14		$	645		$	(605	)	$	40
	Electricity	400				(291		)		109			360			(258		)	102
	Other	37				(34		)		3			11			(6		)	5
	Total derivative assets	$	833			$	(707	)		$	126		$	1,016		$	(869	)	$	147
	Derivative liabilities:
	Commodity Contracts:
	Natural Gas	$	(503	)		$	395			$	(108	)	$	(661	)	$	605		$	(56	)
	Electricity	(398		)		269				(129		)	(351		)	258			(93		)
	Other	(34		)		34				—			(7		)	6			(1		)
	Other derivative liabilities	(1		)		—				(1		)	(1		)	—			(1		)
	Total derivative liabilities	$	(936	)		$	698			$	(238	)	$	(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 December 31, 2013 and 2012:
		31-Dec-13														31-Dec-12
		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	$	691			$	142			$	(773	)	$	(163	)	$	862		$	154		$	(879	)	$	(141	)
	Counterparty netting	(566		)		(115		)		566			115			(754		)	(115		)	754			115
	Collateral adjustment	(26		)		—				12			5			—			—			—			—
	Total derivatives as reported	$	99			$	27			$	(195	)	$	(43	)	$	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 years ended December 31, 2013 and 2012 is as follows:
			Location of Gain		Gain (Loss)
			(Loss) Recognized		Recognized in
			in Income on Derivatives		Income on
					Derivatives for
					Years Ended
					December 31
	Derivatives not Designated as Hedging Instruments				2013				2012
					(In millions)
	Foreign currency exchange contracts		Operating Revenue		$	(1	)		$	—
	Commodity Contracts:
	Natural Gas		Operating Revenue		(48		)		(29		)
	Natural Gas		Fuel, purchased power and gas		(44		)		25
	Electricity		Operating Revenue		82				64
	Other		Operating Revenue		—				5
	Total				$	(11	)		$	65
Volume of Commodity Contracts [Table Text Block]	'
	The following represents the cumulative gross volume of derivative contracts outstanding as of December 31, 2013:
	Commodity		Number of Units
	Natural Gas (MMBtu)		795,553,773
	Electricity (MWh)		55,658,483
	Foreign Currency Exchange ($ CAD)		65,074,206
	FTR (MWh)		10,485,618

Goodwill_Tables

Goodwill (Tables)	12 Months Ended
	Dec. 31, 2013
Goodwill and Intangible Assets Disclosure [Abstract]	'
Schedule of Goodwill [Table Text Block]	'
	The change in the carrying amount of goodwill for the fiscal years ended December 31, 2013 and 2012 is as follows:
		2013		2012
		(In millions)
	Balance as of January 1	$	2,018	$	2,020
	Goodwill attributable to sale of Unconventional Gas Production business	—		(2		)
	Balance at December 31	$	2,018	$	2,018

Acquisition_Tables

Acquisition (Tables)	12 Months Ended
	Dec. 31, 2013
Business Combinations [Abstract]	'
Schedule of Purchase Price Allocation [Table Text Block]	'
	The following table summarizes the fair value of the assets acquired and liabilities assumed as of the closing date:
		(In millions)
	Cash	$	22
	Accounts receivable	14
	Other current assets	8
	Property, plant and equipment	100
	Intangible assets	75
	Other noncurrent assets	9
	Current liabilities	(7		)
	Non-controlling interest	(1		)
	Total purchase price	$	220

Discontinued_Operations_Tables

Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2013
Discontinued Operations and Disposal Groups [Abstract]	'
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]	'
		2012			2011
		(In millions)
	Operating Revenues	$	55		$	39
	Operation and Maintenance	24			16
	Depreciation, Depletion and Amortization	23			18
	Taxes Other Than Income	4			3
	Asset (Gains) and Losses, Net	83			—
		134			37
	Operating Income (Loss)	(79		)	2
	Other (Income) and Deductions	6			6
	Loss Before Income Taxes	(85		)	(4		)
	Income Tax Expense (Benefit)	(29		)	(1		)
	Net Loss Attributable to DTE Energy Company	$	(56	)	$	(3	)

Property_Plant_and_Equipment_T

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Property, Plant and Equipment [Table Text Block]	'
	Summary of property by classification as of December 31:
		2013				2012
	Property, Plant and Equipment	(In millions)
	DTE Electric
	Generation	$	11,127			$	10,383
	Distribution	7,603				7,306
	Total DTE Electric	18,730				17,689
	DTE Gas
	Distribution	2,834				2,704
	Storage	431				426
	Other	836				852
	Total DTE Gas	4,101				3,982
	Non-utility and other	2,292				1,960
	Total	25,123				23,631
	Less Accumulated Depreciation, Depletion and Amortization
	DTE Electric
	Generation	(4,004		)		(3,880		)
	Distribution	(2,947		)		(2,837		)
	Total DTE Electric	(6,951		)		(6,717		)
	DTE Gas
	Distribution	(1,129		)		(1,057		)
	Storage	(138		)		(132		)
	Other	(338		)		(365		)
	Total DTE Gas	(1,605		)		(1,554		)
	Non-utility and other	(767		)		(676		)
	Total	(9,323		)		(8,947		)
	Net Property, Plant and Equipment	$	15,800			$	14,684
Useful Life [Table Text Block]	'
	The average estimated useful life for each major class of utility property, plant and equipment as of December 31, 2013 follows:
			Estimated Useful Lives in Years
	Utility		Generation		Distribution		Storage
	Electric		40		41		N/A
	Gas		N/A		50		53

Jointly_Owned_Utility_Plant_Ta

Jointly Owned Utility Plant (Tables)	12 Months Ended
	Dec. 31, 2013
Jointly Owned Utility Plant, Net Ownership Amount [Abstract]	'
Schedule of Jointly Owned Utility Plants [Table Text Block]	'
	Ownership information of the two utility plants as of December 31, 2013 was as follows:
		Belle River			Ludington
					Hydroelectric
					Pumped Storage
	In-service date	1984-1985			1973
	Total plant capacity	1,270		MW	1,872		MW
	Ownership interest	(a)			49		%
	Investment in property, plant and equipment (in millions)	$	1,702		$	354
	Accumulated depreciation (in millions)	$	969		$	170
	_______________________________________
	(a)	DTE Electric's ownership interest is 63% in Unit No. 1, 81% of the facilities applicable to Belle River used jointly by the Belle River and St. Clair Power Plants and 75% in common facilities used at Unit No. 2.

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Schedule of Change in Asset Retirement Obligation [Table Text Block]	'
	A reconciliation of the asset retirement obligations for 2013 follows:
		(In millions)
	Asset retirement obligations at December 31, 2012	$	1,719
	Accretion	106
	Liabilities incurred	5
	Liabilities settled	(13		)
	Revision in estimated cash flows	10
	Asset retirement obligations at December 31, 2013	$	1,827

Regulatory_Matters_Tables

Regulatory Matters (Tables)	12 Months Ended
	Dec. 31, 2013
Regulatory Assets and Liabilities Disclosure [Abstract]	'
Schedule of Regulatory Assets [Table Text Block]	'
	The following are balances and a brief description of the regulatory assets and liabilities at December 31:
		2013			2012
		(In millions)
	Assets
	Recoverable pension and other postretirement costs:
	Pension	$	1,660		$	2,420
	Other postretirement costs	—			426
	Asset retirement obligation	394			424
	Recoverable Michigan income taxes	286			304
	Recoverable income taxes related to securitized regulatory assets	126			226
	Cost to achieve Performance Excellence Process	75			96
	Other recoverable income taxes	71			76
	Unamortized loss on reacquired debt	63			63
	Deferred environmental costs	59			58
	Enterprise Business Systems costs	13			16
	Recoverable revenue decoupling	9			28
	Choice incentive mechanism	3			66
	Accrued PSCR/GCR revenue	—			87
	Recoverable restoration expense	—			49
	Other	104			78
		2,863			4,417
	Less amount included in current assets	(26		)	(182		)
		$	2,837		$	4,235
	Securitized regulatory assets	$	231		$	413
Schedule of Regulatory Liabilities [Table Text Block]	'
		2013			2012
		(In millions)
	Liabilities
	Asset removal costs	$	351		$	439
	Renewable energy	277			230
	Refundable revenue decoupling/deferred gain	127			127
	Negative pension offset	84			105
	Over recovery of Securitization	72			54
	Refundable other postretirement costs	72			—
	Accrued PSCR/GCR	65			16
	Refundable income taxes	45			56
	Energy optimization	31			34
	Fermi 2 refueling outage	26			12
	Refundable uncollectible expense	12			37
	Other	2			10
		$	1,164		$	1,120
	Less amount included current liabilities	(302		)	(89		)
		$	862		$	1,031

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2013
Income Tax Disclosure [Abstract]	'
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	'
	Total income tax expense varied from the statutory federal income tax rate for the following reasons:
		2013			2012			2011
		(In millions)
	Income before income taxes	$	922		$	960		$	991
	Income tax expense at 35% statutory rate	$	323		$	336		$	347
	Production tax credits	(68		)	(49		)	(6		)
	Investment tax credits	(6		)	(6		)	(6		)
	Depreciation	(4		)	(4		)	(4		)
	AFUDC - Equity	(5		)	(4		)	(1		)
	Employee Stock Ownership Plan dividends	(4		)	(4		)	(4		)
	Domestic production activities deduction	(14		)	(14		)	(7		)
	State and local income taxes, net of federal benefit	37			37			37
	Enactment of Michigan Corporate Income Tax, net of federal expense	—			—			(87		)
	Other, net	(5		)	(6		)	(1		)
	Income tax expense	$	254		$	286		$	268
	Effective income tax rate	27.5		%	29.8		%	27		%
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]	'
	Components of income tax expense were as follows:
		2013			2012			2011
		(In millions)
	Current income tax expense (benefit)
	Federal	$	74		$	190		$	27
	State and other income tax	16			49			21
	Total current income taxes	90			239			48
	Deferred income tax expense (benefit)
	Federal	122			39			318
	State and other income tax	42			8			(98		)
	Total deferred income taxes	164			47			220
	Total income taxes from continuing operations	254			286			268
	Discontinued operations	—			(29		)	(1		)
	Total	$	254		$	257		$	267
Schedule of Deferred Tax Assets and Liabilities [Table Text Block]	'
	Deferred tax assets (liabilities) were comprised of the following at December 31:
		2013			2012
		(In millions)
	Property, plant and equipment	$	(3,372	)	$	(3,389	)
	Securitized regulatory assets	(127		)	(256		)
	Alternative minimum tax credit carry-forwards	266			254
	Merger basis differences	18			42
	Pension and benefits	(30		)	(33		)
	Other comprehensive loss	—			101
	Derivative assets and liabilities	—			66
	State net operating loss and credit carry-forwards	43			37
	Other	(110		)	41
		(3,312		)	(3,137		)
	Less valuation allowance	(37		)	(33		)
		$	(3,349	)	$	(3,170	)
	Current deferred income tax assets (liabilities)	$	(28	)	$	21
	Long-term deferred income tax liabilities	(3,321		)	(3,191		)
		$	(3,349	)	$	(3,170	)
	Deferred income tax assets	$	1,808		$	1,038
	Deferred income tax liabilities	(5,157		)	(4,208		)
		$	(3,349	)	$	(3,170	)
Schedule of Unrecognized Tax Benefits Roll Forward [Table Text Block]	'
	A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows:
		2013			2012			2011
		(In millions)
	Balance at January 1	$	11		$	48		$	28
	Additions for tax positions of prior years	—			—			27
	Reductions for tax positions of prior years	—			(2		)	(4		)
	Additions for tax positions of current year	—			1			1
	Settlements	—			(30		)	(3		)
	Lapse of statute of limitations	(1		)	(6		)	(1		)
	Balance at December 31	$	10		$	11		$	48

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 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 as of December 31:
		2013		2012		2011
		(In millions, expect per share amounts)
	Basic Earnings per Share
	Net income attributable to DTE Energy Company	$	661	$	610	$	711
	Average number of common shares outstanding	175		171		169
	Weighted average net restricted shares outstanding	1		1		1
	Dividends declared — common shares	$	453	$	413	$	392
	Dividends declared — net restricted shares	1		1		1
	Total distributed earnings	$	454	$	414	$	393
	Net income less distributed earnings	$	207	$	196	$	318
	Distributed (dividends per common share)	$	2.59	$	2.42	$	2.32
	Undistributed	1.17		1.14		1.87
	Total Basic Earnings per Common Share	$	3.76	$	3.56	$	4.19
	Diluted Earnings per Share
	Net income attributable to DTE Energy Company	$	661	$	610	$	711
	Average number of common shares outstanding	175		171		169
	Average incremental shares from assumed exercise of options	—		1		1
	Common shares for dilutive calculation	175		172		170
	Weighted average net restricted shares outstanding	1		1		1
	Dividends declared — common shares	$	453	$	413	$	392
	Dividends declared — net restricted shares	1		1		1
	Total distributed earnings	$	454	$	414	$	393
	Net income less distributed earnings	$	207	$	196	$	318
	Distributed (dividends per common share)	$	2.59	$	2.42	$	2.32
	Undistributed	1.17		1.13		1.86
	Total Diluted Earnings per Common Share	$	3.76	$	3.55	$	4.18

LongTerm_Debt_Tables

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2013
Long-term Debt, Unclassified [Abstract]	'
Schedule of Long-term Debt Instruments [Table Text Block]	'
	The Company’s long-term debt outstanding and weighted average interest rates (a) of debt outstanding at December 31 were:
		2013				2012
		(In millions)
	Mortgage bonds, notes, and other
	DTE Energy Debt, Unsecured
	6.1% due 2014 to 2033	$	1,297			$	1,298
	DTE Electric Taxable Debt, Principally Secured
	4.7% due 2014 to 2043	4,286				3,777
	DTE Electric Tax-Exempt Revenue Bonds (b)
	5.1% due 2014 to 2036	558				707
	DTE Gas Taxable Debt, Principally Secured
	5.6% due 2014 to 2042	1,029				919
	Other Long-Term Debt, Including Non-Recourse Debt	142				153
		7,312				6,854
	Less amount due within one year	(694		)		(634		)
		$	6,618			$	6,220
	Securitization bonds
	6.6% due 2015	$	302			$	479
	Less amount due within one year	(197		)		(177		)
		$	105			$	302
	Junior Subordinated Debentures
	6.5% due 2061	$	280			$	280
	5.25% due 2062	200				200
		$	480			$	480
	_______________________________________
	(a)	Weighted average interest rates as of December 31, 2013 are shown below the description of each category of debt.
	(b)	DTE Electric Tax-Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds.
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	%	2043		$	375
	DTE Electric		August		Mortgage Bonds (a)		3.65	%	2024		400
	DTE Energy		November		Senior Notes (a)		3.85	%	2023		300
	DTE Gas		December		Mortgage Bonds (a)		3.64	%	2023		50
	DTE Gas		December		Mortgage Bonds (a)		3.74	%	2025		70
	DTE Gas		December		Mortgage Bonds (a)		3.94	%	2028		50
											$	1,245
	_______________________________________
	(a)	Proceeds were used for the redemption of long-term debt, repayment of short-term borrowings and 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)		5.3	%	2030		51
	DTE Electric		April		Other Long-Term Debt		Various		2013		13
	DTE Gas		April		Senior Notes		5.26	%	2013		60
	DTE Energy		June		Senior Notes		Variable		2013		300
	DTE Electric		September		Securitization Bonds		6.62	%	2013		89
	DTE Electric		September		Senior Notes		6.4	%	2013		250
	DTE Electric		December		Tax Exempt Revenue Bonds (a)		5.5	%	2030		49
	DTE Electric		December		Tax Exempt Revenue Bonds (a)		6.75	%	2038		50
	DTE Energy		Various		Other Long-Term Debt		Various		2013		11
											$	961
	_______________________________________
	(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.
Schedule of Maturities of Long-term Debt [Table Text Block]	'
	The following table shows the scheduled debt maturities:
		2014				2015			2016				2017		2018		2019 and		Total
																	Thereafter
		(In millions)
	Amount to mature	$	891			$	476		$	465			$	9	$	407	$	5,846	$	8,094

Preferred_and_Preferenced_Secu1

Preferred and Preferenced Securities (Tables)	12 Months Ended
	Dec. 31, 2013
Preferred Stock, Number of Shares, Par Value and Other Disclosures [Abstract]	'
Preferred and Preference Securities [Table Text Block]	'
	As of December 31, 2013, the amount of authorized and unissued stock is as follows:
	Company	Type of Stock	Par Value		Shares Authorized
	DTE Energy	Preferred	$	—	5,000,000
	DTE Electric	Preferred	$	100	6,747,484
	DTE Electric	Preference	$	1	30,000,000
	DTE Gas	Preferred	$	1	7,000,000
	DTE Gas	Preference	$	1	4,000,000

ShortTerm_Credit_Arrangements_1

Short-Term Credit Arrangements and Borrowings (Tables)	12 Months Ended
	Dec. 31, 2013
Short-term Debt [Abstract]	'
Schedule of Line of Credit Facilities [Table Text Block]	'
	The availability under the facilities in place at December 31, 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
		1,375		300		300		1,975
	Amounts outstanding at December 31, 2013:
	Commercial paper issuances	35		—		96		131
	Letters of credit	244		—		—		244
		279		—		96		375
	Net availability at December 31, 2013	$	1,096	$	300	$	204	$	1,600

Capital_and_Operating_Leases_T

Capital and Operating Leases (Tables)	12 Months Ended
	Dec. 31, 2013
Capital and Operating Leases [Abstract]	'
Capital and Operating Leases [Table Text Block]	'
	Future minimum lease payments under non-cancelable leases at December 31, 2013 were:
		Capital			Operating
		Leases			Leases
		(In millions)
	2014	$	8		$	35
	2015	8			31
	2016	3			27
	2017	—			25
	2018	—			20
	Thereafter	—			92
	Total minimum lease payments	$	19		$	230
	Less imputed interest	1
	Present value of net minimum lease payments	18
	Less current portion	7
	Non-current portion	$	11
Schedule of Capital Lease of Lessor [Table Text Block]	'
	The components of the net investment in the capital leases at December 31, 2013, were as follows:
		(In millions)
	2014	$	12
	2015	12
	2016	12
	2017	12
	2018	12
	Thereafter	19
	Total minimum future lease receipts	79
	Residual value of leased pipeline	40
	Less unearned income	(40		)
	Net investment in capital lease	79
	Less current portion	(5		)
		$	74

Commitments_and_Contingencies_1

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Long-term Purchase Commitment [Table Text Block]	'
	The Company estimates that these commitments will be approximately $8.6 billion from 2014 through 2051 as detailed in the following table:
		(In millions)
	2014	$	2,617
	2015	1,195
	2016	643
	2017	345
	2018	311
	2019 — 2051	3,487
		$	8,598

Retirement_Benefits_and_Truste1

Retirement Benefits and Trusteed Assets (Tables)	12 Months Ended
	Dec. 31, 2013
Pension Plan, Defined Benefit [Member]	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'
Schedule of Net Benefit Costs [Table Text Block]	'
	Net pension cost includes the following components:
		2013				2012				2011
		(In millions)
	Service cost	$	94			$	82			$	69
	Interest cost	192				204				202
	Expected return on plan assets	(266		)		(244		)		(246		)
	Amortization of:
	Net loss	208				176				142
	Prior service cost	—				—				3
	Special termination benefits	—				2				2
	Net pension cost	$	228			$	220			$	172
Schedule of Defined Benefit Plan Amounts Recognized in Other Comprehensive Income (Loss) [Table Text Block]	'
		2013				2012
		(In millions)
	Other changes in plan assets and benefit obligations recognized in Regulatory assets and Other comprehensive income
	Net actuarial (gain) loss	$	(581	)		$	395
	Amortization of net actuarial loss	(208		)		(178		)
	Total recognized Regulatory assets and Other comprehensive income	$	(789	)		$	217
	Total recognized in net periodic pension cost, Regulatory assets and Other comprehensive income	$	(561	)		$	437
	Estimated amounts to be amortized from Regulatory assets and Accumulated other comprehensive income into net periodic benefit cost during next fiscal year
	Net actuarial loss	$	151			$	202
Schedule of Defined Benefit Plans Disclosures [Table Text Block]	'
	The following table reconciles the obligations, assets and funded status of the plans as well as the amounts recognized as prepaid pension cost or pension liability in the Consolidated Statements of Financial Position at December 31:
		2013				2012
		(In millions)
	Accumulated benefit obligation, end of year	$	4,068			$	4,349
	Change in projected benefit obligation
	Projected benefit obligation, beginning of year	$	4,729			$	4,195
	Service cost	94				82
	Interest cost	192				204
	Plan amendments	(3		)		—
	Actuarial (gain) loss	(400		)		474
	Special termination benefits	—				2
	Benefits paid	(232		)		(228		)
	Projected benefit obligation, end of year	$	4,380			$	4,729
	Change in plan assets
	Plan assets at fair value, beginning of year	$	3,223			$	2,886
	Actual return on plan assets	445				325
	Company contributions	284				240
	Benefits paid	(232		)		(228		)
	Plan assets at fair value, end of year	$	3,720			$	3,223
	Funded status of the plans	$	(660	)		$	(1,506	)
	Amount recorded as:
	Current liabilities	$	(7	)		$	(8	)
	Noncurrent liabilities	(653		)		(1,498		)
		$	(660	)		$	(1,506	)
	Amounts recognized in Accumulated other comprehensive loss, pre-tax
	Net actuarial loss	$	174			$	205
	Prior service (credit)	(1		)		(2		)
		$	173			$	203
	Amounts recognized in Regulatory assets (see Note 11)
	Net actuarial loss	$	1,654			$	2,413
	Prior service cost	6				7
		$	1,660			$	2,420
Schedule of Expected Benefit Payments [Table Text Block]	'
	At December 31, 2013, the benefits related to the Company’s qualified and nonqualified pension plans expected to be paid in each of the next five years and in the aggregate for the five fiscal years thereafter are as follows:
		(In millions)
	2014	$	242
	2015	250
	2016	258
	2017	268
	2018	280
	2019-2023	1,529
		$	2,827
Schedule of Assumptions Used [Table Text Block]	'
	Assumptions used in determining the projected benefit obligation and net pension costs are listed below:
		2013			2012			2011
	Projected benefit obligation
	Discount rate	4.95	%		4.15	%		5	%
	Rate of compensation increase	4.2	%		4.2	%		4.2	%
	Net pension costs
	Discount rate	4.15	%		5	%		5.5	%
	Rate of compensation increase	4.2	%		4.2	%		4	%
	Expected long-term rate of return on plan assets	8.25	%		8.25	%		8.5	%
Schedule of Allocation of Plan Assets [Table Text Block]	'
	Target allocations for pension plan assets as of December 31, 2013 are listed below:
	U.S. Large Cap Equity Securities	22	%
	U.S. Small Cap and Mid Cap Equity Securities	5
	Non U.S. Equity Securities	20
	Fixed Income Securities	25
	Hedge Funds and Similar Investments	20
	Private Equity and Other	8
		100	%
Pension Plans Fair Value Hierachy Level [Table Text Block]	'
	Fair Value Measurements for pension plan assets at December 31, 2013 and 2012 (a):
		31-Dec-13														31-Dec-12
		Level 1				Level 2				Level 3			Total			Level 1			Level 2			Level 3		Total
		(In millions)
	Asset Category:
	Short-term investments (b)	$	22			$	—			$	—		$	22		$	—		$	24		$	—	$	24
	Equity securities
	U.S. Large Cap (c)	896				—				—			896			688			44			—		732
	U.S. Small/Mid Cap (d)	221				—				—			221			153			5			—		158
	Non U.S. (e)	611				130				—			741			530			120			—		650
	Fixed income securities (f)	16				921				—			937			87			765			—		852
	Hedge Funds and Similar Investments (g)	268				70				395			733			209			80			339		628
	Private Equity and Other (h)	—				—				170			170			—			—			179		179
	Total	$	2,034			$	1,121			$	565		$	3,720		$	1,667		$	1,038		$	518	$	3,223
	_______________________________________
	(a)	See Note 3 — Fair Value for a description of levels within the fair value hierarchy.
	(b)	This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category are obtained from quoted prices in actively traded markets or valuations from brokers or pricing services.
	(c)	This category comprises both actively and not actively managed portfolios that track the S&P 500 low cost equity index funds. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
	(d)	This category represents portfolios of small and medium capitalization domestic equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
	(e)	This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
	(f)	This category includes corporate bonds from diversified industries, U.S. Treasuries, and mortgage-backed securities. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. Non-exchange traded securities and exchange-traded securities held in commingled funds are classified as Level 2 assets.
	(g)	This category utilizes a diversified group of strategies that attempt to capture financial market inefficiencies and includes publicly traded debt and equity, publicly traded mutual funds, commingled and limited partnership funds and non-exchange traded securities. Pricing for Level 1 and Level 2 assets in this category is obtained from quoted prices in actively traded markets and quoted prices from broker or pricing services. Non-exchange traded securities held in commingled funds are classified as Level 2 assets. Valuations for some Level 3 assets in this category may be based on limited observable inputs as there may be little, if any, publicly available pricing.
	(h)	This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in timber and private mezzanine debt. Pricing for investments in this category is based on limited observable inputs as there is little, if any, publicly available pricing. Valuations for assets in this category may be based on discounted cash flow analyses, relevant publicly-traded comparables and comparable transactions.
Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets [Table Text Block]	'
	Fair Value Measurements Using Significant Unobservable Inputs (Level 3):
		Year Ended December 31, 2013											Year Ended December 31, 2012
		Hedge Funds				Private Equity				Total			Hedge Funds			Private Equity			Total
		and Similar				and Other							and Similar			and Other
		Investments											Investments
		(In millions)
	Beginning Balance at January 1	$	339			$	179			$	518		$	296		$	168		$	464
	Total realized/unrealized gains (losses):
	Realized gains (losses)	—				18				18			18			(6		)	12
	Unrealized gains (losses)	40				(14		)		26			(5		)	12			7
	Purchases, sales and settlements:
	Purchases	16				15				31			250			33			283
	Sales	—				(28		)		(28		)	(220		)	(28		)	(248		)
	Ending Balance at December 31	$	395			$	170			$	565		$	339		$	179		$	518
	The amount of total gains for the period attributable to the change in unrealized gains or losses related to assets still held at the end of the period	$	38			$	3			$	41		$	16		$	6		$	22
Other Postretirement Benefit Plan, Defined Benefit [Member]	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'
Schedule of Net Benefit Costs [Table Text Block]	'
	Net other postretirement cost includes the following components:
		2013				2012				2011
		(In millions)
	Service cost	$	47			$	68			$	64
	Interest cost	88				120				121
	Expected return on plan assets	(110		)		(92		)		(94		)
	Amortization of:
	Net loss	64				80				55
	Prior service credit	(131		)		(27		)		(26		)
	Net transition asset	—				2				2
	Net other postretirement cost (benefit)	$	(42	)		$	151			$	122
Schedule of Defined Benefit Plan Amounts Recognized in Other Comprehensive Income (Loss) [Table Text Block]	'
		2013				2012
		(In millions)
	Other changes in plan assets and APBO recognized in Regulatory assets (liabilities) and Other comprehensive income
	Net actuarial gain	$	(353	)		$	(34	)
	Amortization of net actuarial loss	(64		)		(80		)
	Prior service credit	(218		)		(264		)
	Amortization of prior service credit	131				27
	Amortization of transition asset	—				(2		)
	Total recognized in Regulatory assets (liabilities) and Other comprehensive income	$	(504	)		$	(353	)
	Total recognized in net periodic benefit cost, Regulatory assets (liabilities) and Other comprehensive income	$	(546	)		$	(202	)
	Estimated amounts to be amortized from Regulatory assets (liabilities) and Accumulated other comprehensive income into net periodic benefit cost during next fiscal year
	Net actuarial loss	$	21			$	69
	Prior service credit	$	(144	)		$	(91	)
Schedule of Defined Benefit Plans Disclosures [Table Text Block]	'
	The following table reconciles the obligations, assets and funded status of the plans including amounts recorded as Accrued postretirement liability in the Consolidated Statements of Financial Position at December 31:
		2013				2012
		(In millions)
	Change in accumulated postretirement benefit obligation
	Accumulated postretirement benefit obligation, beginning of year	$	2,315			$	2,470
	Service cost	47				68
	Interest cost	88				120
	Plan amendments	(218		)		(264		)
	Actuarial (gain) loss	(267		)		5
	Medicare Part D subsidy	1				6
	Benefits paid	(88		)		(90		)
	Accumulated postretirement benefit obligation, end of year	$	1,878			$	2,315
	Change in plan assets
	Plan assets at fair value, beginning of year	$	1,153			$	985
	Actual return on plan assets	196				131
	Company contributions	264				140
	Benefits paid	(86		)		(103		)
	Plan assets at fair value, end of year	$	1,527			$	1,153
	Funded status, end of year	$	(351	)		$	(1,162	)
	Amount recorded as:
	Current liabilities	$	(1	)		$	(2	)
	Noncurrent liabilities	(350		)		(1,160		)
		$	(351	)		$	(1,162	)
	Amounts recognized in Accumulated other comprehensive loss, pre-tax
	Net actuarial loss	$	29			$	40
	Prior service credit	(10		)		(14		)
	Net transition asset	—				(1		)
		$	19			$	25
	Amounts recognized in Regulatory assets (liabilities) (See Note 11)
	Net actuarial loss	$	321			$	727
	Prior service credit	(393		)		(302		)
	Net transition obligation	—				1
		$	(72	)		$	426
Schedule of Expected Benefit Payments [Table Text Block]	'
	At December 31, 2013, the benefits expected to be paid, including prescription drug benefits, in each of the next five years and in the aggregate for the five fiscal years thereafter are as follows:
		(In millions)
	2014	$	103
	2015	110
	2016	115
	2017	123
	2018	130
	2019 — 2023	724
		$	1,305
Schedule of Assumptions Used [Table Text Block]	'
	Assumptions used in determining the accumulated postretirement benefit obligation and net other postretirement benefit costs are listed below:
		2013			2012			2011
	Accumulated postretirement benefit obligation
	Discount rate	4.95	%		4.15	%		5	%
	Health care trend rate pre- and post- 65	7.5	/ 6.50%		7	%		7	%
	Ultimate health care trend rate	4.5	%		5	%		5	%
	Year in which ultimate reached pre- and post- 65	2025 / 2024			2021			2020
	Other postretirement benefit costs
	Discount rate (prior to interim remeasurement)	4.15	%		5	%		5.5	%
	Discount rate (post interim remeasurement)	4.3	%		N/A			N/A
	Expected long-term rate of return on plan assets	8.25	%		8.25	%		8.75	%
	Health care trend rate pre- and post- 65	7	%		7	%		7	%
	Ultimate health care trend rate	5	%		5	%		5	%
	Year in which ultimate reached	2021			2020			2019
Schedule of Allocation of Plan Assets [Table Text Block]	'
	Target allocations for other postretirement benefit plan assets as of December 31, 2013 are listed below:
	U.S. Large Cap Equity Securities	17	%
	U.S. Small Cap and Mid Cap Equity Securities	4
	Non U.S. Equity Securities	20
	Fixed Income Securities	25
	Hedge Funds and Similar Investments	20
	Private Equity and Other	14
		100	%
Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets [Table Text Block]	'
	Fair Value Measurements Using Significant Unobservable Inputs (Level 3):
		Year Ended December 31, 2013											Year Ended December 31, 2012
		Hedge Funds				Private Equity				Total			Hedge Funds			Private Equity			Total
		and Similar				and Other							and Similar			and Other
		Investments											Investments
		(In millions)
	Beginning Balance at January 1	$	119			$	86			$	205		$	95		$	60		$	155
	Total realized/unrealized gains (losses):
	Realized gains (losses)	—				2				2			6			(11		)	(5		)
	Unrealized gains	14				7				21			—			14			14
	Purchases, sales and settlements:
	Purchases	26				15				41			86			36			122
	Sales	—				(9		)		(9		)	(68		)	(13		)	(81		)
	Ending Balance at December 31	$	159			$	101			$	260		$	119		$	86		$	205
	The amount of total gains for the period attributable to the change in unrealized gains or losses related to assets still held at the end of the period	$	14			$	9			$	23		$	6		$	2		$	8
Other Postretirement Benefit Plans Hierachy Level [Table Text Block]	'
	Fair Value Measurements for other postretirement benefit plan assets at December 31, 2013 and 2012 (a):
		31-Dec-13														31-Dec-12
		Level 1				Level 2				Level 3			Total			Level 1			Level 2			Level 3		Total
	Asset Category:	(In millions)
	Short-term investments (b)	$	5			$	—			$	—		$	5		$	1		$	2		$	—	$	3
	Equity securities:
	U.S. Large Cap (c)	302				—				—			302			189			3			—		192
	U.S. Small/Mid Cap (d)	147				—				—			147			105			—			—		105
	Non U.S. (e)	282				9				—			291			230			7			—		237
	Fixed income securities (f)	17				350				—			367			38			247			—		285
	Hedge Funds and Similar Investments (g)	130				25				159			314			102			24			119		245
	Private Equity and Other (h)	—				—				101			101			—			—			86		86
	Total	$	883			$	384			$	260		$	1,527		$	665		$	283		$	205	$	1,153
	_______________________________________
	(a)	See Note 3 — Fair Value for a description of levels within the fair value hierarchy.
	(b)	This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category are obtained from quoted prices in actively traded markets or valuations from brokers or pricing services.
	(c)	This category comprises both actively and not actively managed portfolios that track the S&P 500 low cost equity index funds. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
	(d)	This category represents portfolios of small and medium capitalization domestic equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
	(e)	This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
	(f)	This category includes corporate bonds from diversified industries, U.S. Treasuries, bank loans and mortgage backed securities. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. Non-exchange traded securities and exchange-traded securities held in commingled funds are classified as Level 2 assets.
	(g)	This category utilizes a diversified group of strategies that attempt to capture financial market inefficiencies and includes publicly traded debt and equity, publicly traded mutual funds, commingled and limited partnership funds and non-exchange traded securities. Pricing for Level 1 and Level 2 assets in this category is obtained from quoted prices in actively traded markets and quoted prices from broker or pricing services. Non-exchange traded securities held in commingled funds are classified as Level 2 assets. Valuations for some Level 3 assets in this category may be based on limited observable inputs as there may be little, if any, publicly available pricing.
	(h)	This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in timber and private mezzanine debt. Pricing for investments in this category is based on limited observable inputs as there is little, if any, publicly available pricing. Valuations for assets in this category may be based on discounted cash flow analyses, relevant publicly-traded comparables and comparable transactions.

StockBased_Compensation_Tables

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2013
Share-based Compensation [Abstract]	'
Schedule of Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Table Text Block]	'
	Stock-based compensation for the reporting periods is as follows:
		2013				2012			2011
		(In millions)
	Stock-based compensation expense	$	99			$	83		$	66
	Tax benefit	38				33			25
	Stock-based compensation cost capitalized in property, plant and equipment	15				5			4
Schedule of Share-based Compensation, Stock Options, Activity [Table Text Block]	'
	Stock option activity was as follows:
		Number of			Weighted			Aggregate
		Options			Average			Intrinsic
					Exercise Price			Value (In millions)
	Options outstanding at December 31, 2012	1,192,670			$	41.86
	Granted	—			$	—
	Exercised	(458,603	)		$	40.71
	Forfeited or expired	(10,370	)		$	41.46
	Options outstanding and exercisable at December 31, 2013	723,697			$	42.6		$	18
Schedule of Share-based Compensation, Shares Authorized under Stock Option Plans, by Exercise Price Range [Table Text Block]	'
	The number, weighted average exercise price and weighted average remaining contractual life of options outstanding were as follows:
											Weighted Average		Weighted Average
								Number of Options			Exercise Price		Remaining Contractual Life (Years)
	Range of Exercise Prices
	$	27		—	$	38		67,257			$	28.3	5.15
	$	38.01		—	$	42		167,447			$	41.23	3.21
	$	42.01		—	$	45		351,893			$	44.02	4.16
	$	45.01		—	$	50		137,100			$	47.67	3.08
								723,697			$	42.6	3.83
Schedule of Share-based Compensation, Restricted Stock Units Award Activity [Table Text Block]	'
	Stock award activity for the years ended December 31 was:
		2013				2012			2011
	Fair value of awards vested (in millions)	$	8			$	9		$	13
	Restricted common shares awarded	127,785				167,320			381,840
	Weighted average market price of shares awarded	$	64.72			$	53.71		$	47.98
	Compensation cost charged against income (in millions)	$	23			$	12		$	12
Schedule of Share-based Compensation, Restricted Stock and Restricted Stock Units Activity [Table Text Block]	'
	The following table summarizes the Company’s stock awards activity for the period ended December 31, 2013:
		Restricted			Weighted Average
		Stock			Grant Date
					Fair Value
	Balance at December 31, 2012	597,648			$	48.33
	Grants	127,785			$	64.72
	Forfeitures	(7,155	)		$	54.61
	Vested and issued	(225,949	)		$	45.54
	Balance at December 31, 2013	492,329			$	53.76
Share Based Compensation Expense [Table Text Block]	'
	The Company recorded compensation expense for performance share awards as follows:
		2013				2012			2011
		(In millions)
	Compensation expense	$	77			$	71		$	53
	Cash settlements (a)	$	9			$	4		$	3
	Stock settlements (a)	$	56			$	41		$	25
Summary of Performance Share Activity [Table Text Block]	'
	The following table summarizes the Company’s performance share activity for the period ended December 31, 2013:
		Performance Shares
	Balance at December 31, 2012	1,634,364
	Grants	564,561
	Forfeitures	(41,512	)
	Payouts	(548,624	)
	Balance at December 31, 2013	1,608,789
Schedule of Unrecognized Compensation Cost, Nonvested Awards [Table Text Block]	'
		Unrecognized				Weighted Average
		Compensation				to be Recognized
		Cost
		(In millions)				(In years)
	Stock awards	$	10			0.93
	Performance shares	45				0.93
		$	55			0.93

Segment_Information_Tables

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2013
Segment Reporting [Abstract]	'
Inter segment billing for goods and services [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:
		2013			2012			2011
		(In millions)
	Electric	$	26		$	29		$	33
	Gas	4			4			2
	Gas Storage and Pipelines	3			6			8
	Power and Industrial Projects	816			801			238
	Energy Trading	43			43			70
	Corporate and Other	(24		)	(37		)	(50		)
	Discontinued Operations	—			2			—
		$	868		$	848		$	301
Schedule of Segment Reporting Information, by Segment [Table Text Block]	'
	Financial data of the business segments follows:
		Operating			Depreciation,			Interest			Interest			Income			Net Income (Loss)			Total			Goodwill		Capital
		Revenue			Depletion &			Income			Expense			Taxes			Attributable			Assets					Expenditures
					Amortization												to DTE
																	Energy
																	Company
		(In millions)
	2013
	Electric	$	5,199		$	902		$	(1	)	$	268		$	252		$	484		$	17,508		$	1,208	$	1,325
	Gas	1,474			95			(7		)	58			77			143			3,938			743		209
	Gas Storage and Pipelines	132			23			(7		)	18			45			70			824			24		245
	Power and Industrial Projects	1,950			72			(6		)	27			(45		)	66			1,067			26		93
	Energy Trading	1,771			1			—			8			(38		)	(58		)	623			17		3
	Corporate and Other	3			1			(51		)	120			(37		)	(44		)	2,945			—		1
	Reclassifications and Eliminations	(868		)	—			63			(63		)	—			—			(970		)	—		—
	Total	$	9,661		$	1,094		$	(9	)	$	436		$	254		$	661		$	25,935		$	2,018	$	1,876
		Operating			Depreciation,			Interest			Interest			Income			Net Income (Loss)			Total			Goodwill		Capital
		Revenue			Depletion &			Income			Expense			Taxes			Attributable			Assets					Expenditures
					Amortization												to DTE
																	Energy
																	Company
		(In millions)
	2012
	Electric	$	5,293		$	827		$	(1	)	$	272		$	280		$	483		$	17,755		$	1,208	$	1,230
	Gas	1,315			92			(7		)	59			50			115			4,059			745		221
	Gas Storage and Pipelines	96			8			(8		)	8			39			61			668			22		233
	Power and Industrial Projects	1,823			65			(7		)	37			(44		)	42			991			26		83
	Energy Trading	1,109			2			—			8			7			12			629			17		1
	Corporate and Other	3			1			(52		)	121			(46		)	(47		)	3,074			—		3
	Reclassifications and Eliminations	(848		)	—			65			(65		)	—			—			(837		)	—		—
	Total from Continuing Operations	$	8,791		$	995		$	(10	)	$	440		$	286		$	666		$	26,339		$	2,018	$	1,771
	Discontinued Operations (Note 7)																(56		)	—			—		49
	Total																$	610		$	26,339		$	2,018	$	1,820
		Operating			Depreciation,			Interest			Interest			Income			Net Income (Loss)			Total			Goodwill		Capital
		Revenue			Depletion &			Income			Expense			Taxes			Attributable			Assets					Expenditures
					Amortization												to DTE
																	Energy
																	Company
		(In millions)
	2011
	Electric	$	5,154		$	818		$	(1	)	$	289		$	265		$	434		$	17,567		$	1,208	$	1,203
	Gas	1,505			89			(7		)	64			60			110			4,065			745		179
	Gas Storage and Pipelines	91			6			(5		)	7			35			57			538			22		16
	Power and Industrial Projects	1,129			60			(8		)	32			11			38			789			26		56
	Energy Trading	1,276			3			—			9			34			52			612			17		1
	Corporate & Other	4			1			(47		)	145			(136		)	23			2,605			—		—
	Reclassifications and Eliminations	(301		)	—			58			(58		)	(1		)	—			(485		)	—		—
	Total from Continuing Operations	$	8,858		$	977		$	(10	)	$	488		$	268		$	714		$	25,691		$	2,018	$	1,455
	Discontinued Operations (Note 7)																(3		)	318			2		29
	Total																$	711		$	26,009		$	2,020	$	1,484

Supplementary_Quarterly_Financ1

Supplementary Quarterly Financial Information (Unaudited ) (Tables)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Schedule of Quarterly Financial Information [Table Text Block]	'
	Quarterly earnings per share may not equal full year totals, since quarterly computations are based on weighted average common shares outstanding during each quarter.
		First		Second			Third		Fourth			Year
		Quarter		Quarter			Quarter		Quarter
		(In millions, except per share amounts)
	2013
	Operating Revenues	$	2,516	$	2,225		$	2,387	$	2,533		$	9,661
	Operating Income	$	410	$	223		$	329	$	241		$	1,203
	Net Income Attributable to DTE Energy Company	$	234	$	105		$	198	$	124		$	661
	Basic Earnings per Share	$	1.35	$	0.6		$	1.13	$	0.7		$	3.76
	Diluted Earnings per Share	$	1.34	$	0.6		$	1.13	$	0.7		$	3.76
	2012
	Operating Revenues	$	2,239	$	2,013		$	2,190	$	2,349		$	8,791
	Operating Income	$	312	$	294		$	406	$	267		$	1,279
	Net Income Attributable to DTE Energy Company
	Continuing Operations	$	156	$	147		$	226	$	137		$	666
	Discontinued Operations	—		(1		)	1		(56		)	(56		)
	Net Income Attributable to DTE Energy Company	$	156	$	146		$	227	$	81		$	610
	Basic Earnings per Share
	Continuing Operations	$	0.91	$	0.87		$	1.31	$	0.79		$	3.89
	Discontinued Operations	—		(0.01		)	0.01		(0.32		)	(0.33		)
	Total	$	0.91	$	0.86		$	1.32	$	0.47		$	3.56
	Diluted Earnings per Share
	Continuing Operations	$	0.91	$	0.87		$	1.3	$	0.79		$	3.88
	Discontinued Operations	—		(0.01		)	0.01		(0.32		)	(0.33		)
	Total	$	0.91	$	0.86		$	1.31	$	0.47		$	3.55

Valuation_and_Qualifying_Accou1

Valuation and Qualifying Accounts (Tables)	12 Months Ended
	Dec. 31, 2013
Valuation and Qualifying Accounts [Abstract]	'
Summary of Valuation Allowance [Table Text Block]	'
	Valuation and Qualifying Accounts
		Year Ending December 31,
		2013			2012			2011
		(In millions)
	Allowance for Doubtful Accounts (shown as deduction from Accounts Receivable in the Consolidated Statements of Financial Position)
	Balance at Beginning of Period	$	62		$	162		$	196
	Additions:
	Charged to costs and expenses	94			79			94
	Charged to other accounts (a)	23			16			18
	Deductions (b)	(124		)	(195		)	(146		)
	Balance at End of Period	$	55		$	62		$	162

Organization_and_Basis_of_Pres2

Organization and Basis of Presentation (Details Textuals) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2012	Dec. 31, 2011
In Millions, unless otherwise specified	customers	Proceeds from sale of nuclear decommissioning trust funds [Member]	Proceeds from sale of nuclear decommissioning trust funds [Member]	Investment in Nuclear Decommissioning Trust Funds [Member]	Investment in Nuclear Decommissioning Trust Funds [Member]
Prior Period Reclassification Adjustment	'	$662	$753	($662)	($753)
Number of Electric Utility Customers	2,100,000	'	'	'	'
Number of Gas Utility Customers	1,200,000	'	'	'	'
Significant Potential Exposure to Loss Due to VIE Long-Term Purchase Contracts	$0	'	'	'	'

Organization_and_Basis_of_Pres3

Organization and Basis of Presentation (Consolidated Variable Interest Entities) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
In Millions, unless otherwise specified
Assets [Abstract]	'	'	'	'
Cash and cash equivalents	$52	$65	$68	$65
Restricted cash	123	122	'	'
Accounts receivable	1,542	1,336	'	'
Other current assets	209	215	'	'
Property, plant and equipment	15,800	14,684	'	'
Securitized regulatory assets	231	413	'	'
Other assets	198	197	'	'
Total Assets	25,935	26,339	26,009	'
Liabilities [Abstract]	'	'	'	'
Current portion long-term debt, including capital leases	898	817	'	'
Current regulatory liabilities	302	89	'	'
Other current liabilities	495	449	'	'
Mortgage bonds, notes and other	6,618	6,220	'	'
Securitization bonds	105	302	'	'
Capital lease obligations	11	12	'	'
Other long term liabilities	297	306	'	'
Variable Interest Entity Securitization [Member]	'	'	'	'
Assets [Abstract]	'	'	'	'
Cash and cash equivalents	0	0	'	'
Restricted cash	100	102	'	'
Accounts receivable	34	34	'	'
Inventories	0	0	'	'
Other current assets	0	0	'	'
Property, plant and equipment	0	0	'	'
Securitized regulatory assets	231	413	'	'
Other assets	4	7	'	'
Total Assets	369	556	'	'
Liabilities [Abstract]	'	'	'	'
Accounts payable and accrued current liabilities	7	11	'	'
Current portion long-term debt, including capital leases	196	177	'	'
Current regulatory liabilities	43	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	12	10	'	'
Restricted cash	8	7	'	'
Accounts receivable	16	7	'	'
Inventories	118	141	'	'
Other current assets	1	1	'	'
Property, plant and equipment	99	93	'	'
Securitized regulatory assets	0	0	'	'
Other assets	8	11	'	'
Total Assets	262	270	'	'
Liabilities [Abstract]	'	'	'	'
Accounts payable and accrued current liabilities	23	14	'	'
Current portion long-term debt, including capital leases	9	8	'	'
Current regulatory liabilities	0	0	'	'
Other current liabilities	4	4	'	'
Mortgage bonds, notes and other	21	25	'	'
Securitization bonds	0	0	'	'
Capital lease obligations	7	11	'	'
Other long term liabilities	2	2	'	'
Total Liabilities	66	64	'	'
Consolidated Variable Interest Entity [Member]	'	'	'	'
Assets [Abstract]	'	'	'	'
Cash and cash equivalents	12	10	'	'
Restricted cash	108	109	'	'
Accounts receivable	50	41	'	'
Inventories	118	141	'	'
Other current assets	1	1	'	'
Property, plant and equipment	99	93	'	'
Securitized regulatory assets	231	413	'	'
Other assets	12	18	'	'
Total Assets	631	826	'	'
Liabilities [Abstract]	'	'	'	'
Accounts payable and accrued current liabilities	30	25	'	'
Current portion long-term debt, including capital leases	205	185	'	'
Current regulatory liabilities	43	50	'	'
Other current liabilities	4	4	'	'
Mortgage bonds, notes and other	21	25	'	'
Securitization bonds	105	302	'	'
Capital lease obligations	7	11	'	'
Other long term liabilities	10	9	'	'
Total Liabilities	$425	$611	'	'

Organization_and_Basis_of_Pres4

Organization and Basis of Presentation (Non Consolidated Variable Interest Entities) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Variable Interest Entity, Nonconsolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]	'	'
Notes receivable	$102	$112
Variable Interest Entity, NonConsolidated [Member]	'	'
Variable Interest Entity, Nonconsolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]	'	'
Other investments	141	130
Notes receivable	$8	$6

Significant_Accounting_Policie3

Significant Accounting Policies (Accumulated Other Comprehensive Income (Loss)) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax	($158)	'	'
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	13	'	'
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	9	'	'
Other Comprehensive Income (Loss), Net of Tax	22	0	-9
Accumulated Other Comprehensive Income (Loss), Net of Tax	-136	-158	'
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax	-4	'	'
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	0	'	'
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	0	'	'
Other Comprehensive Income (Loss), Net of Tax	0	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax	-4	'	'
Accumulated Net Unrealized Investment Gain (Loss) [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax	-8	'	'
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	2	'	'
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	0	'	'
Other Comprehensive Income (Loss), Net of Tax	2	1	'
Accumulated Other Comprehensive Income (Loss), Net of Tax	-6	-8	'
Accumulated Defined Benefit Plans Adjustment [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax	-148	'	'
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	13	'	'
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	9	'	'
Other Comprehensive Income (Loss), Net of Tax	22	-2	-9
Accumulated Other Comprehensive Income (Loss), Net of Tax	-126	-148	'
Accumulated Translation Adjustment [Member]	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax	2	'	'
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax	-2	'	'
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax	0	'	'
Other Comprehensive Income (Loss), Net of Tax	-2	1	'
Accumulated Other Comprehensive Income (Loss), Net of Tax	$0	$2	'

Significant_Accounting_Policie4

Significant Accounting Policies (Intangible Assets) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Finite-Lived Intangible Assets [Line Items]	'	'
Intangible Assets, Gross	$179	$189
Less: Accumulated Amortization	45	34
Intangible Assets, Net	134	155
Less current intangible assets	12	20
Finite-Lived Intangible Assets, Net	122	135
Emission Allowances [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Intangible Assets, Gross	2	6
Renewable Energy Credits [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Intangible Assets, Gross	51	44
Contract Intangible Assets [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Intangible Assets, Gross	$126	$139

Significant_Accounting_Policie5

Significant Accounting Policies (Future Amortization Expense Intangible Assets) (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]	'
Finite-Lived Intangible Assets, Amortization Expense, Next Twelve Months	$13
Finite-Lived Intangible Assets, Amortization Expense, Year Two	12
Finite-Lived Intangible Assets, Amortization Expense, Year Three	11
Finite-Lived Intangible Assets, Amortization Expense, Year Four	8
Finite-Lived Intangible Assets, Amortization Expense, Year Five	$8

Significant_Accounting_Policie6

Significant Accounting Policies (Details Textuals) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Significant Accounting Policies [Line Items]	'	'	'
Other Nonoperating Income	$201,000,000	$173,000,000	$117,000,000
Receivables Due Date	'21 days	'	'
Threshold Period Past Due for Write-off of Trade Accounts Receivable	'150 days	'	'
Specific Review of Probable Future Collections Based on Receivable Balances in Excess of Pre Specified Days	'30 days	'	'
Unbilled Revenues included in Customer Accounts Receivable	1,542,000,000	1,336,000,000	'
Accrued Expense Related to Fermi 2 Refueling Outages	26,000,000	12,000,000	'
Period Expenses Related To Fermi 2 Refueling Outages Are Accrued	'18 months	'	'
Amortization of Intangible Assets	14,000,000	6,000,000	5,000,000
Excise Sales Tax Net Impact on Statement of Operations	0	'	'
Charitable Contributions to a Foundation	18,000,000	21,000,000	21,000,000
Minimum [Member]	'	'	'
Significant Accounting Policies [Line Items]	'	'	'
Notes Receivable Considered Delinquent Period	'60 days	'	'
Finite Lived Asset Useful Life	'1 year	'	'
Maximum [Member]	'	'	'
Significant Accounting Policies [Line Items]	'	'	'
Notes Receivable Considered Delinquent Period	'120 days	'	'
Finite Lived Asset Useful Life	'28 years	'	'
Unbilled Revenues [Member]	'	'	'
Significant Accounting Policies [Line Items]	'	'	'
Unbilled Revenues included in Customer Accounts Receivable	815,000,000	686,000,000	'
Public Utilities, Inventory, Natural Gas [Member]	'	'	'
Significant Accounting Policies [Line Items]	'	'	'
LIFO Inventory Amount	4,000,000	37,000,000	'
Excess of Replacement Costs over Stated LIFO Value	170,000,000	113,000,000	'
Power and Industrial Projects [Member]	'	'	'
Significant Accounting Policies [Line Items]	'	'	'
Other Nonoperating Income	$81,000,000	$63,000,000	$15,000,000

Fair_Value_Assets_and_Liabilit

Fair Value (Assets and Liabilities Recorded at Fair Value on a Recurring Basis) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Derivative liabilities [Abstract]	'	'
Derivative Liabilities, Current	($195)	($125)
Derivative Liabilities, Noncurrent	-43	-26
Fair Value, Measurements, Recurring [Member]	'	'
Assets [Abstract]	'	'
Cash and Cash Equivalents, Fair Value Disclosure	125	123
Nuclear decommissioning trusts	1,191	1,037
Other investments	136	110
Derivative assets [Abstract]	'	'
Derivative Assets	126	147
Assets, Fair Value Disclosure	1,578	1,417
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	-238	-151
Derivative Liabilities, Current	-195	-125
Derivative Liabilities, Noncurrent	-43	-26
Fair Value, Net Asset (Liability)	1,340	1,266
Fair Value, Measurements, Recurring [Member] | Current Asset [Member]	'	'
Derivative assets [Abstract]	'	'
Assets, Fair Value Disclosure	224	231
Fair Value, Measurements, Recurring [Member] | Non Current Asset [Member]	'	'
Derivative assets [Abstract]	'	'
Assets, Fair Value Disclosure	1,354	1,186
Fair Value, Measurements, Recurring [Member] | Natural Gas Commodity Contract [Member]	'	'
Derivative assets [Abstract]	'	'
Derivative Assets	14	40
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	-108	-56
Fair Value, Measurements, Recurring [Member] | Electricity Commodity Contract [Member]	'	'
Derivative assets [Abstract]	'	'
Derivative Assets	109	102
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	-129	-93
Fair Value, Measurements, Recurring [Member] | Other Commodity Contract [Member]	'	'
Derivative assets [Abstract]	'	'
Derivative Assets	3	5
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	0	-1
Fair Value, Measurements, Recurring [Member] | Other Contract [Member]	'	'
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	-1	-1
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]	'	'
Assets [Abstract]	'	'
Cash and Cash Equivalents, Fair Value Disclosure	10	0
Nuclear decommissioning trusts	779	694
Other investments	92	66
Derivative assets [Abstract]	'	'
Derivative Assets	306	561
Assets, Fair Value Disclosure	1,187	1,321
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	-309	-532
Derivative Liabilities, Current	-268	-466
Derivative Liabilities, Noncurrent	-41	-66
Fair Value, Net Asset (Liability)	878	789
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Current Asset [Member]	'	'
Derivative assets [Abstract]	'	'
Assets, Fair Value Disclosure	277	493
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Non Current Asset [Member]	'	'
Derivative assets [Abstract]	'	'
Assets, Fair Value Disclosure	910	828
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Natural Gas Commodity Contract [Member]	'	'
Derivative assets [Abstract]	'	'
Derivative Assets	273	555
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	-277	-526
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Electricity Commodity Contract [Member]	'	'
Derivative assets [Abstract]	'	'
Derivative Assets	0	0
Derivative 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	33	6
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	-32	-6
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Other Contract [Member]	'	'
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	0	0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]	'	'
Assets [Abstract]	'	'
Cash and Cash Equivalents, Fair Value Disclosure	115	123
Nuclear decommissioning trusts	412	343
Other investments	44	44
Derivative assets [Abstract]	'	'
Derivative Assets	351	295
Assets, Fair Value Disclosure	922	805
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	-415	-315
Derivative Liabilities, Current	-328	-269
Derivative Liabilities, Noncurrent	-87	-46
Fair Value, Net Asset (Liability)	507	490
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Current Asset [Member]	'	'
Derivative assets [Abstract]	'	'
Assets, Fair Value Disclosure	400	372
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Non Current Asset [Member]	'	'
Derivative assets [Abstract]	'	'
Assets, Fair Value Disclosure	522	433
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Natural Gas Commodity Contract [Member]	'	'
Derivative assets [Abstract]	'	'
Derivative Assets	89	66
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	-140	-73
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Electricity Commodity Contract [Member]	'	'
Derivative assets [Abstract]	'	'
Derivative Assets	261	226
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	-272	-240
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Other Commodity Contract [Member]	'	'
Derivative assets [Abstract]	'	'
Derivative Assets	1	3
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	-2	-1
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Other Contract [Member]	'	'
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	-1	-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	176	160
Assets, Fair Value Disclosure	176	160
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	-212	-173
Derivative Liabilities, Current	-177	-144
Derivative Liabilities, Noncurrent	-35	-29
Fair Value, Net Asset (Liability)	-36	-13
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Current Asset [Member]	'	'
Derivative assets [Abstract]	'	'
Assets, Fair Value Disclosure	139	120
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Non Current Asset [Member]	'	'
Derivative assets [Abstract]	'	'
Assets, Fair Value Disclosure	37	40
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Natural Gas Commodity Contract [Member]	'	'
Derivative assets [Abstract]	'	'
Derivative Assets	34	24
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	-86	-62
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Electricity Commodity Contract [Member]	'	'
Derivative assets [Abstract]	'	'
Derivative Assets	139	134
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	-126	-111
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Other Commodity Contract [Member]	'	'
Derivative assets [Abstract]	'	'
Derivative Assets	3	2
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	0	0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Other Contract [Member]	'	'
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	0	0
Fair Value, Measurements, Recurring [Member] | Netting Adjustments [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	-707	-869
Assets, Fair Value Disclosure	-707	-869
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	698	869
Derivative Liabilities, Current	578	754
Derivative Liabilities, Noncurrent	120	115
Fair Value, Net Asset (Liability)	9	0
Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member] | Current Asset [Member]	'	'
Derivative assets [Abstract]	'	'
Assets, Fair Value Disclosure	-592	-754
Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member] | Non Current Asset [Member]	'	'
Derivative assets [Abstract]	'	'
Assets, Fair Value Disclosure	-115	-115
Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member] | Natural Gas Commodity Contract [Member]	'	'
Derivative assets [Abstract]	'	'
Derivative Assets	-382	-605
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	395	605
Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member] | Electricity Commodity Contract [Member]	'	'
Derivative assets [Abstract]	'	'
Derivative Assets	-291	-258
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	269	258
Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member] | Other Commodity Contract [Member]	'	'
Derivative assets [Abstract]	'	'
Derivative Assets	-34	-6
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	34	6
Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member] | Other Contract [Member]	'	'
Derivative liabilities [Abstract]	'	'
Derivative Liabilities	$0	$0

Fair_Value_Reconciliation_of_L

Fair Value (Reconciliation of Level 3 Assets and Liabilities at Fair Value on a Recurring Basis) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'	'
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	($13)	$44
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Transfers into Level 3	1	1
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	43	60
Fair Value Net Derivative Asset (Liability) Measured on Recurring Basis Unobservable Inputs Reconciliation Gains and Losses Recorded In Regulatory Assets Liabilities	5	15
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Purchases	-7	2
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Issues	-1	0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Settlements	-64	-135
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	-36	-13
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss)	-1	58
Natural Gas Commodity Contract [Member]	'	'
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'	'
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	-38	6
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Transfers into Level 3	1	1
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	-32	-41
Fair Value Net Derivative Asset (Liability) Measured on Recurring Basis Unobservable Inputs Reconciliation Gains and Losses Recorded In Regulatory Assets Liabilities	0	0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Purchases	-8	0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Issues	0	0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Settlements	25	-4
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	-52	-38
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss)	-49	-33
Electricity Commodity Contract [Member]	'	'
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'	'
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	23	32
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Transfers into Level 3	0	0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	75	101
Fair Value Net Derivative Asset (Liability) Measured on Recurring Basis Unobservable Inputs Reconciliation Gains and Losses Recorded In Regulatory Assets Liabilities	0	0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Purchases	1	2
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Issues	-1	0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Settlements	-85	-112
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	13	23
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss)	48	91
Other Commodity Contract [Member]	'	'
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'	'
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	2	6
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Transfers into Level 3	0	0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings	0	0
Fair Value Net Derivative Asset (Liability) Measured on Recurring Basis Unobservable Inputs Reconciliation Gains and Losses Recorded In Regulatory Assets Liabilities	5	15
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Purchases	0	0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Issues	0	0
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Settlements	-4	-19
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	3	2
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss)	$0	$0

Fair_Value_Transfers_between_L

Fair Value (Transfers between Levels of the Fair Value Hierarchy) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Fair Value Transfers Between Level 1, Level 2 and Level 3 [Line Items]	'	'
Fair Value Transfer from Level 1 to Level 2, Amount	$0	$0
Fair Value Transfer from Level 1 to Level 3, Amount	0	0
Fair Value Transfer from Level 2 to Level 1, Amount	0	0
Fair Value Transfer from Level 2 to Level 3, Amount	1	1
Fair Value Transfer from Level 3 to Level 1, Amount	0	0
Fair Value Transfer from Level 3 to Level 2, Amount	$0	$0

Fair_Value_Unobservable_Inputs

Fair Value (Unobservable Inputs related to Level 3 Assets and Liabilities) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified	MMBTU	MMBTU
Fair Value, Inputs, Level 3 [Member] | Natural Gas Commodity Contract [Member]	'	'
Unobservable Inputs Valuation Techniques [Line Items]	'	'
Derivative Weighted Average Forward Basis Price	-0.16	0.03
Fair Value, Inputs, Level 3 [Member] | Electricity Commodity Contract [Member]	'	'
Unobservable Inputs Valuation Techniques [Line Items]	'	'
Derivative Weighted Average Forward Basis Price	3	3
Fair Value, Measurements, Recurring [Member]	'	'
Unobservable Inputs Valuation Techniques [Line Items]	'	'
Derivative Assets	126	147
Derivative Liabilities	-238	-151
Fair Value, Measurements, Recurring [Member] | Natural Gas Commodity Contract [Member]	'	'
Unobservable Inputs Valuation Techniques [Line Items]	'	'
Derivative Assets	14	40
Derivative Liabilities	-108	-56
Fair Value, Measurements, Recurring [Member] | Electricity Commodity Contract [Member]	'	'
Unobservable Inputs Valuation Techniques [Line Items]	'	'
Derivative Assets	109	102
Derivative Liabilities	-129	-93
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]	'	'
Unobservable Inputs Valuation Techniques [Line Items]	'	'
Derivative Assets	176	160
Derivative Liabilities	-212	-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	-86	-62
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Electricity Commodity Contract [Member]	'	'
Unobservable Inputs Valuation Techniques [Line Items]	'	'
Derivative Assets	139	134
Derivative Liabilities	-126	-111
Minimum [Member] | Fair Value, Inputs, Level 3 [Member] | Natural Gas Commodity Contract [Member]	'	'
Unobservable Inputs Valuation Techniques [Line Items]	'	'
Weighted Average Range for Unobservable Inputs	-0.88	-0.63
Minimum [Member] | Fair Value, Inputs, Level 3 [Member] | Electricity Commodity Contract [Member]	'	'
Unobservable Inputs Valuation Techniques [Line Items]	'	'
Weighted Average Range for Unobservable Inputs	-7	-2
Maximum [Member] | Fair Value, Inputs, Level 3 [Member] | Natural Gas Commodity Contract [Member]	'	'
Unobservable Inputs Valuation Techniques [Line Items]	'	'
Weighted Average Range for Unobservable Inputs	5.07	1.95
Maximum [Member] | Fair Value, Inputs, Level 3 [Member] | Electricity Commodity Contract [Member]	'	'
Unobservable Inputs Valuation Techniques [Line Items]	'	'
Weighted Average Range for Unobservable Inputs	15	16

Fair_Value_Fair_Value_of_Finan

Fair Value (Fair Value of Financial Instruments) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Fair Value of Financial Instruments [Line Items]	'	'
Notes Receivable Excudling Capital Leases	$41	$39
Dividends Payable, Current	116	107
Short-term Debt	131	240
Long-term Debt	8,094	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 Disclosure	0	0
Long-term Debt, Fair Value	425	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 Disclosure	131	240
Long-term Debt, Fair Value	7,551	7,453
Fair Value, Inputs, Level 3 [Member]	'	'
Fair Value of Financial Instruments [Line Items]	'	'
Notes Receivable, Fair Value Disclosure	41	39
Dividends Payable Fair Value Disclosure	0	0
Short-term Debt, Fair Value Disclosure	0	0
Long-term Debt, Fair Value	$499	$933

Fair_Value_Fair_Value_of_Nucle

Fair Value (Fair Value of Nuclear Decommissioning Trust Fund Assets) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Decommissioning Fund Investments	$1,191	$1,037
Fermi 2 [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Decommissioning Fund Investments	1,172	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
Nuclear Decommissioning Trust Fund [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Decommissioning Fund Investments	$1,191	$1,037

Fair_Value_Gains_and_Losses_an

Fair Value (Gains and Losses and Proceeds from the Sale of Securities by the Nuclear Decommissioning Trust Funds) (Details) (Nuclear Decommissioning Trust Fund [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Nuclear Decommissioning Trust Fund [Member]	'	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'	'
Realized gains	$83	$37	$46
Realized losses	-41	-31	-38
Proceeds from sales of securities	$1,118	$759	$833

Fair_Value_Fair_Value_and_Unre

Fair Value (Fair Value and Unrealized Gains for the Nuclear Decommissioning Trust Funds) (Details) (Nuclear Decommissioning Trust Fund [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'
Nuclear decommissioning trusts	$1,191	$1,037
Unrealized Gains	213	149
Equity Securities [Member]	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'
Equity securities	730	631
Unrealized Gains	201	122
Debt Securities [Member]	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'
Debt securities	442	399
Unrealized Gains	12	27
Cash and Cash Equivalents [Member]	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'
Cash and Cash Equivalents, Fair Value Disclosure	19	7
Unrealized Gains	$0	$0

Fair_Value_Details_Textuals

Fair Value (Details Textuals) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'	'
Other Comprehensive Income (Loss), Unrealized Holding Gain (Loss) on Securities Arising During Period, before Tax	$0	$0	'
Trading Securities, Change in Unrealized Holding Gain (Loss)	22,000,000	11,000,000	4,000,000
Equity Securities [Member]	'	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'	'
Nuclear Decommissioning Trust Fund Investments	61.00%	61.00%	'
Debt Securities [Member]	'	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'	'
Nuclear Decommissioning Trust Fund Investments	37.00%	38.00%	'
Cash and Cash Equivalents [Member]	'	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'	'
Nuclear Decommissioning Trust Fund Investments	2.00%	1.00%	'
Fair Value, Measurements, Recurring [Member]	'	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'	'
Cash and Cash Equivalents, Fair Value Disclosure	125,000,000	123,000,000	'
Other investments	136,000,000	110,000,000	'
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'	'
Cash and Cash Equivalents, Fair Value Disclosure	115,000,000	123,000,000	'
Other investments	44,000,000	44,000,000	'
Other Investments [Member] | Fair Value, Measurements, Recurring [Member]	'	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'	'
Cash and Cash Equivalents, Fair Value Disclosure	16,000,000	'	'
Other Investments [Member] | Fair Value, Measurements, Recurring [Member] | Equity [Member]	'	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'	'
Available-for-sale Securities, Fair Value Disclosure	7,000,000	5,000,000	'
Other investments	136,000,000	110,000,000	'
Other Investments [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'	'
Cash and Cash Equivalents, Fair Value Disclosure	'	14,000,000	'
Restricted Assets [Member] | Fair Value, Measurements, Recurring [Member]	'	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'	'
Cash and Cash Equivalents, Fair Value Disclosure	109,000,000	'	'
Restricted Assets [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'	'
Cash and Cash Equivalents, Fair Value Disclosure	'	109,000,000	'
Nuclear Decommissioning Trust Fund [Member]	'	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'	'
Average Maturity of Debt Securities	'7 years	'6 years	'
Nuclear Decommissioning Trust Fund [Member] | Cash and Cash Equivalents [Member]	'	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'	'
Cash and Cash Equivalents, Fair Value Disclosure	19,000,000	7,000,000	'
Fermi 2 [Member]	'	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'	'
Unrealized losses recognized as regulatory assets	31,000,000	44,000,000	'
Fermi 1 [Member]	'	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'	'
Other than Temporary Impairment Losses, Investments, Portion Recognized in Earnings, Net	$0	$0	$0

Financial_and_Other_Derivative2

Financial and Other Derivative Instruments (Fair Value of Derivative Instruments) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Derivatives designated as hedging instruments:	'	'
Derivative Asset, Fair Value, Gross Asset	$833	$1,016
Derivative Liability, Fair Value, Gross Liability	-936	-1,020
Derivative Asset, Current	99	108
Derivative Assets, Noncurrent	27	39
Derivative Liabilities, Current	-195	-125
Derivative Liabilities, Noncurrent	-43	-26
Estimate of Fair Value, Fair Value Disclosure [Member]	'	'
Derivatives designated as hedging instruments:	'	'
Derivative Asset, Current	691	862
Derivative Assets, Noncurrent	142	154
Derivative Liabilities, Current	-773	-879
Derivative Liabilities, Noncurrent	-163	-141
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	833	1,016
Derivative Liability, Fair Value, Gross Liability	-936	-1,019
Not Designated as Hedging Instrument [Member] | Foreign currency exchange contracts [Member]	'	'
Derivatives designated as hedging instruments:	'	'
Derivative Asset, Fair Value, Gross Asset	0	0
Derivative Liability, Fair Value, Gross Liability	-1	0
Not Designated as Hedging Instrument [Member] | Natural Gas [Member]	'	'
Derivatives designated as hedging instruments:	'	'
Derivative Asset, Fair Value, Gross Asset	396	645
Derivative Liability, Fair Value, Gross Liability	-503	-661
Not Designated as Hedging Instrument [Member] | Electricity [Member]	'	'
Derivatives designated as hedging instruments:	'	'
Derivative Asset, Fair Value, Gross Asset	400	360
Derivative Liability, Fair Value, Gross Liability	-398	-351
Not Designated as Hedging Instrument [Member] | Other [Member]	'	'
Derivatives designated as hedging instruments:	'	'
Derivative Asset, Fair Value, Gross Asset	37	11
Derivative Liability, Fair Value, Gross Liability	($34)	($7)

Financial_and_Other_Derivative3

Financial and Other Derivative Instruments (Netting Offsets of Derivative Assets and Liabilites) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Netting Offsets of Derivative Assets and Liabilities [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	$833	$1,016
Derivative Asset, Fair Value, Gross Liability	-707	-869
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	126	147
Derivative Liability, Fair Value, Gross Liability	-936	-1,020
Derivative Liability, Fair Value, Gross Asset	698	869
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	-238	-151
Natural Gas Commodity Contract [Member]	'	'
Netting Offsets of Derivative Assets and Liabilities [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	396	645
Derivative Asset, Fair Value, Gross Liability	-382	-605
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	14	40
Derivative Liability, Fair Value, Gross Liability	-503	-661
Derivative Liability, Fair Value, Gross Asset	395	605
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	-108	-56
Electricity Commodity Contract [Member]	'	'
Netting Offsets of Derivative Assets and Liabilities [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	400	360
Derivative Asset, Fair Value, Gross Liability	-291	-258
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	109	102
Derivative Liability, Fair Value, Gross Liability	-398	-351
Derivative Liability, Fair Value, Gross Asset	269	258
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	-129	-93
Other Commodity Contract [Member]	'	'
Netting Offsets of Derivative Assets and Liabilities [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	-34	-7
Derivative Liability, Fair Value, Gross Asset	34	6
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	0	-1
Other Contract [Member]	'	'
Netting Offsets of Derivative Assets and Liabilities [Line Items]	'	'
Derivative Asset, Fair Value, Gross Asset	37	11
Derivative Asset, Fair Value, Gross Liability	-34	-6
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	3	5
Derivative Liability, Fair Value, Gross Liability	-1	-1
Derivative Liability, Fair Value, Gross Asset	0	0
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	($1)	($1)

Financial_and_Other_Derivative4

Financial and Other Derivative Instruments (Netting Offsets Reconciliation to Balance Sheet) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Derivative [Line Items]	'	'
Derivative Asset, Current	$99	$108
Derivative Assets, Noncurrent	27	39
Derivative Liabilities, Current	-195	-125
Derivative Liabilities, Noncurrent	-43	-26
Derivative Asset [Member]	'	'
Derivative [Line Items]	'	'
Derivative Asset, Current	691	862
Derivative Assets, Noncurrent	142	154
Derivative Liabilities [Member]	'	'
Derivative [Line Items]	'	'
Derivative Liabilities, Current	-773	-879
Derivative Liabilities, Noncurrent	-163	-141
Counterparty Netting [Member]	'	'
Derivative [Line Items]	'	'
Derivative Asset, Current	-566	-754
Derivative Assets, Noncurrent	-115	-115
Derivative Liabilities, Current	566	754
Derivative Liabilities, Noncurrent	115	115
Collateral Adjustment [Member]	'	'
Derivative [Line Items]	'	'
Derivative Asset, Current	-26	0
Derivative Assets, Noncurrent	0	0
Derivative Liabilities, Current	12	0
Derivative Liabilities, Noncurrent	$5	$0

Financial_and_Other_Derivative5

Financial and Other Derivative Instruments (Effect of Derivatives not Deisgnated as Hedging Instruments on the Consolidated Statement of Operations) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	($11)	$65
Foreign currency exchange contracts [Member] | Operating Revenue [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	-1	0
Natural Gas [Member] | Operating Revenue [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	-48	-29
Natural Gas [Member] | Fuel, purchased power and gas [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	-44	25
Electricity [Member] | Operating Revenue [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	82	64
Other [Member] | Operating Revenue [Member]	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$0	$5

Financial_and_Other_Derivative6

Financial and Other Derivative Instruments (Cumulative Gross Volume of Derivative Contracts Outstanding) (Details)	Dec. 31, 2013
	dte.volumes
Natural Gas [Member]	'
Derivative [Line Items]	'
Volume of Commodity Contracts	795,553,773
Electricity [Member]	'
Derivative [Line Items]	'
Volume of Commodity Contracts	55,658,483
Foreign currency exchange contracts [Member]	'
Derivative [Line Items]	'
Volume of Commodity Contracts	65,074,206
FTR [Member]	'
Derivative [Line Items]	'
Volume of Commodity Contracts	10,485,618

Financial_and_Other_Derivative7

Financial and Other Derivative Instruments (Details Textuals) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Derivative [Line Items]	'	'
Interest Rate Cash Flow Hedge Gain (Loss) to be Reclassified During Next 12 Months, Net	$1	'
Letters of Credit Outstanding, Amount	19	63
Cash Collateral Posted Net of Cash Collateral Received	12	'
Cash Collateral Paid or Received for Derivative Assets	26	0
Cash Collateral Paid or Received for Derivative Liabilities	17	'
Cash Collateral Paid	34	4
Cash Collateral Received	13	24
Value of Transactions Company Would Have Been Exposed to if Credit Rating Below Investment Grade	406	'
Derivative, Net Liability Position, Aggregate Fair Value	1,176	'
Collateral Already Posted, Aggregate Fair Value	902	20
Additional Collateral, Aggregate Fair Value	249	'
FTR [Member]	'	'
Derivative [Line Items]	'	'
Derivative Instruments Recoverable Through PSCR Mechanism	5	15
Credit Risk Contract [Member]	'	'
Derivative [Line Items]	'	'
Collateral Already Posted, Aggregate Fair Value	$25	'

Goodwill_Carrying_Amount_of_Go

Goodwill (Carrying Amount of Goodwill) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Goodwill [Line Items]	'	'
Beginning Balance	$2,018	$2,020
Goodwill Period Increase (Decrease)	0	-2
Ending Balance	$2,018	$2,018

Acquisition_Details_Textuals

Acquisition (Details Textuals) (USD $)	3 Months Ended
	Mar. 31, 2013	Dec. 31, 2012
		facilities
Business Acquisition, Equity Interests Issued or Issuable [Line Items]	'	'
Number of Businesses Acquired	'	14
Business Combination, Consideration Transferred	'	$294,000,000
Business Combination, Payments to Acquire Businesses, Gross	'	220,000,000
Business Acquisition, Consideration Transferred, Other	'	74,000,000
Number of Project Companies Acquired Deemed VIEs that assumed Debt Relates	'	2
Exposure Loss Related to the Debt Assumed	'	0
Business Combination, Intangible assets	'	75,000,000
Amortization Years for Intangible Assets Acquired in a Business Combination	'	'8 years
Revenues of Acquired Business Included in the Company's Consolidated Statement of Operations	'	30,000,000
Earnings of Acquired Business Included in the Company's Consolidated Statements of Operations	'	$2,000,000
The Period of the Acquired Project Companies Following the Closing included in Results of Operations	'3 months	'
Minimum [Member]	'	'
Business Acquisition, Equity Interests Issued or Issuable [Line Items]	'	'
Equity Method Investment, Ownership Percentage	'	46.00%
Maximum [Member]	'	'
Business Acquisition, Equity Interests Issued or Issuable [Line Items]	'	'
Equity Method Investment, Ownership Percentage	'	100.00%

Acquisition_Details

Acquisition (Details) (USD $)	Dec. 31, 2012
In Millions, unless otherwise specified
Allocation of the Purchase Price to Assets and Liabilities [Line Items]	'
Business Combination, Cash	$22
Business Combination, Accounts receivables	14
Business Combination, Other Current assets	8
Business Combination, Property, Plant and Equipment	100
Business Combination, Intangible assets	75
Business Combination, Other Noncurrent Assets	9
Business Combination, Current Liabilities	-7
Business Combination, Non-controlling Interest	-1
Business Combination, Purchase Price	$220

Discontinued_Operations_Detail

Discontinued Operations (Details Textuals) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'
Proceeds from Divestiture of Businesses	$0	$255	$0
Discontinued Operations [Member]	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'
Disposal of Equity Interest In Segment Percentage	'	100.00%	'
Proceeds from Divestiture of Businesses	'	255	'
Discontinued Operation, Loss from Disposal of Discontinued Operation, before Income Tax	'	83	'
Discontinued Operation, Loss on Disposal of Discontinued Operation, Net of Tax	'	55	'
Allocation of Corporate Interest Costs	$0	'	'

Discontinued_Operations_Detail1

Discontinued Operations (Details) (USD $)	3 Months Ended				12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'
Total operating expenses	'	'	'	'	$8,458	$7,512	$7,437
Disposal Group, Income tax expense (benefit)	'	'	'	'	0	29	1
Discontinued Operations Income (Loss), net of tax	-56	1	-1	0	0	-56	-3
Segment, Discontinued Operations [Member]	'	'	'	'	'	'	'
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]	'	'	'	'	'	'	'
Disposal Group, Operating Revenues	'	'	'	'	'	55	39
Disposal Group, Operation and maintenance	'	'	'	'	'	24	16
Disposal Group, Depreciation, Depletion and Amortization	'	'	'	'	'	23	18
Disposal Group, Taxes Other than Income	'	'	'	'	'	4	3
Disposal Group, Assets (Gains) and Losses, Net	'	'	'	'	'	83	0
Total operating expenses	'	'	'	'	'	134	37
Disposal Group, Operating Income (Loss)	'	'	'	'	'	-79	2
Disposal Group, Other (income) and deductions	'	'	'	'	'	6	6
Disposal Group, Income (Loss) from Discontinued Operation, before Income Tax	'	'	'	'	'	-85	-4
Disposal Group, Income tax expense (benefit)	'	'	'	'	'	-29	-1
Discontinued Operations Income (Loss), net of tax	'	'	'	'	'	($56)	($3)

Property_Plant_and_Equipment_S

Property, Plant and Equipment (Summary of Property by Classification) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Property, Plant and Equipment [Line Items]	'	'
Property, Plant and Equipment - Non-utility and other	$2,292	$1,960
Property, plant and equipment, Total	25,123	23,631
Less Accumulated Depreciation, Depletion and Amortization - Nonutility and Other	-767	-676
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	-9,323	-8,947
Property, plant and equipment	15,800	14,684
Electric Generation Equipment [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property Plant and Equipment - Generation	11,127	10,383
Less Accumulated Depreciation, Depletion and Amortization - Generation	-4,004	-3,880
Electric Distribution [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property Plant and Equipment - Distribution	7,603	7,306
Less Accumulated Depreciation, Depletion and Amortization - Distribution	-2,947	-2,837
Electric Generation, Transmission and Distribution Equipment [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Public Utilities, Property, Plant and Equipment, Plant in Service	18,730	17,689
Total Utility Accumulated Depreciation, Depletion and Amortization	-6,951	-6,717
Gas Distribution [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property Plant and Equipment - Distribution	2,834	2,704
Less Accumulated Depreciation, Depletion and Amortization - Distribution	-1,129	-1,057
Storage [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, Plant and Equipment - Storage	431	426
Less Accumulated Depreciation, Depletion and Amortization - Storage	-138	-132
Other [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Property, Plant and Equipment - Other	836	852
Less Accumulated Depreciation, Depletion and Amortization - Other	-338	-365
Gas Distribution and Storage [Member]	'	'
Property, Plant and Equipment [Line Items]	'	'
Public Utilities, Property, Plant and Equipment, Plant in Service	4,101	3,982
Total Utility Accumulated Depreciation, Depletion and Amortization	($1,605)	($1,554)

Property_Plant_and_Equipment_A

Property, Plant and Equipment (Average Estimated Useful Life of Each Major Class) (Details)	12 Months Ended
	Dec. 31, 2013
Electric [Member]	'
Public Utility Property, Plant and Equipment [Line Items]	'
Useful Life - Generation	'40 years
Useful Life - Distribution	'41 years
Gas [Member]	'
Public Utility Property, Plant and Equipment [Line Items]	'
Useful Life - Distribution	'50 years
Useful Life - Storage	'53 years

Property_Plant_and_Equipment_D

Property, Plant and Equipment (Details Textuals) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Public Utility Property, Plant and Equipment [Line Items]	'	'	'
AFUDC capitalized	$23	$20	'
Capitalized Computer Software, Amortization	71	68	65
Capitalized Computer Software, Gross	668	608	'
Capitalized Computer Software, Accumulated Amortization	384	313	'
Capital Leased Assets, Gross	35	32	'
Capital Leases, Lessee Balance Sheet, Assets by Major Class, Accumulated Depreciation	$21	$20	'
Electric [Member]	'	'	'
Public Utility Property, Plant and Equipment [Line Items]	'	'	'
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service	3.40%	3.30%	3.30%
Gas [Member]	'	'	'
Public Utility Property, Plant and Equipment [Line Items]	'	'	'
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service	2.40%	2.40%	2.30%
Minimum [Member]	'	'	'
Public Utility Property, Plant and Equipment [Line Items]	'	'	'
Property, Plant and Equipment, Useful Life	'3 years	'	'
Finite-Lived Intangible Assets, Useful Life	'1 year	'	'
Maximum [Member]	'	'	'
Public Utility Property, Plant and Equipment [Line Items]	'	'	'
Property, Plant and Equipment, Useful Life	'55 years	'	'
Finite-Lived Intangible Assets, Useful Life	'28 years	'	'
Computer Software, Intangible Asset [Member] | Minimum [Member]	'	'	'
Public Utility Property, Plant and Equipment [Line Items]	'	'	'
Finite-Lived Intangible Assets, Useful Life	'3 years	'	'
Computer Software, Intangible Asset [Member] | Maximum [Member]	'	'	'
Public Utility Property, Plant and Equipment [Line Items]	'	'	'
Finite-Lived Intangible Assets, Useful Life	'15 years	'	'

Jointly_Owned_Utility_Plant_De

Jointly Owned Utility Plant (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified	dte.capacity
Belle River [Member]	'
Jointly Owned Utility Plant Interests [Line Items]	'
Total plant capacity (in MW)	1,270
Investment (in millions)	$1,702
Accumulated depreciation (in millions)	969
Ludington [Member]	'
Jointly Owned Utility Plant Interests [Line Items]	'
Total plant capacity (in MW)	1,872
Ownership interest	49.00%
Investment (in millions)	354
Accumulated depreciation (in millions)	$170

Jointly_Owned_Utility_Plant_De1

Jointly Owned Utility Plant (Detail Textuals)	Dec. 31, 2013
	facilities
Jointly Owned Utility Plant Interests [Line Items]	'
Jointly Owned Utility Plant Number of Plants	2
Belle River Unit 1 [Member]	'
Jointly Owned Utility Plant Interests [Line Items]	'
Jointly Owned Utility Plant, Proportionate Ownership Share	63.00%
Belle River Facilities used jointly by Belle River and St. Clair Power Plants [Member]	'
Jointly Owned Utility Plant Interests [Line Items]	'
Jointly Owned Utility Plant, Proportionate Ownership Share	81.00%
Belle River [Member]	'
Jointly Owned Utility Plant Interests [Line Items]	'
Joint Owners Percentage of the Total Capacity Energy and Related Responsibilities	19.00%
Belle River Unit 2 [Member]	'
Jointly Owned Utility Plant Interests [Line Items]	'
Jointly Owned Utility Plant, Proportionate Ownership Share	75.00%
Ludington [Member]	'
Jointly Owned Utility Plant Interests [Line Items]	'
Jointly Owned Utility Plant, Proportionate Ownership Share	49.00%
Joint Owners Percentage of the Total Capacity Energy and Related Responsibilities	51.00%

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'
Asset retirement obligations, beginning balance	$1,719
Accretion	106
Liabilities incurred	5
Liabilities settled	-13
Revision in estimated cash flows	10
Asset retirement obligations, ending balance	$1,827

Asset_Retirement_Obligations_D1

Asset Retirement Obligations (Details Textuals) (USD $)	12 Months Ended	3 Months Ended	6 Months Ended	3 Months Ended	12 Months Ended
	Dec. 31, 2013	Mar. 31, 2011	Jun. 30, 2011	Dec. 31, 2011	Dec. 31, 2013
		Fermi 1 [Member]	Fermi 1 [Member]	Fermi 2 [Member]	Fermi 2 [Member]
Asset Retirement Obligations [Line Items]	'	'	'	'	'
Asset Retirement Obligations, Liability Not Recognized	'Natural gas storage system assets, substations, manholes and certain other distribution assets have an indeterminate life. Therefore, no liability has been recorded for these assets.	'	'	'	'
Revision in estimated cash flows	$10,000,000	$19,000,000	$20,000,000	$22,000,000	'
Reserve and Impairment of Retirement Obligation	'	'	6,000,000	'	'
Proposed Extension of Nuclear Plant 2 License	'	'	'	'	'20 years
Estimated decommissioning expenses, current fiscal year dollars	'	'	'	'	1,600,000,000
Estimated decommissioning expenses, end of extended license dollars	'	'	'	'	10,000,000,000
Inflation Rate Used to Determine Estimated Decommissioning Expenditures	'	'	'	'	6.00%
Nuclear Decommissioning Liabilities Funded Through Surcharge and Included In ARO Balance	'	'	'	'	1,600,000,000
Liabilities Balance upon Completion of Decommissioning	$0	'	'	'	'

Regulatory_Matters_Schedule_of

Regulatory Matters (Schedule of Regulatory Assets) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Regulatory Assets [Line Items]	'	'
Regulatory Assets	$2,863	$4,417
Regulatory Assets, Current	-26	-182
Regulatory Assets, Noncurrent	2,837	4,235
Securitized Regulatory Assets, Noncurrent	231	413
Pension Costs [Member]	'	'
Regulatory Assets [Line Items]	'	'
Regulatory Assets	1,660	2,420
Postretirment Costs [Member]	'	'
Regulatory Assets [Line Items]	'	'
Regulatory Assets	0	426
Asset Retirement Obligation Costs [Member]	'	'
Regulatory Assets [Line Items]	'	'
Regulatory Assets	394	424
Recoverable Michigan Income Taxes [Member]	'	'
Regulatory Assets [Line Items]	'	'
Regulatory Assets	286	304
Recoverable Income Taxes related to Securitized Regulatory Assets [Member]	'	'
Regulatory Assets [Line Items]	'	'
Regulatory Assets	126	226
Cost to Achieve Performance Excellence Process [Member]	'	'
Regulatory Assets [Line Items]	'	'
Regulatory Assets	75	96
Other Recoverabe Income Taxes [Member]	'	'
Regulatory Assets [Line Items]	'	'
Regulatory Assets	71	76
Unamortized Loss on Reacquired Debt [Member]	'	'
Regulatory Assets [Line Items]	'	'
Regulatory Assets	63	63
Environmental Restoration Costs [Member]	'	'
Regulatory Assets [Line Items]	'	'
Regulatory Assets	59	58
Enterprise Business Systems Costs [Member]	'	'
Regulatory Assets [Line Items]	'	'
Regulatory Assets	13	16
Regulatory Clause Revenues, under-recovered [Member]	'	'
Regulatory Assets [Line Items]	'	'
Regulatory Assets	9	28
Choice Incentive Mechanism [Member]	'	'
Regulatory Assets [Line Items]	'	'
Regulatory Assets	3	66
Accrued PSCRandGCR Revenue [Member]	'	'
Regulatory Assets [Line Items]	'	'
Regulatory Assets	0	87
Recoverable Restoration Expense [Member]	'	'
Regulatory Assets [Line Items]	'	'
Regulatory Assets	0	49
Other Assets [Member]	'	'
Regulatory Assets [Line Items]	'	'
Regulatory Assets	$104	$78

Regulatory_Matters_Regulatory_

Regulatory Matters Regulatory Matters (Schedule of Regulatory Liabilities) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	$1,164	$1,120
Regulatory Liability, Current	-302	-89
Regulatory Liability, Noncurrent	862	1,031
Asset Removal Costs [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	351	439
Renewable Energy [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	277	230
Refundable Revenue Decoupling [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	127	127
Pension Costs [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	84	105
Over Recovery of Securitization [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	72	54
Refundable postretirement costs [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	72	0
Accrued PSCR GCR Refund [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	65	16
Refundable Income Taxes [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	45	56
Energy Optimization [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	31	34
Refueling Outage [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	26	12
Refundable Uncollectible Expense [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	12	37
Other Liabilities [Member]	'	'
Regulatory Liabilities [Line Items]	'	'
Regulatory Liabilities	$2	$10

Regulatory_Matters_Details_Tex

Regulatory Matters (Details Textuals) (USD $)

1 Months Ended

3 Months Ended

6 Months Ended

12 Months Ended

1 Months Ended

1 Months Ended

12 Months Ended

6 Months Ended

1 Months Ended

12 Months Ended

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2013

Jul. 29, 2013

Jul. 30, 2012

31-May-13

Dec. 31, 2013

31-May-13

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Jun. 30, 2013

Oct. 17, 2013

Aug. 29, 2013

Feb. 28, 2013

Oct. 31, 2013

Feb. 29, 2012

Dec. 31, 2013

Nov. 14, 2013

15-May-13

Apr. 16, 2013

Jun. 30, 2012

Electric [Member]

Electric [Member]

Gas [Member]

Gas [Member]

Five Year (Minimum) [Member]

Seven Year (Maximum) [Member]

MPSC [Member]

MPSC [Member]

MPSC [Member]

MPSC [Member]

MPSC [Member]

MPSC [Member]

MPSC [Member]

MPSC [Member]

MPSC [Member]

MPSC [Member]

MPSC [Member]

MPSC [Member]

Electric [Member]

Electric [Member]

Electric [Member]

Electric [Member]

Electric [Member]

Electric [Member]

Electric [Member]

Gas [Member]

Gas [Member]

Gas [Member]

Gas [Member]

Gas [Member]

Gas [Member]

Gas [Member]

Regulatory Assets [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Probability of Recovery Through Regulatory Rates for Regulatory Assets and Liabilities

'

'

'

'

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Time Period Required by Non-Bypassable Securitization Bond Surcharge to Recover Securitized Regulatory Asset

'

'

'

'

'14 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amortization Period of Cost to Achieve Deferral

'

'

'

'

'10 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferral of Investigation and Remediation of Costs Associated with Gas Utilities Former MGP Sites

'

'

'

'

'10 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amortization Period for Enterprise Business Systems

'

'

'

'

'10 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Rate increase previously authorized by the MPSC challeged by Court of Appeals affirmed by the MPSC

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,000,000

'

'

'

'

'

'

'

'

'

Rate increase previously authorized by the MPSC challenged by Court of Appeals reopened by the MPSC

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

11,000,000

'

'

'

'

'

'

'

'

Transition PLD customers to DTE Electric distribution system

'

'

'

'

'

'

'

'

'

'

'

'5 years

'7 years

'

'

'

'

'

'

'

'

'

'

'

'

EO Reconciliation net over-recovery

'

'

'

'

'

'

'

26,000,000

'

7,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Approved performance incentive charges

'

'

'

'

'

'

'

'

'

'

'

'

'

10,000,000

'

'

'

'

'

'

4,000,000

'

'

'

'

Approved net recovery of restoration expense tracker mechanism and line clearance tracker

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

44,000,000

'

'

'

'

'

'

'

Approved refund of uncollectible expense true up mechanism for two plan years prior

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9,000,000

'

'

'

'

'

Monthly Funding Factor for all Michigan Electric utilities participating in Low Income Energy Assistance Fund

'

'

'

'

'

0.0099

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

REP Surcharge Revenue Recovery

'

'

'

15,000,000

'

'

'

'

'

'

'

'

'

'

100,000,000

'

'

'

'

'

'

'

'

'

'

REP Time Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'20 years

'

'

'

'

'

'

'

'

'

'

'

PSCR under-recovery from Three Plan Years Prior

'

'

52,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Pension Equalization Mechanism Reconciliation surcharge length

'1 month

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

PSCR under-recovery from One Plan Year Prior

'

87,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

PSCR Under-Recovery from Two Plan Years Prior

'

148,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fermi 2 Production Level of Full Capacity

'

'

'

'

'

'

68.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum of challenged Fermi 2 outage charges

'

'

'

'

'

'

'

'

32,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Projected Test Year Period for Gas Rate Case

'

'

'

'

'

'

'

'

'

'

'12 months

'

'

'

'

'

'

'

'

'

'

'

'

'

'

MPSC Approved Increase in Annual Gas Rates

'

'

'

'

'

'

'

'

'

'

19,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Approved recovery of infrastructure recovery mechanism

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

77,000,000

'

UETM Accrual for Over-Recovery

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20,000,000

'

'

'

'

Period over which approved UETM will be refunded

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'12 months

'

'

'

'

'

'

RDM Application Proposed Recovery

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$5,200,000

'

'

$9,000,000

RDM Caps for First Reconciliation Period

'

'

'

'

1.13%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

RDM Cap for Second Period Reconciliation

'

'

'

'

2.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Composite Depreciation Rates

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.51%

'

2.29%

'

'

Income_Taxes_Reconciliation_of

Income Taxes (Reconciliation of Income Tax Expense to the Statutory Federal Income Tax Rate) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Effective Income Tax Rate Reconciliation, Amount [Abstract]	'	'	'
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	$922	$960	$991
Income tax expense at 35% statutory rate	323	336	347
Production tax credits	-68	-49	-6
Investment tax credits	-6	-6	-6
Depreciation	-4	-4	-4
AFUDC - Equity	-5	-4	-1
Employee Stock Ownership Plan dividends	-4	-4	-4
Domestic production activities deduction	-14	-14	-7
State and Local income taxes, net of federal benefit	37	37	37
Enactment of Michigan Corporate income Tax, net of federal expense	0	0	-87
Other, net	-5	-6	-1
Income Tax Expense (Benefit)	$254	$286	$268
Effective Income Tax Rate	27.50%	29.80%	27.00%

Income_Taxes_Components_of_Inc

Income Taxes (Components of Income Tax Expense) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Components of Income Tax Expense (Benefit) [Abstract]	'	'	'
Federal income tax expense (benefit)	$74	$190	$27
State and other income tax expense (benefit)	16	49	21
Total current income taxes expense (benefit)	90	239	48
Federal deferred income tax expense (benefit)	122	39	318
State and other income tax deferred expense (benefit)	42	8	-98
Total deferred income taxes exepense (benefit)	164	47	220
Income Tax Expense (Benefit)	254	286	268
Income tax expense (benefit) from Discontinued Operations	0	-29	-1
Income Tax Expense (Benefit) including Discontinued Operations	$254	$257	$267

Income_Taxes_Deferred_Tax_Asse

Income Taxes (Deferred Tax Assets (Liabilities)) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Components of Deferred Tax Assets and Liabilities [Abstract]	'	'
Property, plant and equipment	($3,372)	($3,389)
Securitized regulatory assets	-127	-256
Alternative minimum tax credit carry-forwards	266	254
Merger basis differences	18	42
Pension and benefits	-30	-33
Other comprehensive income	0	101
Derivative assets liabilities	0	66
State net operating loss and credit carry-forwards	43	37
Deferred Tax Liabilities, Other	-110	'
Other	'	41
Deferred Tax Liabilities, Gross	-3,312	-3,137
Less valuation allowance	-37	-33
Current deferred income tax assets	-28	21
Long-term deferred income tax liabilities	-3,321	-3,191
Deferred Tax Assets, Net of Valuation Allowance	1,808	1,038
Deferred Tax Liability, Net of Valuation Allowance	-5,157	-4,208
Deferred income tax liabilities	($3,349)	($3,170)

Income_Taxes_Reconciliation_of1

Income Taxes (Reconciliation of Unrecognized Tax Benefits) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]	'	'	'
Unrecognized Tax Benefits, beginning balance	$11	$48	$28
Additions for tax positions of prior years	0	0	27
Reductions for tax positions of prior years	0	-2	-4
Additions for tax positions related to the current year	0	1	1
Settlements	0	-30	-3
Lapse of statute of limitations	-1	-6	-1
Unrecognized Tax Benefits, ending balance	$10	$11	$48

Income_Taxes_Details_Textuals

Income Taxes (Details Textuals) (USD $)	3 Months Ended	12 Months Ended
	Jun. 30, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Tax Disclosure [Abstract]	'	'	'	'
Production Tax Credits Earned In Prior Years But Not Utilized Carried Forward Indefinitely As Alternative Minimum Tax Credits	'	$266,000,000	$254,000,000	'
Deferred Tax Assets State Net Operating Loss and Credit Carry Forwards	'	43,000,000	37,000,000	'
Valuation Allowance, Amount	'	37,000,000	33,000,000	'
Unrecognized Tax Benefits that Would Impact Effective Tax Rate	'	2,000,000	3,000,000	'
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit	'	1,000,000	'	'
Unrecognized Tax Benefits, Interest on Income Taxes Accrued	'	1,000,000	1,000,000	'
Unrecognized Tax Benefits, Income Tax Penalties Accrued	'	0	'	'
Unrecognized Tax Benefits, Interest on Income Taxes Expense	'	0	-1,000,000	-2,000,000
Michigan Corporate Income Tax	6.00%	'	'	'
Time Period for the MBT Deferred Tax Asset	'1 year	'	'	'
Net impact of Michigan Corporate Income Tax enactment, decrease in deferred tax liabilities attributable to non-utilities	87,000,000	'	'	'
Consistent with Original Treatment of Deferred Tax Liabilities No Cash Flow Impact	$0	'	'	'

Common_Stock_Details

Common Stock (Details) (Pension Plan, Defined Benefit [Member], Common Stock [Member], USD $)	3 Months Ended				12 Months Ended
In Millions, except Share data, unless otherwise specified	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Jun. 30, 2012	Dec. 31, 2013
Pension Plan, Defined Benefit [Member] | Common Stock [Member]	'	'	'	'	'
Class of Stock [Line Items]	'	'	'	'	'
Stock Issued During Period, Shares, Employee Benefit Plan	1,522,301	753,579	750,075	1,334,668	'
Contribution of Common Stock to Pension Plans Amount Per Share	$65.69	$66.35	$66.66	$59.94	'
Pension Contributions	$100	$50	$50	$80	$200

Common_Stock_Details_Textuals

Common Stock (Details Textuals) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Class of Stock [Line Items]	'	'
Maximum Total Funded Debt to Total Capitalization Ratio	0.65	'
Line of Credit Facility, Dividend Restrictions	'166	'
Retained Earnings (Accumulated Deficit)	$4,150	$3,944
Other Restrictions on Payment of Dividends	'0	'

Earnings_Per_Share_Details

Earnings Per Share (Details) (USD $)	3 Months Ended								12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Basic Earnings per Share	'	'	'	'	'	'	'	'	'	'	'
Net Income Attributable to DTE Energy Company	$124	$198	$105	$234	$81	$227	$146	$156	$661	$610	$711
Average number of common shares outstanding	'	'	'	'	'	'	'	'	175	171	169
Weighted average net restricted shares outstanding	'	'	'	'	'	'	'	'	1	1	1
Dividends declared, Common Stock	'	'	'	'	'	'	'	'	453	413	392
Dividends declared, Net restricted shares	'	'	'	'	'	'	'	'	1	1	1
Total distributed earnings	'	'	'	'	'	'	'	'	454	414	393
Net income less distributed earnings, Basic	'	'	'	'	'	'	'	'	207	196	318
Distributed (dividends per common share)	'	'	'	'	'	'	'	'	$2.59	$2.42	$2.32
Undistributed	'	'	'	'	'	'	'	'	$1.17	$1.14	$1.87
Total Basic Earnings per Common Share	$0.70	$1.13	$0.60	$1.35	$0.47	$1.32	$0.86	$0.91	$3.76	$3.56	$4.19
Diluted Earnings per Share	'	'	'	'	'	'	'	'	'	'	'
Net Income Attributable to DTE Energy Company	124	198	105	234	81	227	146	156	661	610	711
Common shares for dilutive calculation	'	'	'	'	'	'	'	'	175	171	169
Average incremental shares from assumed exercise of options	'	'	'	'	'	'	'	'	0	1	1
Weighted Average Number Common shares for dilutive calculation	'	'	'	'	'	'	'	'	175	172	170
Weighted average net restricted shares outstanding	'	'	'	'	'	'	'	'	1	1	1
Dividends declared, Common Stock	'	'	'	'	'	'	'	'	453	413	392
Dividends declared, Net restricted shares	'	'	'	'	'	'	'	'	1	1	1
Total distributed earnings	'	'	'	'	'	'	'	'	454	414	393
Undistributed	'	'	'	'	'	'	'	'	$207	$196	$318
Distributed (dividends per common share)	'	'	'	'	'	'	'	'	$2.59	$2.42	$2.32
Earnings Per Share, Diluted, Undistributed	'	'	'	'	'	'	'	'	$1.17	$1.13	$1.86
Total Diluted Earnings per Common Share	$0.70	$1.13	$0.60	$1.34	$0.47	$1.31	$0.86	$0.91	$3.76	$3.55	$4.18

LongTerm_Debt_Long_Term_Debt_O

Long-Term Debt (Long Term Debt Outstanding and Weighted Average Interest Rates) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Debt Instrument [Line Items]	'	'
Long-term Debt, Total	$8,094	$7,813
Long Term Debt excluding Securitization, Debentures and Capital Leases	7,312	6,854
Less Amount of Long-term Debt due within one year	-694	-634
Long-term Debt, Excluding Current Maturities	6,618	6,220
Long-term Securitization Bond	302	479
Less Amount of Securitization Bonds due within one year	-197	-177
Securitization bonds, Excluding Current Maturities	105	302
Junior Subordinated Notes, Noncurrent	480	480
Securitization Bonds [Member]	'	'
Debt Instrument [Line Items]	'	'
Debt, Weighted Average Interest Rate	6.60%	'
Debt Instrument, Maturity Date	15-Mar-15	'
Junior Subordinated Debentures [Member]	'	'
Debt Instrument [Line Items]	'	'
Debt, Weighted Average Interest Rate	6.50%	'
Debt Instrument, Maturity Date	1-Dec-61	'
Junior Subordinated Notes, Noncurrent	280	280
Junior Subordinated Debentures 1 [Member]	'	'
Debt Instrument [Line Items]	'	'
Debt, Weighted Average Interest Rate	5.25%	'
Debt Instrument, Maturity Date	1-Dec-62	'
Junior Subordinated Notes, Noncurrent	200	200
DTE Energy [Member] | Unsecured Debt [Member]	'	'
Debt Instrument [Line Items]	'	'
Debt, Weighted Average Interest Rate	6.10%	'
Debt Instrument, Maturity Date Range, Start	15-May-14	'
Debt Instrument, Maturity Date Range, End	15-Apr-33	'
Long-term Debt, Total	1,297	1,298
DTE Electric [Member] | Secured Debt [Member]	'	'
Debt Instrument [Line Items]	'	'
Debt, Weighted Average Interest Rate	4.70%	'
Debt Instrument, Maturity Date Range, Start	31-Mar-14	'
Debt Instrument, Maturity Date Range, End	1-Apr-43	'
Long-term Debt, Total	4,286	3,777
DTE Electric [Member] | Tax Exempt Revenue Bonds [Member]	'	'
Debt Instrument [Line Items]	'	'
Debt, Weighted Average Interest Rate	5.10%	'
Debt Instrument, Maturity Date Range, Start	1-Apr-14	'
Debt Instrument, Maturity Date Range, End	1-Dec-36	'
Long-term Debt, Total	558	707
DTE Gas [Member] | Secured Debt [Member]	'	'
Debt Instrument [Line Items]	'	'
Debt, Weighted Average Interest Rate	5.60%	'
Debt Instrument, Maturity Date Range, Start	1-May-14	'
Debt Instrument, Maturity Date Range, End	15-Dec-42	'
Long-term Debt, Total	1,029	919
DTE Gas [Member] | Long Term Debt, Other [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term Debt, Total	$142	$153

LongTerm_Debt_Debt_Issuances_D

Long-Term Debt (Debt Issuances) (Details) (USD $)	Dec. 31, 2013	Sep. 30, 2013	Apr. 30, 2013	Mar. 31, 2013	Aug. 31, 2013	Nov. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013
In Millions, unless otherwise specified		Electric [Member]	Gas [Member]	Thirty Years [Member]	Eleven Years [Member]	Ten Years [Member]	Ten Years [Member]	Twelve Years [Member]	Fifteen Years [Member]
		Senior Notes [Member]	Senior Notes [Member]	Electric [Member]	Electric [Member]	DTE Energy [Member]	Gas [Member]	Gas [Member]	Gas [Member]
				Mortgages [Member]	Mortgages [Member]	Senior Notes [Member]	Mortgages [Member]	Mortgages [Member]	Mortgages [Member]
Debt Instrument [Line Items]	'	'	'	'	'	'	'	'	'
Debt Instrument, Interest Rate, Stated Percentage	'	6.40%	5.26%	4.00%	3.65%	3.85%	3.64%	3.74%	3.94%
Debt Instrument, Face Amount	$1,245	'	'	$375	$400	$300	$50	$70	$50

LongTerm_Debt_Debt_Redemptions

Long-Term Debt (Debt Redemptions) (Details) (USD $)	12 Months Ended	1 Months Ended								9 Months Ended	1 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Mar. 31, 2013	Dec. 31, 2013	Mar. 31, 2013	Apr. 30, 2013	Sep. 30, 2013	Dec. 31, 2013	Apr. 30, 2013	Sep. 30, 2013	Jun. 30, 2013
		Electric [Member]	Electric [Member]	Electric [Member]	Electric [Member]	Electric [Member]	Electric [Member]	Electric [Member]	Gas [Member]	DTE Energy [Member]	DTE Energy [Member]
		Securitization Bonds [Member]	Securitization Bonds [Member]	Tax Exempt Revenue Bonds [Member]	Tax Exempt Revenue Bonds [Member]	Long Term Debt, Other [Member]	Senior Notes [Member]	Tax-Exempt Revenue Bonds 1 [Member]	Senior Notes [Member]	Long Term Debt, Other [Member]	Senior Notes [Member]
Extinguishment of Debt [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Debt Instrument, Interest Rate, Stated Percentage	'	6.62%	6.42%	5.50%	5.30%	'	6.40%	6.75%	5.26%	'	'
Extinguishment of Debt, Amount	$961	$89	$88	$49	$51	$13	$250	$50	$60	$11	$300

LongTerm_Debt_Scheduled_Debt_M

Long-Term Debt (Scheduled Debt Maturities) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Maturities of Long-term Debt [Abstract]	'	'
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$891	'
Long-term Debt, Maturities, Repayments of Principal in Year Two	476	'
Long-term Debt, Maturities, Repayments of Principal in Year Three	465	'
Long-term Debt, Maturities, Repayments of Principal in Year Four	9	'
Long-term Debt, Maturities, Repayments of Principal in Year Five	407	'
Long-term Debt, Maturities, Repayments of Principal after Year Five	5,846	'
Long-term Debt, Total	$8,094	$7,813

LongTerm_Debt_Details_Textuals

Long-Term Debt (Details Textuals) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Debt Instrument [Line Items]	'	'
Junior Subordinated Notes, Noncurrent	$480	$480
Junior Subordinated Debentures [Member]	'	'
Debt Instrument [Line Items]	'	'
Debt, Weighted Average Interest Rate	6.50%	'
Junior Subordinated Notes, Noncurrent	280	280
Junior Subordinated Debentures 1 [Member]	'	'
Debt Instrument [Line Items]	'	'
Debt, Weighted Average Interest Rate	5.25%	'
Junior Subordinated Notes, Noncurrent	$200	$200

Preferred_and_Preferenced_Secu2

Preferred and Preferenced Securities (Details) (USD $)	Dec. 31, 2013
DTE Energy [Member]	'
Preferred and Preferenced Securities [Line Items]	'
Preferred Stock, Par Value Per Share	$0
Preferred Stock, Shares Authorized	5,000,000
DTE Electric [Member]	'
Preferred and Preferenced Securities [Line Items]	'
Preferred Stock, Par Value Per Share	$100
Preferred Stock, Shares Authorized	6,747,484
Preference Stock, Par Value Per Share	$1
Preference Stock, Shares Authorized	30,000,000
DTE Gas [Member]	'
Preferred and Preferenced Securities [Line Items]	'
Preferred Stock, Par Value Per Share	$1
Preferred Stock, Shares Authorized	7,000,000
Preference Stock, Par Value Per Share	$1
Preference Stock, Shares Authorized	4,000,000

ShortTerm_Credit_Arrangements_2

Short-Term Credit Arrangements and Borrowings (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Line Of Credit Facility [Line Items]	'
Line of Credit Facility, Maximum Borrowing Capacity	$1,975
Amounts outstanding	375
Net availability	1,600
DTE Energy [Member]	'
Line Of Credit Facility [Line Items]	'
Line of Credit Facility, Maximum Borrowing Capacity	1,375
Amounts outstanding	279
Net availability	1,096
DTE Electric [Member]	'
Line Of Credit Facility [Line Items]	'
Line of Credit Facility, Maximum Borrowing Capacity	300
Amounts outstanding	0
Net availability	300
DTE Gas [Member]	'
Line Of Credit Facility [Line Items]	'
Line of Credit Facility, Maximum Borrowing Capacity	300
Amounts outstanding	96
Net availability	204
Letter of Credit [Member]	'
Line Of Credit Facility [Line Items]	'
Amounts outstanding	244
Letter of Credit [Member] | DTE Energy [Member]	'
Line Of Credit Facility [Line Items]	'
Amounts outstanding	244
Letter of Credit [Member] | DTE Electric [Member]	'
Line Of Credit Facility [Line Items]	'
Amounts outstanding	0
Letter of Credit [Member] | DTE Gas [Member]	'
Line Of Credit Facility [Line Items]	'
Amounts outstanding	0
Letter of Credit [Member] | Unsecured letter of credit, expiring in May 2014 [Member]	'
Line Of Credit Facility [Line Items]	'
Line of Credit Facility, Maximum Borrowing Capacity	50
Letter of Credit [Member] | Unsecured letter of credit, expiring in May 2014 [Member] | DTE Energy [Member]	'
Line Of Credit Facility [Line Items]	'
Line of Credit Facility, Maximum Borrowing Capacity	50
Letter of Credit [Member] | Unsecured letter of credit, expiring in May 2014 [Member] | DTE Electric [Member]	'
Line Of Credit Facility [Line Items]	'
Line of Credit Facility, Maximum Borrowing Capacity	0
Letter of Credit [Member] | Unsecured letter of credit, expiring in May 2014 [Member] | DTE Gas [Member]	'
Line Of Credit Facility [Line Items]	'
Line of Credit Facility, Maximum Borrowing Capacity	0
Letter of Credit [Member] | Unsecured letter of credit, expiring in August 2015 [Member]	'
Line Of Credit Facility [Line Items]	'
Line of Credit Facility, Maximum Borrowing Capacity	125
Letter of Credit [Member] | Unsecured letter of credit, expiring in August 2015 [Member] | DTE Energy [Member]	'
Line Of Credit Facility [Line Items]	'
Line of Credit Facility, Maximum Borrowing Capacity	125
Letter of Credit [Member] | Unsecured letter of credit, expiring in August 2015 [Member] | DTE Electric [Member]	'
Line Of Credit Facility [Line Items]	'
Line of Credit Facility, Maximum Borrowing Capacity	0
Letter of Credit [Member] | Unsecured letter of credit, expiring in August 2015 [Member] | DTE Gas [Member]	'
Line Of Credit Facility [Line Items]	'
Line of Credit Facility, Maximum Borrowing Capacity	0
Revolving Credit Facility [Member] | Unsecured revolving credit facility, expiring April 2018 [Member]	'
Line Of Credit Facility [Line Items]	'
Line of Credit Facility, Maximum Borrowing Capacity	1,800
Revolving Credit Facility [Member] | Unsecured revolving credit facility, expiring April 2018 [Member] | DTE Energy [Member]	'
Line Of Credit Facility [Line Items]	'
Line of Credit Facility, Maximum Borrowing Capacity	1,200
Revolving Credit Facility [Member] | Unsecured revolving credit facility, expiring April 2018 [Member] | DTE Electric [Member]	'
Line Of Credit Facility [Line Items]	'
Line of Credit Facility, Maximum Borrowing Capacity	300
Revolving Credit Facility [Member] | Unsecured revolving credit facility, expiring April 2018 [Member] | DTE Gas [Member]	'
Line Of Credit Facility [Line Items]	'
Line of Credit Facility, Maximum Borrowing Capacity	300
Commercial Paper [Member]	'
Line Of Credit Facility [Line Items]	'
Amounts outstanding	131
Commercial Paper [Member] | DTE Energy [Member]	'
Line Of Credit Facility [Line Items]	'
Amounts outstanding	35
Commercial Paper [Member] | DTE Electric [Member]	'
Line Of Credit Facility [Line Items]	'
Amounts outstanding	0
Commercial Paper [Member] | DTE Gas [Member]	'
Line Of Credit Facility [Line Items]	'
Amounts outstanding	$96

ShortTerm_Credit_Arrangements_3

Short-Term Credit Arrangements and Borrowings (Details Textuals) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified	banks
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	'
Letters of Credit Outstanding, Amount	$375	'
Short-term Debt, Weighted Average Interest Rate	0.20%	0.40%
DTE Energy [Member]	'	'
Short-term Debt [Line Items]	'	'
Total Funded Debt to Total Capitalization Ratio	0.48	'
Letters of Credit Outstanding, Amount	279	'
DTE Electric [Member]	'	'
Short-term Debt [Line Items]	'	'
Total Funded Debt to Total Capitalization Ratio	0.5	'
Letters of Credit Outstanding, Amount	0	'
DTE Gas [Member]	'	'
Short-term Debt [Line Items]	'	'
Total Funded Debt to Total Capitalization Ratio	0.48	'
Letters of Credit Outstanding, Amount	96	'
Letter of Credit [Member]	'	'
Short-term Debt [Line Items]	'	'
Letters of Credit Outstanding, Amount	244	'
Letter of Credit [Member] | DTE Energy [Member]	'	'
Short-term Debt [Line Items]	'	'
Letters of Credit Outstanding, Amount	244	'
Letter of Credit [Member] | DTE Electric [Member]	'	'
Short-term Debt [Line Items]	'	'
Letters of Credit Outstanding, Amount	0	'
Letter of Credit [Member] | DTE Gas [Member]	'	'
Short-term Debt [Line Items]	'	'
Letters of Credit Outstanding, Amount	0	'
Letter of Credit [Member] | Other outstanding letters of credit [Member] | DTE Energy [Member]	'	'
Short-term Debt [Line Items]	'	'
Letters of Credit Outstanding, Amount	53	'
Letter of Credit [Member] | Demand Financing Agreement with Newedge letter of credit to raise capacity [Member] | DTE Energy [Member]	'	'
Short-term Debt [Line Items]	'	'
Borrowing Capacity Under Financing Agreement With iss Clearing Agent	50	'
Demand Financing Agreement with Newedge plus letter of credit [Member] | DTE Energy [Member]	'	'
Short-term Debt [Line Items]	'	'
Borrowing Capacity Under Financing Agreement With iss Clearing Agent	150	'
Demand Financing Agreement with Newedge [Member] | DTE Energy [Member]	'	'
Short-term Debt [Line Items]	'	'
Borrowing Capacity Under Financing Agreement With iss Clearing Agent	100	'
Maximum Additional Margin Financing	50	'
Financing Agreement, Amount Outstanding	$138	65

Capital_and_Operating_Leases_F

Capital and Operating Leases (Future Minimum Lease Payments under Non-Cancelable Leases) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Capital Leases of Lessee [Abstract]	'	'
Capital Leases, Future Minimum Payments Due, Next Twelve Months	$8	'
Capital Leases, Future Minimum Payments Due in Two Years	8	'
Capital Leases, Future Minimum Payments Due in Three Years	3	'
Capital Leases, Future Minimum Payments Due in Four Years	0	'
Capital Leases, Future Minimum Payments Due in Five Years	0	'
Capital Leases, Future Minimum Payments Due Thereafter	0	'
Capital Leases, Future Minimum Payments Due	19	'
Capital Leases, Less imputed interest	1	'
Capital Leases, Present value of net minimum lease payments	18	'
Capital Leases, Less current portion	7	'
Capital lease obligations	11	12
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]	'	'
Operating Leases, Future Minimum Payments Due, Next Twelve Months	35	'
Operating Leases, Future Minimum Payments Due in Two Years	31	'
Operating Leases, Future Minimum Payments, Due in Two Years	27	'
Operating Leases, Future Minimum Payments, Due in Four Years	25	'
Operating Leases, Future Minimum Payments, Due in Five Years	20	'
Operating Leases, Future Minimum Payments, Due Thereafter	92	'
Operating Leases, Future Minimum Payments Due	$230	'

Capital_and_Operating_Componen

Capital and Operating (Components of the Net Investment in the Capital Leases) (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Capital Leases of Lessor [Abstract]	'
Capital Leases, Future Minimum Payments Receivable, Next Twelve Months	$12
Capital Leases, Future Minimum Payments, Receivable in Two Years	12
Capital Leases, Future Minimum Payments, Receivable in Three Years	12
Capital Leases, Future Minimum Payments, Receivable in Four Years	12
Capital Leases, Future Minimum Payments, Receivable in Five Years	12
Capital Leases, Future Minimum Payments, Receivable Due Thereafter	19
Capital Leases, Future Minimum Payments Receivable, Total	79
Capital Leases, Residual value of leased pipeline	40
Capital Leases, Less unearned income	-40
Net Investment in Capital lease	79
Capital Leases, Less current portion	-5
Capital Leases, Lessor Balance Sheet, Net Investment in Direct Financing Leases, Noncurrent	$74

Capital_and_Operating_Leases_D

Capital and Operating Leases (Details Textuals) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Capital and Operating Leases [Abstract]	'	'	'
Operating Leases, Rent Expense	$34	$36	$40
Description of Lessor Leasing Arrangements, Capital Leases	'The Company leases a portion of its pipeline system to the Vector Pipeline through a capital lease contract that expires in 2020, with renewal options extending for five years. The Company owns a 40% interest in the Vector Pipeline. In addition, the Company has an energy services agreement, a portion of which is accounted for as a capital lease. The agreement expires in 2019, with a three or five year renewal option.	'	'

Commitments_and_Contingencies_2

Commitments and Contingencies (Details Textuals) (USD $)

12 Months Ended

12 Months Ended

12 Months Ended

3 Months Ended

9 Months Ended

12 Months Ended

12 Months Ended

Dec. 31, 2013

Aug. 31, 2013

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Mar. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

employees

dte_instances

Gas [Member]

Gas [Member]

Synthetic Fuel [Member]

Emissions [Member]

Other Guarantees [Member]

Electric [Member]

Electric [Member]

Electric [Member]

Electric [Member]

Electric [Member]

Eight Year [Member]

facilities

facilities

dte_instances

facilities

facilities

Electric [Member]

dte_instances

facilities

dte_instances

kWh

dte_instances

Loss Contingencies [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Environmental Capital Expenditures Through Current Year

'

'

'

'

'

'

'

'

'

'

'

$2,000,000,000

'

'

Estimated capital expenditures in next fiscal year

'

'

'

'

'

'

'

'

'

'

'

280,000,000

'

'

Environmental Capital Expenditures In Future Years

'

'

'

'

'

'

'

'

'

'

'

1,200,000,000

'

'

EPA is Alleging Power Plants Violated New Source Performance Standards

'

'

'

'

'

'

'

'

5

'

5

5

'

'

Number of NOVs/FOVs currently being discussed with the EPA

'

'

'

'

'

'

'

'

2

'

2

2

'

'

Sierra Club is Alleging DTE Electric Coal Fired Power Plants Violated the Clean Air Act

'

'

'

'

'

'

'

'

'

4

'

'

'

'

Exceedances of Opacity Standard

'

'

'

'

'

'

'

'

1,139

1,499

1,139

1,139

'

'

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

'

'

'

15

'

'

'

'

'

'

'

3

'

'

Accrued for remediation related to the sites

'

'

'

28,000,000

29,000,000

'

'

'

8,000,000

'

8,000,000

8,000,000

9,000,000

'

Number of Options to Regulate Coal Ash Residue

'

'

'

'

'

'

'

'

2

'

2

2

'

'

Period Gas Utility Can Amortize MGP Costs

'

'

'

'10 years

'

'

'

'

'

'

'

'

'

'

Number of NOVs

'

'

2

'

'

'

'

'

'

'

'

'

'

'

Possible Environmental Capital Expenditures to Comply with Requirements

3,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

EPA Sulfur Dioxide Ambient Air Quality Standard

'1 hour

'

'

'

'

'

'

'

'

'

'

'

'

'

Waiting Period of Policy

'P12W

'

'

'

'

'

'

'

'

'

'

'

'

'

Insurance Coverage for Extra Expense when Power Plant 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

'

1,000,000

1,000,000

'

'

Total Limit for Property Damage for Non-Nuclear Events

'

'

'

'

'

'

'

'

1,800,000,000

'

1,800,000,000

1,800,000,000

'

'

Limit of Coverage for Aggregate Extra Expenses for Non-Nuclear Events

'

'

'

'

'

'

'

'

'

'

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 Terroism 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 Terroist 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

'

48,000,000

48,000,000

'

'

Court of Appeals proposal to congress to reduce nuclear waste fee, amount

'

'

'

'

'

'

'

'

0

'

'

'

'

'

Time period after which the Court of Appeals proposal to Congress for nuclear waste fee reduction will take effect

'90 days

'

'

'

'

'

'

'

'

'

'

'

'

'

Days Obligations will Survive After Expiration of All Applicable Statutes of Limiations

'

'

'

'

'

'90 years

'90 days

'

'

'

'

'

'

'

Guarantor Obligations, Maximum Exposure, Undiscounted

'

'

'

'

'

1,100,000,000

144,000,000

60,000,000

'

'

'

'

'

'

Performance Bonds Outstanding

41,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of Represented Employees

4,900

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Purchase Commitment, Amount

8,598,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimated future capital expenditures for next year

2,300,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Bankruptcy Claims, Accounts Receivable under Review by Management

'

$20,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Commitments_and_Contingencies_3

Commitments and Contingencies (Purchase Commitments) (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Purchase Obligation, Fiscal Year Maturity [Abstract]	'
Purchase Obligation, Due in Next Twelve Months	$2,617
Purchase Obligation, Due in Second Year	1,195
Purchase Obligation, Due in Third Year	643
Purchase Obligation, Due in Fourth Year	345
Purchase Obligation, Due in Fifth Year	311
Purchase Obligation, Due after Fifth Year	3,487
Long-term Purchase Commitment, Amount	$8,598

Retirement_Benefits_and_Truste2

Retirement Benefits and Trusteed Assets (Pension Plan - Pension Cost Inclusions) (Details) (Pension Plan, Defined Benefit [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Pension Plan, Defined Benefit [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Service cost	$94	$82	$69
Interest cost	192	204	202
Expected return on plan assets	-266	-244	-246
Amortization of Net Loss	208	176	142
Amortization of Prior Service Cost (Credit)	0	0	3
Special termination benefits	0	2	2
Net pension or postretirement cost (benefit)	$228	$220	$172

Retirement_Benefits_and_Truste3

Retirement Benefits and Trusteed Assets (Pension Plan - Other Changes in Plan Assets and Benefit Obligations recognized in Reg Assets and OCI) (Details) (Pension Plan, Defined Benefit [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Pension Plan, Defined Benefit [Member]	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Net actuarial loss	($581)	$395
Amortization of net actuarial loss	-208	-178
Total recognized Regulatory assets and Other comprehensive income	-789	217
Total recognized in net periodic pension cost, Regulatory assets and Other comprehensive income	-561	437
Future amortization of net actuarial loss into net periodic benefit cost	$151	$202

Retirement_Benefits_and_Truste4

Retirement Benefits and Trusteed Assets (Pension Plan - Reconciliation of Obligations, Assets and Funded Status of Plans) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]	'	'	'
Regulatory Assets	$2,863	$4,417	'
Pension Plan, Defined Benefit [Member]	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]	'	'	'
Accumulated benefit obligation, end of year	4,068	4,349	'
Benefit obligation, beginning of year	4,729	4,195	'
Service cost	94	82	69
Interest cost	192	204	202
Plan amendments	-3	0	'
Actuarial loss	-400	474	'
Special termination benefits	0	2	2
Benefits paid	-232	-228	'
Benefit obligation, end of year	4,380	4,729	4,195
Plan assets at fair value, beginning of the year	3,223	2,886	'
Actual return on plan assets	445	325	'
Company contributions	284	240	'
Plan assets at fair value, end of the year	3,720	3,223	2,886
Funded status of the plans	-660	-1,506	'
Current liabilities	-7	-8	'
Noncurrent liabilities	-653	-1,498	'
Pension and Other Postretirement Defined Benefit Plans, Liabilities	-660	-1,506	'
Net actuarial loss recognized in other comprehensive loss	174	205	'
Prior service cost (credit) recognized in other comprehensive income	-1	-2	'
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax	173	203	'
Net actuarial loss recognized in regulatory assets	1,654	2,413	'
Prior service cost recognized in regulatory assets	6	7	'
Regulatory Assets	$1,660	$2,420	'

Retirement_Benefits_and_Truste5

Retirement Benefits and Trusteed Assets (Pension Plan - Benefits related to Qualified and Nonqualified Pension Plans Expected to be paid in the Next Ten Years) (Details) (Pension Plan, Defined Benefit [Member], USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Pension Plan, Defined Benefit [Member]	'
Pension Benefits to be Paid Over the Next 5 Years and Thereafter [Line Items]	'
Defined Benefit Plan, Expected Future Benefit Payments in next twelve months	$242
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	250
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	258
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	268
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	280
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	1,529
Total Defined Benefit Pension Plan Expected Future Payments	$2,827

Retirement_Benefits_and_Truste6

Retirement Benefits and Trusteed Assets (Pension Plan - Assumptions used in Determining the PBO and Net Pension Costs) (Details) (Pension Plan, Defined Benefit [Member])	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Pension Plan, Defined Benefit [Member]	'	'	'
Assumptions Used to Determin Projected Benefit Obligations and Net Pension Costs [Line Items]	'	'	'
Assumptions Used Calculating Benefit Obligation, Discount Rate	4.95%	4.15%	5.00%
Assumptions Used Calculating Benefit Obligation, Rate of compensation increase	4.20%	4.20%	4.20%
Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.15%	5.00%	5.50%
Assumptions Used Calculating Net Periodic Benefit Cost, Rate of compensation increase	4.20%	4.20%	4.00%
Assumptions Used Calculating Net Periodic Benefit Cost, Expected long-term rate of return on plan assets	8.25%	8.25%	8.50%

Retirement_Benefits_and_Truste7

Retirement Benefits and Trusteed Assets (Pension Plan - Target Allocations of Plan Assets) (Details) (Pension Plan, Defined Benefit [Member])	12 Months Ended
	Dec. 31, 2013
Pension Plan Target Allocations of Plan Assets [Line Items]	'
Target Allocation Percentage of Assets	'1
US Large Cap Equity Securities [Member]	'
Pension Plan Target Allocations of Plan Assets [Line Items]	'
Target Allocation Percentage of Assets	'0.22
US Small Cap and Mid Cap Equity Securities [Member]	'
Pension Plan Target Allocations of Plan Assets [Line Items]	'
Target Allocation Percentage of Assets	'0.05
Non US Equity Securities [Member]	'
Pension Plan Target Allocations of Plan Assets [Line Items]	'
Target Allocation Percentage of Assets	'0.2
Fixed Income Securities [Member]	'
Pension Plan Target Allocations of Plan Assets [Line Items]	'
Target Allocation Percentage of Assets	'0.25
Hedge Funds and Similar Investments [Member]	'
Pension Plan Target Allocations of Plan Assets [Line Items]	'
Target Allocation Percentage of Assets	'0.2
Private Equity and Other [Member]	'
Pension Plan Target Allocations of Plan Assets [Line Items]	'
Target Allocation Percentage of Assets	'0.08

Retirement_Benefits_and_Truste8

Retirement Benefits and Trusteed Assets (Pension Plan - Fair Value Measurements) (Details) (Pension Plan, Defined Benefit [Member], USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Millions, unless otherwise specified
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	$3,720	$3,223	$2,886
Fair Value, Inputs, Level 1 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	2,034	1,667	'
Fair Value, Inputs, Level 2 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	1,121	1,038	'
Fair Value, Inputs, Level 3 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	565	518	'
Short-term investments [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	22	24	'
Short-term investments [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	22	0	'
Short-term investments [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	24	'
Short-term investments [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
US Large Cap Equity Securities [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	896	732	'
US Large Cap Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	896	688	'
US Large Cap Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	44	'
US Large Cap Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
US Small Cap and Mid Cap Equity Securities [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	221	158	'
US Small Cap and Mid Cap Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	221	153	'
US Small Cap and Mid Cap Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	5	'
US Small Cap and Mid Cap Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Non US Equity Securities [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	741	650	'
Non US Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	611	530	'
Non US Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	130	120	'
Non US Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Fixed income securities [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	937	852	'
Fixed income securities [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	16	87	'
Fixed income securities [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	921	765	'
Fixed income securities [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Hedge Funds and Similar Investments [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	733	628	'
Hedge Funds and Similar Investments [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	268	209	'
Hedge Funds and Similar Investments [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	70	80	'
Hedge Funds and Similar Investments [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	395	339	'
Private Equity and Other [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	170	179	'
Private Equity and Other [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Private Equity and Other [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Private Equity and Other [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	$170	$179	'

Retirement_Benefits_and_Truste9

Retirement Benefits and Trusteed Assets (Pension Plan - Fair Value Measurement using Level 3 Inputs) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plans Fair Value Measurements Using Significant Unobservale Inputs [Line Items]	'	'
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	($1)	$58
Pension Plan, Defined Benefit [Member]	'	'
Defined Benefit Plans Fair Value Measurements Using Significant Unobservale Inputs [Line Items]	'	'
Beginning Balance	518	464
Realized gains (losses)	18	12
Unrealized gains (losses)	26	7
Purchases	31	283
Sales	-28	-248
Ending Balance	565	518
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	41	22
Pension Plan, Defined Benefit [Member] | Hedge Funds and Similar Investments [Member]	'	'
Defined Benefit Plans Fair Value Measurements Using Significant Unobservale Inputs [Line Items]	'	'
Beginning Balance	339	296
Realized gains (losses)	0	18
Unrealized gains (losses)	40	-5
Purchases	16	250
Sales	0	-220
Ending Balance	395	339
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	38	16
Pension Plan, Defined Benefit [Member] | Private Equity and Other [Member]	'	'
Defined Benefit Plans Fair Value Measurements Using Significant Unobservale Inputs [Line Items]	'	'
Beginning Balance	179	168
Realized gains (losses)	18	-6
Unrealized gains (losses)	-14	12
Purchases	15	33
Sales	-28	-28
Ending Balance	170	179
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	$3	$6

Recovered_Sheet1

Retirement Benefits and Trusteed Assets (OPEB - Postretirement Cost Inclusions) (Details) (Other Postretirement Benefit Plan, Defined Benefit [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Other Postretirement Benefit Plan, Defined Benefit [Member]	'	'	'
Other Postretirement Costs [Line Items]	'	'	'
Service cost	$47	$68	$64
Interest cost	88	120	121
Expected return on plan assets	-110	-92	-94
Amortization of Net Loss	64	80	55
Amortization of Prior Service Cost (Credit)	-131	-27	-26
Amortization of net transition asset	0	2	2
Net pension or postretirement cost (benefit)	($42)	$151	$122

Recovered_Sheet2

Retirement Benefits and Trusteed Assets (OPEB - Other Changes in Plan Assets and APBO Recognized in Regulatory Assets and OCI) (Details) (Other Postretirement Benefit Plan, Defined Benefit [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Other Postretirement Benefit Plan, Defined Benefit [Member]	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Net actuarial loss	($353)	($34)
Amortization of net actuarial loss	-64	-80
Prior service credit	-218	-264
Amortization of prior service cost	131	27
Amortization of transition asset	0	-2
Total recognized Regulatory assets and Other comprehensive income	-504	-353
Total recognized in net periodic pension cost, Regulatory assets and Other comprehensive icnome	-546	-202
Future amortization of net actuarial loss into net periodic benefit cost	21	69
Future amortization of prior service credit into net periodic benefit cost	($144)	($91)

Recovered_Sheet3

Retirement Benefits and Trusteed Assets (OPEB - Reconciliation of Obligations, Assets and Funded Status of Plans) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Change in Accumulated PostRetirement Benefit Obligation [Line Items]	'	'	'
Regulatory Liabilities	($1,164)	($1,120)	'
Regulatory Assets	2,863	4,417	'
Other Postretirement Benefit Plan, Defined Benefit [Member]	'	'	'
Change in Accumulated PostRetirement Benefit Obligation [Line Items]	'	'	'
Benefit obligation, beginning of year	2,315	2,470	'
Service cost	47	68	64
Interest cost	88	120	121
Plan amendments	-218	-264	'
Actuarial loss	-267	5	'
Medicare Part D subsidy	1	6	'
Benefits paid	-88	-90	'
Benefit obligation, end of year	1,878	2,315	2,470
Defined Benefit Plan, Fair Value of Plan Assets	1,527	1,153	985
Actual return on plan assets	196	131	'
Company contributions	264	140	'
Benefits paid	-86	-103	'
Funded status of the plans	-351	-1,162	'
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities	-1	-2	'
Noncurrent liabilities	-350	-1,160	'
Pension and Other Postretirement Defined Benefit Plans, Liabilities	-351	-1,162	'
Net actuarial loss recognized in other comprehensive loss	29	40	'
Prior service cost (credit) recognized in other comprehensive income	-10	-14	'
Net transition obligation	0	-1	'
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax	19	25	'
Net actuarial loss recognized in regulatory assets	321	727	'
Prior service cost recognized in regulatory assets	-393	-302	'
Net transition obligation	0	1	'
Regulatory Liabilities	-72	'	'
Regulatory Assets	'	$426	'

Recovered_Sheet4

Retirement Benefits and Trusteed Assets (OPEB - Benefits related to Qualified and Nonqualified Pension Plans Expected to be paid in the Next Ten Years) (Details) (Other Postretirement Benefit Plan, Defined Benefit [Member], USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Other Postretirement Benefit Plan, Defined Benefit [Member]	'
Benefits Expected to be Paid Over the Next Five Years and Thereafter [Line Items]	'
Defined Benefit Plan, Expected Future Benefit Payments in next twelve months	$103
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	110
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	115
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	123
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	130
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	724
Total Expected Future Benefit Payments	$1,305

Recovered_Sheet5

Retirement Benefits and Trusteed Assets (OPEB - Assumptions used in Determining the PBO and Net Pension Costs) (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Mar. 31, 2013
Assumptions Used to Determine Projected Benefit Obligation and Benefit Costs [Line Items]	'	'	'	'
Health care trend rate pre and post 65	'	'	7.00%	'
Ultimate health care trend rate	'	'	5.00%	'
Other Postretirement Benefit Plan, Defined Benefit [Member]	'	'	'	'
Assumptions Used to Determine Projected Benefit Obligation and Benefit Costs [Line Items]	'	'	'	'
Assumptions Used Calculating Benefit Obligation, Discount Rate	4.95%	4.15%	5.00%	4.30%
Defined Benefit Plan Health Care Trend Rate Pre Sixty Five	7.50%	'	'	'
Defined Benefit Plan Health Care Trend Rate Post Sixty Five	6.50%	'	'	'
Health care trend rate pre and post 65	7.00%	7.00%	7.00%	'
Ultimate health care trend rate	'	5.00%	5.00%	'
Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.15%	'	'	'
Defined Benefit Plan Assumptions Used Calculating Other Postretirement Benefit Cost Discount Rate	'	5.00%	5.50%	'
Defined Benefit Plan Assumptions Used Calculating Other Postretirement Benefit Cost Discount Rate, post remeasurement	4.30%	'	'	'
Expected long-term rate of return on plan assets	8.25%	8.25%	8.75%	'
Accumulated postretirement benefit obligation [Member] | Other Postretirement Benefit Plan, Defined Benefit [Member]	'	'	'	'
Assumptions Used to Determine Projected Benefit Obligation and Benefit Costs [Line Items]	'	'	'	'
Ultimate health care trend rate	4.50%	'	'	'
Other postretirement benefit costs [Member] | Other Postretirement Benefit Plan, Defined Benefit [Member]	'	'	'	'
Assumptions Used to Determine Projected Benefit Obligation and Benefit Costs [Line Items]	'	'	'	'
Ultimate health care trend rate	5.00%	'	'	'

Recovered_Sheet6

Retirement Benefits and Trusteed Assets (OPEB - Target Allocations of Plan Assets) (Details) (Other Postretirement Benefit Plan, Defined Benefit [Member])	12 Months Ended
	Dec. 31, 2013
Other Postretirement Benefits Target Allocations of Plan Assets [Line Items]	'
Target Allocation Percentage of Assets	'1
US Large Cap Equity Securities [Member]	'
Other Postretirement Benefits Target Allocations of Plan Assets [Line Items]	'
Target Allocation Percentage of Assets	'0.17
US Small Cap and Mid Cap Equity Securities [Member]	'
Other Postretirement Benefits Target Allocations of Plan Assets [Line Items]	'
Target Allocation Percentage of Assets	'0.04
Non US Equity Securities [Member]	'
Other Postretirement Benefits Target Allocations of Plan Assets [Line Items]	'
Target Allocation Percentage of Assets	'0.2
Fixed Income Securities [Member]	'
Other Postretirement Benefits Target Allocations of Plan Assets [Line Items]	'
Target Allocation Percentage of Assets	'0.25
Hedge Funds and Similar Investments [Member]	'
Other Postretirement Benefits Target Allocations of Plan Assets [Line Items]	'
Target Allocation Percentage of Assets	'0.2
Private Equity and Other [Member]	'
Other Postretirement Benefits Target Allocations of Plan Assets [Line Items]	'
Target Allocation Percentage of Assets	'0.14

Recovered_Sheet7

Retirement Benefits and Trusteed Assets (OPEB - Fair Value Measurements) (Details) (Other Postretirement Benefit Plan, Defined Benefit [Member], USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Millions, unless otherwise specified
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	$1,527	$1,153	$985
Fair Value, Inputs, Level 1 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	883	665	'
Fair Value, Inputs, Level 2 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	384	283	'
Fair Value, Inputs, Level 3 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	260	205	'
Short-term investments [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	5	3	'
Short-term investments [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	5	1	'
Short-term investments [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	2	'
Short-term investments [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
US Large Cap Equity Securities [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	302	192	'
US Large Cap Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	302	189	'
US Large Cap Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	3	'
US Large Cap Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
US Small Cap and Mid Cap Equity Securities [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	147	105	'
US Small Cap and Mid Cap Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	147	105	'
US Small Cap and Mid Cap Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
US Small Cap and Mid Cap Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Non US Equity Securities [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	291	237	'
Non US Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	282	230	'
Non US Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	9	7	'
Non US Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Fixed income securities [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	367	285	'
Fixed income securities [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	17	38	'
Fixed income securities [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	350	247	'
Fixed income securities [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Hedge Funds and Similar Investments [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	314	245	'
Hedge Funds and Similar Investments [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	130	102	'
Hedge Funds and Similar Investments [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	25	24	'
Hedge Funds and Similar Investments [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	159	119	'
Private Equity and Other [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	101	86	'
Private Equity and Other [Member] | Fair Value, Inputs, Level 1 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Private Equity and Other [Member] | Fair Value, Inputs, Level 2 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	0	0	'
Private Equity and Other [Member] | Fair Value, Inputs, Level 3 [Member]	'	'	'
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items]	'	'	'
Defined Benefit Plan, Fair Value of Plan Assets	$101	$86	'

Recovered_Sheet8

Retirement Benefits and Trusteed Assets (OPEB - Fair Value Measurements using Level 3 Inputs) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plans Fair Value Measurements Using Significant Unobservale Inputs [Line Items]	'	'
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	($1)	$58
Other Postretirement Benefit Plan, Defined Benefit [Member]	'	'
Defined Benefit Plans Fair Value Measurements Using Significant Unobservale Inputs [Line Items]	'	'
Beginning Balance	205	155
Realized gains (losses)	2	-5
Unrealized gains (losses)	21	14
Purchases	41	122
Sales	-9	-81
Ending Balance	260	205
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	23	8
Other Postretirement Benefit Plan, Defined Benefit [Member] | Hedge Funds and Similar Investments [Member]	'	'
Defined Benefit Plans Fair Value Measurements Using Significant Unobservale Inputs [Line Items]	'	'
Beginning Balance	119	95
Realized gains (losses)	0	6
Unrealized gains (losses)	14	0
Purchases	26	86
Sales	0	-68
Ending Balance	159	119
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	14	6
Other Postretirement Benefit Plan, Defined Benefit [Member] | Private Equity and Other [Member]	'	'
Defined Benefit Plans Fair Value Measurements Using Significant Unobservale Inputs [Line Items]	'	'
Beginning Balance	86	60
Realized gains (losses)	2	-11
Unrealized gains (losses)	7	14
Purchases	15	36
Sales	-9	-13
Ending Balance	101	86
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	$9	$2

Recovered_Sheet9

Retirement Benefits and Trusteed Assets (Details Textuals) (USD $)	3 Months Ended	12 Months Ended
	Mar. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'	'
Company Contribution to Employee Savings Plan	'	4.00%	'	'
Company Retiree New Coverage Minimum	'	$3,250	'	'
Company Retiree New Coverage Maximum	'	3,500	'	'
Retiree Health Care Allowance will increase at lower of the rate of medical inflation or a set percentage	'	2.00%	'	'
Retiree Health Care Allowance	3,250	'	'	'
Prescription Drug Benefit, Effect of Subsidy on Net Periodic Postretirement Benefit Cost	'	1,000,000	6,000,000	6,000,000
Grantor Trust Balance	'	17,000,000	14,000,000	'
Defined Contribution Plan, Cost Recognized	'	41,000,000	37,000,000	35,000,000
Pension Plan, Defined Benefit [Member]	'	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'	'
Company contributions	'	284,000,000	240,000,000	'
Estimated Future Employer Contributions in Next Fiscal Year	'	345,000,000	'	'
Defined Benefit Plan, Expected Return on Plan Assets	'	7.75%	'	'
Transfers between Level 3 and Level 2	'	0	0	'
Transfers between Level 2 and Level 1	'	0	0	'
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	'	4.95%	4.15%	5.00%
Other Postretirement Benefit Plan, Defined Benefit [Member]	'	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'	'
Company contributions	'	264,000,000	140,000,000	'
Estimated Future Employer Contributions in Next Fiscal Year	'	145,000,000	'	'
Defined Benefit Plan, Expected Return on Plan Assets	'	8.00%	'	'
Transfers between Level 3 and Level 2	'	0	0	'
Transfers between Level 2 and Level 1	'	0	0	'
Defined Benefit Plan, Effect of One Percentage Point Increase on Service and Interest Cost Components	'	9,000,000	'	'
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation	'	124,000,000	'	'
Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components	'	8,000,000	'	'
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation	'	108,000,000	'	'
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.30%	4.95%	4.15%	5.00%
Retiree Healthcare Plan [Member]	'	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'	'
Defined Contribution Plan, Cost Recognized	'	2,000,000	0	'
DTE Gas Represented Employees [Member]	'	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'	'
Company Contribution to Employee Savings Plan	'	8.00%	'	'
Qualified Plans [Member] | Pension Plan, Defined Benefit [Member]	'	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'	'
Company contributions	'	$277,000,000	'	'

StockBased_Compensation_Stock_

Stock-Based Compensation (Stock based compensation by period) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'	'
Stock-based compensation expense	$99	$83	$66
Tax benefit	38	33	25
Stock-based compensation cost capitalized in property, plant and equipment	$15	$5	$4

StockBased_Compensation_Stock_1

Stock-Based Compensation (Stock Option Activity) (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'
Options outstanding at beginning of period	1,192,670
Granted	0
Exercised	-458,603
Forfeitured and expired	-10,370
Options outstanding and exercisable at end of period	723,697
Weighted Average Exercise Price Per Share - Options outstanding at beginning of period	$41.86
Weighted Average Exercise Price Per Share - Granted	$0
Weighted Average Exercise Price Per Share - Exercised	$40.71
Weighted Average Exercise Price Per Share - Forfeitured or expired	$41.46
Weighted Average Exercise Price Per Share - Options outstanding and exercisable at end of period	$42.60
Aggregate Intrinsic Value - Options outstanding and exercisable at end of period	$18

StockBased_Compensation_Number

Stock-Based Compensation (Number, Weighted Average Exercise Price and Weighted Average Remaining Contractual Life of Options Outstanding) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'
Number of Options	723,697
Weighted Average Exercise Price	$42.60
Weighted Average Remaining Contractual Life (Years)	'3 years 10 months
Exercise Price Range One [Member]	'
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'
Range of Exercise Prices Lower Limit	$27
Range of Exercise Prices Upper Limit	$38
Number of Options	67,257
Weighted Average Exercise Price	$28.30
Weighted Average Remaining Contractual Life (Years)	'5 years 1 month 23 days
Exercise Price Range Two [Member]	'
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'
Range of Exercise Prices Lower Limit	$38.01
Range of Exercise Prices Upper Limit	$42
Number of Options	167,447
Weighted Average Exercise Price	$41.23
Weighted Average Remaining Contractual Life (Years)	'3 years 2 months 15 days
Exercise Price Range Three [Member]	'
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'
Range of Exercise Prices Lower Limit	$42.01
Range of Exercise Prices Upper Limit	$45
Number of Options	351,893
Weighted Average Exercise Price	$44.02
Weighted Average Remaining Contractual Life (Years)	'4 years 1 month 27 days
Exercise Price Range Four [Member]	'
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]	'
Range of Exercise Prices Lower Limit	$45.01
Range of Exercise Prices Upper Limit	$50
Number of Options	137,100
Weighted Average Exercise Price	$47.67
Weighted Average Remaining Contractual Life (Years)	'3 years 1 month

StockBased_Compensation_Stock_2

Stock-Based Compensation (Stock Award Activity) (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Stock Award Activity [Line Items]	'	'	'
Compensation cost charged against income (in millions)	$99	$83	$66
Restricted Stock [Member]	'	'	'
Stock Award Activity [Line Items]	'	'	'
Fair value of awards vested (in millions)	8	9	13
Restricted common shares awarded	127,785	167,320	381,840
Weighted average market price of shares awarded	$64.72	$53.71	$47.98
Compensation cost charged against income (in millions)	$23	$12	$12

Stock_BasedCompensation_Stock_

Stock Based-Compensation (Stock Awards Activity Rollforward) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'
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, Non-Option Equity Instruments, Outstanding, Number	597,648	'	'
Grants	127,785	167,320	381,840
Forfeitures	-7,155	'	'
Vested and Issued	-225,949	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number	492,329	597,648	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$48.33	'	'
Weighted Average Grant Date Fair Value Per Share - Grants	$64.72	$53.71	$47.98
Weighted Average Grant Date Fair Value Per Share - Foreitures	$54.61	'	'
Weighted Average Grant Date Fair Value Per Share - Vested and issued	$45.54	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$53.76	$48.33	'

StockBased_Compensation_Perfor

Stock-Based Compensation (Performance Share Awards Compensation Expense) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Compensation Expense Recorded [Line Items]	'	'	'
Compensation expense	$99	$83	$66
Performance Shares [Member]	'	'	'
Compensation Expense Recorded [Line Items]	'	'	'
Compensation expense	77	71	53
Cash settlements	9	4	3
Stock settlements	$56	$41	$25

StockBased_Compensation_Perfor1

Stock-Based Compensation (Performance Share Awards Activity) (Details)	12 Months Ended
	Dec. 31, 2013
Performance Share Awards [Line Items]	'
Forfeitures	-10,370
Performance Shares [Member]	'
Performance Share Awards [Line Items]	'
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number	1,634,364
Grants	564,561
Forfeitures	-41,512
Performance Shares - Payouts	-548,624
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number	1,608,789

StockBased_Compensation_Unreco

Stock-Based Compensation (Unrecognized Compensation Costs) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Share Based Compensation Unrecognized and Non-Vested Cost [Line Items]	'
Unrecognized Compensation Cost	$55
Weighted Average to be Recognized	'11 months 5 days
Restricted Stock [Member]	'
Share Based Compensation Unrecognized and Non-Vested Cost [Line Items]	'
Unrecognized Compensation Cost	10
Weighted Average to be Recognized	'11 months 5 days
Performance Shares [Member]	'
Share Based Compensation Unrecognized and Non-Vested Cost [Line Items]	'
Unrecognized Compensation Cost	$45
Weighted Average to be Recognized	'11 months 5 days

StockBased_Compensation_Detail

Stock-Based Compensation (Details Textuals) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Schedule of Stock Based Compensation [Line Items]	'	'	'
Authorized limit of common stock shares	11,500,000	'	'
Performance Units Price per Unit	1	'	'
Expiration Period After Date of Grant	'10 years	'	'
Award Vesting Period	'3 years	'	'
Weighted Average Remaining Contractual Term	'3 years 9 months 30 days	'	'
Options, Vested, Number of Shares	200,844	'	'
Options, Grants in Period, Weighted Average Grant Date Fair Value	$0	'	'
Options, Exercises in Period, Total Intrinsic Value	$12	$25	$20
Stock or Unit Option Plan Expense	0	0.7	2
Unrecognized Compensation Cost	55	'	'
Weighted Average to be Recognized	'11 months 5 days	'	'
Employee Stock Option [Member]	'	'	'
Schedule of Stock Based Compensation [Line Items]	'	'	'
Maximum Award Per Employee	500,000	'	'
Restricted Stock [Member]	'	'	'
Schedule of Stock Based Compensation [Line Items]	'	'	'
Maximum Award Per Employee	150,000	'	'
Unrecognized Compensation Cost	10	'	'
Weighted Average to be Recognized	'11 months 5 days	'	'
Performance Shares [Member]	'	'	'
Schedule of Stock Based Compensation [Line Items]	'	'	'
Maximum Award Per Employee	300,000	'	'
Unrecognized Compensation Cost	$45	'	'
Weighted Average to be Recognized	'11 months 5 days	'	'
Performance Unit [Member]	'	'	'
Schedule of Stock Based Compensation [Line Items]	'	'	'
Maximum Award Per Employee	1,000,000	'	'

Segment_Information_Details_Te

Segment Information (Details Textuals)	Dec. 31, 2013
	customers
Segment Reporting [Abstract]	'
Number of Electric Utility Customers	2,100,000
Number of Gas Utility Customers	1,200,000
Number of Citizens Gas Customers	17,000

Segment_Information_Intersegme

Segment Information (Inter-segment billing) (Details) (Intersegment Eliminations [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Inter-Segment Revenue [Line Items]	'	'	'
Revenue, Net	$868	$848	$301
Electric [Member]	'	'	'
Inter-Segment Revenue [Line Items]	'	'	'
Revenue, Net	26	29	33
Gas [Member]	'	'	'
Inter-Segment Revenue [Line Items]	'	'	'
Revenue, Net	4	4	2
Gas Storage and Pipelines [Member]	'	'	'
Inter-Segment Revenue [Line Items]	'	'	'
Revenue, Net	3	6	8
Power and Industrial Projects [Member]	'	'	'
Inter-Segment Revenue [Line Items]	'	'	'
Revenue, Net	816	801	238
Energy Trading [Member]	'	'	'
Inter-Segment Revenue [Line Items]	'	'	'
Revenue, Net	43	43	70
Corporate and Other [Member]	'	'	'
Inter-Segment Revenue [Line Items]	'	'	'
Revenue, Net	-24	-37	-50
Discontinued Operations [Member]	'	'	'
Inter-Segment Revenue [Line Items]	'	'	'
Revenue, Net	$0	$2	$0

Segment_Information_Financial_

Segment Information (Financial Data) (Details) (USD $)	3 Months Ended								12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenue	$2,533	$2,387	$2,225	$2,516	$2,349	$2,190	$2,013	$2,239	$9,661	$8,791	$8,858
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	1,094	1,018	995
Interest Income	'	'	'	'	'	'	'	'	-9	'	'
Interest Expense	'	'	'	'	'	'	'	'	436	440	488
Income Taxes	'	'	'	'	'	'	'	'	254	286	268
Net Income Attributable to DTE Energy Company	124	198	105	234	81	227	146	156	661	610	711
Total Assets	25,935	'	'	'	26,339	'	'	'	25,935	26,339	26,009
Goodwill	2,018	'	'	'	2,018	'	'	'	2,018	2,018	2,020
Capital Expenditures	'	'	'	'	'	'	'	'	1,876	1,820	1,484
Electric [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	902	827	818
Interest Income	'	'	'	'	'	'	'	'	-1	-1	-1
Interest Expense	'	'	'	'	'	'	'	'	268	272	289
Income Taxes	'	'	'	'	'	'	'	'	252	280	265
Net Income Attributable to DTE Energy Company	'	'	'	'	'	'	'	'	484	483	434
Total Assets	17,508	'	'	'	17,755	'	'	'	17,508	17,755	17,567
Goodwill	1,208	'	'	'	1,208	'	'	'	1,208	1,208	1,208
Capital Expenditures	'	'	'	'	'	'	'	'	1,325	1,230	1,203
Gas [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	95	92	89
Interest Income	'	'	'	'	'	'	'	'	-7	-7	-7
Interest Expense	'	'	'	'	'	'	'	'	58	59	64
Income Taxes	'	'	'	'	'	'	'	'	77	50	60
Net Income Attributable to DTE Energy Company	'	'	'	'	'	'	'	'	143	115	110
Total Assets	3,938	'	'	'	4,059	'	'	'	3,938	4,059	4,065
Goodwill	743	'	'	'	745	'	'	'	743	745	745
Capital Expenditures	'	'	'	'	'	'	'	'	209	221	179
Gas Storage and Pipelines [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	23	8	6
Interest Income	'	'	'	'	'	'	'	'	-7	-8	-5
Interest Expense	'	'	'	'	'	'	'	'	18	8	7
Income Taxes	'	'	'	'	'	'	'	'	45	39	35
Net Income Attributable to DTE Energy Company	'	'	'	'	'	'	'	'	70	61	57
Total Assets	824	'	'	'	668	'	'	'	824	668	538
Goodwill	24	'	'	'	22	'	'	'	24	22	22
Capital Expenditures	'	'	'	'	'	'	'	'	245	233	16
Power and Industrial Projects [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	72	65	60
Interest Income	'	'	'	'	'	'	'	'	-6	-7	-8
Interest Expense	'	'	'	'	'	'	'	'	27	37	32
Income Taxes	'	'	'	'	'	'	'	'	-45	-44	11
Net Income Attributable to DTE Energy Company	'	'	'	'	'	'	'	'	66	42	38
Total Assets	1,067	'	'	'	991	'	'	'	1,067	991	789
Goodwill	26	'	'	'	26	'	'	'	26	26	26
Capital Expenditures	'	'	'	'	'	'	'	'	93	83	56
Energy Trading [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	1	2	3
Interest Income	'	'	'	'	'	'	'	'	0	0	0
Interest Expense	'	'	'	'	'	'	'	'	8	8	9
Income Taxes	'	'	'	'	'	'	'	'	-38	7	34
Net Income Attributable to DTE Energy Company	'	'	'	'	'	'	'	'	-58	12	52
Total Assets	623	'	'	'	629	'	'	'	623	629	612
Goodwill	17	'	'	'	17	'	'	'	17	17	17
Capital Expenditures	'	'	'	'	'	'	'	'	3	1	1
Corporate and Other [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	1	1	1
Interest Income	'	'	'	'	'	'	'	'	-51	-52	-47
Interest Expense	'	'	'	'	'	'	'	'	120	121	145
Income Taxes	'	'	'	'	'	'	'	'	-37	-46	-136
Net Income Attributable to DTE Energy Company	'	'	'	'	'	'	'	'	-44	-47	23
Total Assets	2,945	'	'	'	3,074	'	'	'	2,945	3,074	2,605
Goodwill	0	'	'	'	0	'	'	'	0	0	0
Capital Expenditures	'	'	'	'	'	'	'	'	1	3	0
Intersegment Eliminations [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	0	0	0
Interest Income	'	'	'	'	'	'	'	'	63	65	58
Interest Expense	'	'	'	'	'	'	'	'	-63	-65	-58
Income Taxes	'	'	'	'	'	'	'	'	0	0	-1
Net Income Attributable to DTE Energy Company	'	'	'	'	'	'	'	'	0	0	0
Total Assets	-970	'	'	'	-837	'	'	'	-970	-837	-485
Goodwill	0	'	'	'	0	'	'	'	0	0	0
Capital Expenditures	'	'	'	'	'	'	'	'	0	0	0
Segment, Continuing Operations [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Depreciation, Depletion and Amortization	'	'	'	'	'	'	'	'	'	995	977
Interest Income	'	'	'	'	'	'	'	'	'	-10	-10
Interest Expense	'	'	'	'	'	'	'	'	'	440	488
Income Taxes	'	'	'	'	'	'	'	'	'	286	268
Net Income Attributable to DTE Energy Company	'	'	'	'	'	'	'	'	'	666	714
Total Assets	'	'	'	'	26,339	'	'	'	'	26,339	25,691
Goodwill	'	'	'	'	2,018	'	'	'	'	2,018	2,018
Capital Expenditures	'	'	'	'	'	'	'	'	'	1,771	1,455
Segment, Discontinued Operations [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Net Income Attributable to DTE Energy Company	'	'	'	'	'	'	'	'	'	-56	-3
Total Assets	'	'	'	'	0	'	'	'	'	0	318
Goodwill	'	'	'	'	0	'	'	'	'	0	2
Capital Expenditures	'	'	'	'	'	'	'	'	'	49	29
Operating Segments [Member] | Electric [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenue	'	'	'	'	'	'	'	'	5,199	5,293	5,154
Operating Segments [Member] | Gas [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenue	'	'	'	'	'	'	'	'	1,474	1,315	1,505
Operating Segments [Member] | Gas Storage and Pipelines [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenue	'	'	'	'	'	'	'	'	132	96	91
Operating Segments [Member] | Power and Industrial Projects [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenue	'	'	'	'	'	'	'	'	1,950	1,823	1,129
Operating Segments [Member] | Energy Trading [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenue	'	'	'	'	'	'	'	'	1,771	1,109	1,276
Operating Segments [Member] | Corporate and Other [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenue	'	'	'	'	'	'	'	'	3	3	4
Intersegment Eliminations [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Revenue, Net	'	'	'	'	'	'	'	'	-868	-848	-301
Intersegment Eliminations [Member] | Electric [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Revenue, Net	'	'	'	'	'	'	'	'	-26	-29	-33
Intersegment Eliminations [Member] | Gas [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Revenue, Net	'	'	'	'	'	'	'	'	-4	-4	-2
Intersegment Eliminations [Member] | Gas Storage and Pipelines [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Revenue, Net	'	'	'	'	'	'	'	'	-3	-6	-8
Intersegment Eliminations [Member] | Power and Industrial Projects [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Revenue, Net	'	'	'	'	'	'	'	'	-816	-801	-238
Intersegment Eliminations [Member] | Energy Trading [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Revenue, Net	'	'	'	'	'	'	'	'	-43	-43	-70
Intersegment Eliminations [Member] | Corporate and Other [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Revenue, Net	'	'	'	'	'	'	'	'	24	37	50
Intersegment Eliminations [Member] | Segment, Discontinued Operations [Member]	'	'	'	'	'	'	'	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Revenue, Net	'	'	'	'	'	'	'	'	$0	($2)	$0

Supplementary_Quarterly_Financ2

Supplementary Quarterly Financial Information (Unaudited) (Details) (USD $)	3 Months Ended								12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Quarterly Financial Information Disclosure [Abstract]	'	'	'	'	'	'	'	'	'	'	'
Operating Revenue	$2,533	$2,387	$2,225	$2,516	$2,349	$2,190	$2,013	$2,239	$9,661	$8,791	$8,858
Operating Income (Loss)	241	329	223	410	267	406	294	312	1,203	1,279	1,421
Income (Loss) from Continuing Operations Attributable to Parent	'	'	'	'	137	226	147	156	'	666	'
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent	'	'	'	'	-56	1	-1	0	0	-56	-3
Net Income Attributable to DTE Energy Company	$124	$198	$105	$234	$81	$227	$146	$156	$661	$610	$711
Income (Loss) from Continuing Operations, Per Basic Share	'	'	'	'	$0.79	$1.31	$0.87	$0.91	$3.76	$3.89	$4.21
Income (Loss) from Discontinued Operations, Net of Tax, Per Basic Share	'	'	'	'	($0.32)	$0.01	($0.01)	$0	$0	($0.33)	($0.02)
Total Basic Earnings per Common Share	$0.70	$1.13	$0.60	$1.35	$0.47	$1.32	$0.86	$0.91	$3.76	$3.56	$4.19
Income (Loss) from Continuing Operations, Per Diluted Share	'	'	'	'	$0.79	$1.30	$0.87	$0.91	$3.76	$3.88	$4.20
Income (Loss) from Discontinued Operations, Net of Tax, Per Diluted Share	'	'	'	'	($0.32)	$0.01	($0.01)	$0	$0	($0.33)	($0.02)
Total Diluted Earnings per Common Share	$0.70	$1.13	$0.60	$1.34	$0.47	$1.31	$0.86	$0.91	$3.76	$3.55	$4.18

Valuation_and_Qualifying_Accou2

Valuation and Qualifying Accounts Valuation and Qualifying Accounts (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Valuation and Qualifying Accounts [Abstract]	'	'	'
Balance at Beginning of Period	$62	$162	$196
Charged to cost and expenses	94	79	94
Charged to other accounts	23	16	18
Deductions	-124	-195	-146
Balance at End of Period	$55	$62	$162