DTE Electric 10-Q 25 Jul 14 2014 Q2 Quarterly report Financial data

Document_Entity_Information_Do

Document Entity Information Document	6 Months Ended
	Jun. 30, 2014
Entity Registrant Name	'DTE ELECTRIC CO
Entity Central Index Key	'0000028385
Current Fiscal Year End Date	'--12-31
Entity Filer Category	'Non-accelerated Filer
Document Type	'10-Q
Document Period End Date	30-Jun-14
Document Fiscal Year Focus	'2014
Document Fiscal Period Focus	'Q2
Amendment Flag	'false
Entity Common Stock, Shares Outstanding	138,632,324

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (Unaudited) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Income Statement [Abstract]	'	'	'	'
Operating Revenues	$1,281	$1,265	$2,691	$2,484
Operating Expenses	'	'	'	'
Fuel and purchased power	400	435	898	807
Operation and maintenance	329	343	671	674
Depreciation and amortization	229	221	457	433
Taxes other than income	65	63	136	133
Asset (gains) losses and reserves, net	-1	1	-1	0
Total operating expenses	1,022	1,063	2,161	2,047
Operating Income	259	202	530	437
Other (Income) and Deductions	'	'	'	'
Interest expense	61	68	124	134
Other income	-17	-9	-30	-24
Other expenses	8	6	15	12
Total Other (Income) and Deductions	52	65	109	122
Income Before Income Taxes	207	137	421	315
Income Tax Expense	77	47	154	109
Net Income	$130	$90	$267	$206

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (Unaudited) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Net Income	$130	$90	$267	$206
Other comprehensive income (loss), net of tax:	'	'	'	'
Benefit obligations, net of taxes of $1, $—, $— and $—, respectively	0	1	-1	1
Comprehensive income	$130	$91	$266	$207

Consolidated_Statements_of_Com1

Consolidated Statements of Comprehensive Income (Parentheticals) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Tax effect on benefit obligations	$1	$0	$0	$0

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (Unaudited) (USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Operating Activities	'	'
Net Income	$267	$206
Adjustments to reconcile net income to net cash from operating activities:	'	'
Depreciation and amortization	457	433
Nuclear fuel amortization	19	17
Allowance for equity funds used during construction	-11	-6
Deferred income taxes	145	61
Changes in assets and liabilities:	'	'
Accounts receivable, net	-14	-84
Inventories	-28	43
Accounts payable	10	18
Accrued pension liability — affiliates	-83	-134
Accrued postretirement liability — affiliates	-28	-138
Regulatory assets and liabilities	-152	217
Other assets	-53	11
Other liabilities	-34	-27
Net cash from operating activities	495	617
Investing Activities	'	'
Plant and equipment expenditures	-832	-607
Restricted cash for debt redemption, principally Securitization	12	12
Notes receivable from affiliate	200	-1
Proceeds from sale of nuclear decommissioning trust fund assets	475	309
Investments in nuclear decommissioning trust funds	-483	-317
Other Investments	-15	-15
Net cash used for investing activities	-643	-619
Financing Activities	'	'
Issuance of long-term debt, net of issuance costs	248	371
Redemption of long-term debt	-281	-152
Short-term borrowings - other	275	-34
Short-term borrowings - Affiliate	97	-20
Dividends on common stock	-185	-171
Other	-4	-2
Net cash from (used for) financing activities	150	-8
Net Increase (Decrease) in Cash and Cash Equivalents	2	-10
Cash and Cash Equivalents at Beginning of Period	27	30
Cash and Cash Equivalents at End of Period	29	20
Supplemental Disclosure of Non-Cash Investing and Financing Activities	'	'
Plant and equipment expenditures in accounts payable	$152	$130

Consolidated_Statements_of_Fin

Consolidated Statements of Financial Position (Unaudited) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Current Assets	'	'
Cash and cash equivalents	$29	$27
Restricted cash, principally Securitization	88	100
Accounts receivable (less allowance for doubtful accounts of $27 and $28, respectively)	'	'
Customer	749	723
Affiliates	17	24
Other	39	24
Inventories	'	'
Fuel	210	188
Materials and supplies	221	215
Notes receivable	'	'
Affiliates	0	200
Other	12	2
Regulatory assets	52	13
Other	73	68
Total Current Assets	1,490	1,584
Investments	'	'
Nuclear decommissioning trust funds	1,237	1,191
Other	167	160
Total Investments	1,404	1,351
Property	'	'
Property, plant and equipment	19,276	18,730
Less accumulated depreciation and amortization	-7,085	-6,951
Property, plant and equipment, net	12,191	11,779
Other Assets	'	'
Regulatory assets	2,175	2,275
Securitized regulatory assets	135	231
Intangible assets	40	41
Other	158	149
Total Noncurrent Assets	2,508	2,696
Total Assets	17,593	17,410
Accounts payable	'	'
Affiliates	57	60
Other	359	424
Accrued interest	57	61
Current portion long-term debt, including capital leases	215	504
Regulatory liabilities	148	278
Deferred income taxes	103	91
Short-term borrowings	'	'
Affiliates	155	58
Other	275	0
Other	150	177
Total Current Liabilities	1,519	1,653
Long-Term Debt (net of current portion)	'	'
Mortgage bonds, notes and other	4,905	4,540
Securitization bonds	0	105
Capital lease obligations	0	4
Total Long-Term Debt (net of current portion)	4,905	4,649
Other Liabilities	'	'
Deferred income taxes	2,937	2,807
Regulatory liabilities	293	386
Asset retirement obligations	1,717	1,667
Unamortized investment tax credit	37	41
Nuclear decommissioning	180	178
Accrued pension liability — affiliates	622	705
Accrued postretirement liability — affiliates	341	369
Other	107	101
Total Noncurrent Liabilities	6,234	6,254
Commitments and Contingencies (Notes 7 and 10)	'	'
Shareholder’s Equity	'	'
Common stock, $10 par value, 400,000,000 shares authorized, and 138,632,324 shares issued and outstanding	3,596	3,596
Retained earnings	1,356	1,274
Accumulated other comprehensive income (loss)	-17	-16
Total Shareholder's Equity	4,935	4,854
Total Liabilities and Shareholder's Equity	$17,593	$17,410

Consolidated_Statements_of_Fin1

Consolidated Statements of Financial Position (Parentheticals) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, except Share data, unless otherwise specified
Assets, Current [Abstract]	'	'
Allowance for Doubtful Accounts Receivable	$27	$28
Statement of Stockholders' Equity [Abstract]	'	'
Common Stock, Par Value Per Share	$10	$10
Common Stock, Shares Authorized	400,000,000	400,000,000
Common Stock, Shares, Issued	138,632,324	138,632,324
Common Stock, Shares, Outstanding	138,632,324	138,632,324

Consolidated_Statements_of_Cha

Consolidated Statements of Changes in Equity (Unaudited) (USD $)	Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Loss [Member]	Accumulated Defined Benefit Plans Adjustment [Member]
In Millions, except Share data
Beginning Balance at Dec. 31, 2013	$4,854	$1,386	$2,210	$1,274	($16)	'
Beginning Balance, shares at Dec. 31, 2013	138,632,324	138,632,000	'	'	'	'
Net Income	267	'	'	267	'	'
Dividends declared on common stock	-185	'	'	-185	'	'
Other Comprehensive (Income) Loss, Benefit obligations, Net of Tax	-1	'	'	'	'	-1
Ending Balance at Jun. 30, 2014	$4,935	$1,386	$2,210	$1,356	($17)	'
Ending Balance, shares at Jun. 30, 2014	138,632,324	138,632,000	'	'	'	'

Basis_of_Presentation_Notes

Basis of Presentation (Notes)	6 Months Ended
	Jun. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]	'
	BASIS OF PRESENTATION
	Corporate Structure
	DTE Electric is an electric utility engaged in the generation, purchase, distribution and sale of electricity to approximately 2.1 million customers in southeastern Michigan. DTE Electric is regulated by the MPSC and the FERC. In addition, we are regulated by other federal and state regulatory agencies including the NRC, the EPA and the MDEQ.
	References in this Report to “we,” “us,” “our” or “Company” are to DTE Electric and its subsidiaries, collectively.
	Basis of Presentation
	These Consolidated Financial Statements should be read in conjunction with the Notes to Consolidated Financial Statements included in the 2013 Annual Report on Form 10-K.
	The accompanying Consolidated Financial Statements are prepared using accounting principles generally accepted in the United States of America. These accounting principles require management to use estimates and assumptions that impact reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results may differ from the Company’s estimates.
	The Consolidated Financial Statements are unaudited, but in the Company's opinion include all adjustments necessary to present a fair statement of the results for the interim periods. All adjustments are of a normal recurring nature, except as otherwise disclosed in these Consolidated Financial Statements and Notes to Consolidated Financial Statements. Financial results for this interim period are not necessarily indicative of results that may be expected for any other interim period or for the fiscal year ending December 31, 2014.
	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 $282 million for the six months ended June 30, 2013. These revisions were needed to properly state the gross purchases and sales activity in the nuclear decommissioning trust fund for the six months ended June 30, 2013. The total of Net cash used in investing activities for the six months ended June 30, 2013 was 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 plants. The Company eliminates all intercompany balances and transactions.
	The Company evaluates whether an entity is a VIE whenever reconsideration events occur. The Company consolidates VIEs for which it is the primary beneficiary. If the Company is not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, the Company considers all relevant facts and circumstances, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE’s economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. The Company performs ongoing reassessments of all VIEs to determine if the primary beneficiary status has changed.
	The Company has variable interests in VIEs through certain of its long-term purchase contracts. As of June 30, 2014, 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 significant 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 related to Securitization is reflected on the Company’s Consolidated Statements of Financial Position.
	The following table summarizes the major balance sheet items as of June 30, 2014 and December 31, 2013 restricted for Securitization that are either (1) assets that can be used only to settle their obligations related to Securitization or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary.
		June 30,		December 31,
		2014		2013
		(In millions)
	ASSETS
	Restricted cash	$	88	$	100
	Accounts receivable	39		34
	Securitized regulatory assets	135		231
	Other long-term assets	2		4
		$	264	$	369
	LIABILITIES
	Accounts payable and accrued current liabilities	$	5	$	7
	Current portion long-term debt	201		196
	Current regulatory liabilities	41		43
	Securitization bonds	—		105
	Other long-term liabilities	8		8
		$	255	$	359

Significant_Accounting_Policie

Significant Accounting Policies (Note)	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Significant Accounting Policies [Text Block]	'
	SIGNIFICANT ACCOUNTING POLICIES
	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 three and six months ended June 30, 2014 include unrealized gains and losses on available-for-sale securities, and changes in benefit obligations, consisting of deferred actuarial losses, prior service costs and transition amounts related to pension and other postretirement benefit plans.
		Changes in Accumulated Other Comprehensive Loss by Component (a)
		Three Months Ended June 30, 2014
		Net Unrealized Gain/(Loss) on Investments		Benefit Obligations			Total
		(In millions)
	Beginning balance, March 31, 2014	$	1	$	(18	)	$	(17	)
	Other comprehensive income before reclassifications	—		—			—
	Amounts reclassified from Accumulated other comprehensive income	—		—			—
	Net current-period other comprehensive income	—		—			—
	Ending balance, June 30, 2014	$	1	$	(18	)	$	(17	)
		Changes in Accumulated Other Comprehensive Loss by Component (a)
		Six Months Ended June 30, 2014
		Net Unrealized Gain/(Loss) on Investments		Benefit Obligations			Total
		(In millions)
	Beginning balance, December 31, 2013	$	1	$	(17	)	$	(16	)
	Other comprehensive income before reclassifications	—		(1		)	(1		)
	Amounts reclassified from Accumulated other comprehensive income	—		—			—
	Net current-period other comprehensive income	—		(1		)	(1		)
	Ending balance, June 30, 2014	$	1	$	(18	)	$	(17	)
	_______________________________________
	(a) All amounts are net of tax.
	Intangible Assets
	The Company has certain intangible assets relating to emission allowances and renewable energy credits as shown below:
		June 30,		December 31,
		2014		2013
		(In millions)
	Emission allowances	$	2	$	2
	Renewable energy credits	51		51
		53		53
	Less current intangible assets	13		12
		$	40	$	41
	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.
	Income Taxes
	The Company's effective tax rate for the three months ended June 30, 2014 was 37% as compared to 34% for the three months ended June 30, 2013. The Company's effective tax rate for the six months ended June 30, 2014 was 37% as compared to 35% for the six months ended June 30, 2013. The increases in the effective tax rates are due primarily to a reduction in the domestic production activities tax benefit.
	DTE Electric had an income tax receivable of $16 million at June 30, 2014 and $23 million at December 31, 2013 due from DTE Energy.
	The Company had $3 million of unrecognized tax benefits at June 30, 2014, that, if recognized, would favorably impact its effective tax rate. The Company does not anticipate any material changes to the unrecognized tax benefits in the next twelve months.
	Stock-Based Compensation
	The Company received an allocation of costs from DTE Energy associated with stock-based compensation of $10 million and $19 million for the three months ended June 30, 2014 and 2013, respectively while such allocation was $29 million and $33 million for the six months ended June 30, 2014 and 2013, respectively.

New_Accounting_Pronouncements_

New Accounting Pronouncements (Notes)	6 Months Ended
	Jun. 30, 2014
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]	'
Description of New Accounting Pronouncements Not yet Adopted [Text Block]	'
	NEW ACCOUNTING PRONOUNCEMENTS
	In May 2014, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2014-09, Revenue from Contracts with Customers. The objectives of this ASU are to improve upon revenue recognition requirements by providing a single comprehensive model to determine the measurement of revenue and timing of recognition. The core principle is that an entity will recognize revenue to depict the transfer of goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services. This ASU also requires expanded qualitative and quantitative disclosures regarding the nature, amount, timing, and uncertainty of revenues and cash flows arising from contracts with customers. The revenue standard is effective for the first interim period within annual reporting periods beginning after December 15, 2016 and is to be applied retrospectively. Early adoption is not permitted. The Company is currently assessing the impact of this ASU on its consolidated financial statements.

Fair_Value_Notes

Fair Value (Notes)	6 Months Ended
	Jun. 30, 2014
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 June 30, 2014 and December 31, 2013. 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 measured and recorded at fair value on a recurring basis as of June 30, 2014 and December 31, 2013:
		30-Jun-14												31-Dec-13
		Level 1			Level 2			Level 3			Net Balance			Level 1		Level 2		Level 3		Net Balance
		(In millions)
	Assets:
	Cash equivalents (a)	$	5		$	96		$	—		$	101		$	2	$	114	$	—	$	116
	Nuclear decommissioning trusts	798			439			—			1,237			779		412		—		1,191
	Other investments (b)	92			50			—			142			91		44		—		135
	Derivative assets — FTRs	—			—			7			7			—		—		3		3
	Total	$	895		$	585		$	7		$	1,487		$	872	$	570	$	3	$	1,445
	Assets:
	Current	$	5		$	96		$	7		$	108		$	2	$	114	$	3	$	119
	Noncurrent	890			489			—			1,379			870		456		—		1,326
	Total Assets	$	895		$	585		$	7		$	1,487		$	872	$	570	$	3	$	1,445
	_______________________________________
	(a)	At June 30, 2014, available-for-sale securities of $101 million, included $88 million and $13 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position. At December 31, 2013, available-for-sale securities of $116 million, included $100 million and $16 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position.
	(b)	Available-for-sale equity securities at both June 30, 2014 and December 31, 2013 of $7 million are included in Other investments on the Consolidated Statements of Financial Position.
	Cash Equivalents
	Cash equivalents include investments with maturities of three months or less when purchased. The cash equivalents shown in the fair value table are comprised of short-term investments and money market funds.
	Nuclear Decommissioning Trusts and Other Investments
	The nuclear decommissioning trusts and other investments hold debt and equity securities directly and indirectly through institutional mutual funds. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. The institutional mutual funds hold exchange-traded equity or debt securities and are valued based on stated net asset values (NAV). 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. The Company has obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices. Additionally, the Company 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. The Company 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. The Company 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. The Company has obtained an understanding of how these prices are derived. Additionally, the Company 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 table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for the three and six months ended June 30, 2014 and 2013:
		Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
		(In millions)
	Net Assets as of beginning of the period	$	1		$	1		$	3		$	1
	Change in fair value recorded in regulatory assets/liabilities	7			3			11			4
	Purchases, issuances and settlements:
	Settlements	(1		)	(2		)	(7		)	(3		)
	Net Assets as of June 30	$	7		$	2		$	7		$	2
	The amount of total gains (losses) included in regulatory assets and liabilities attributed to the change in unrealized gains (losses) related to assets and liabilities held at June 30, 2014 and 2013	$	7		$	2		$	7		$	2
	No transfers between Levels 1, 2 or 3 occurred in the three and six months ended June 30, 2014 and 2013.
	Fair Value of Financial Instruments
	The fair value of financial instruments included in the table below is determined by using quoted market prices when available. When quoted prices are not available, pricing services may be used to determine the fair value with reference to observable interest rate indexes. The Company has obtained an understanding of how the fair values are derived. The Company also selectively corroborates the fair value of its transactions by comparison of market-based price sources. Discounted cash flow analyses based upon estimated current borrowing rates are also used to determine fair value when quoted market prices are not available. The fair values of notes receivable, excluding capital leases, are estimated using discounted cash flow techniques that incorporate market interest rates as well as assumptions about the remaining life of the loans and credit risk. Depending on the information available, other valuation techniques may be used that rely on internal assumptions and models. Valuation policies and procedures are determined by the Company'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 June 30, 2014 and December 31, 2013:
		30-Jun-14												31-Dec-13
		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	$	13		$	—		$	—		$	13		$	10	$	—	$	—	$	10
	Notes receivable — affiliates	$	—		$	—		$	—		$	—		$	200	$	—	$	—	$	200
	Short-term borrowings — affiliates	$	155		$	—		$	—		$	155		$	58	$	—	$	—	$	58
	Short-term borrowings — other	$	275		$	—		$	275		$	—		—		$	—	$	—	$	—
	Long-term debt, excluding capital leases	$	5,116		$	—		$	5,233		$	352		$	5,146	$	—	$	5,253	$	136
	Nuclear Decommissioning Trust Funds
	DTE Electric has a legal obligation to decommission its nuclear power plants following the expiration of their operating licenses. This obligation is reflected as an asset retirement obligation on the Consolidated Statements of Financial Position. Rates approved by the MPSC provide for the recovery of decommissioning costs of Fermi 2 and the disposal of low-level radioactive waste. DTE Electric is continuing to fund FERC jurisdictional amounts for decommissioning even though explicit provisions are not included in FERC rates.
	The following table summarizes the fair value of the nuclear decommissioning trust fund assets:
		June 30,			December 31,
		2014			2013
		(In millions)
	Fermi 2	$	1,214		$	1,172
	Fermi 1	3			3
	Low-level radioactive waste	20			16
	Total	$	1,237		$	1,191
The costs of securities sold are determined on the basis of specific identification. The following table sets forth the gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds:
	Three Months Ended June 30,						Six Months Ended June 30,
	2014			2013			2014			2013
	(In millions)
Realized gains	$	7		$	11		$	16		$	19
Realized losses	$	(4	)	$	(7	)	$	(11	)	$	(14	)
Proceeds from sales of securities	$	204		$	173		$	475		$	309
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:
	30-Jun-14						31-Dec-13
	Fair			Unrealized			Fair			Unrealized
	Value			Gains			Value			Gains
	(In millions)
Equity securities	$	762		$	220		$	730		$	201
Debt securities	462			19			442			12
Cash and cash equivalents	13			—			19			—
	$	1,237		$	239		$	1,191		$	213
The debt securities at June 30, 2014 and December 31, 2013 had an average maturity of approximately 7 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 $28 million and $31 million of unrealized losses as Regulatory assets at June 30, 2014 and December 31, 2013, respectively. Since the decommissioning of Fermi 1 is funded by DTE Electric rather than through a regulatory recovery mechanism, there is no corresponding regulatory asset treatment. Therefore, unrealized losses incurred by the Fermi 1 trust are recognized in earnings immediately. There were no unrealized losses recognized in the three and six months ended June 30, 2014 and 2013 for Fermi 1.
Other Securities
At June 30, 2014 and December 31, 2013, the securities were comprised primarily of money market and equity securities. During the three and six months ended June 30, 2014 and 2013, 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 June 30, 2014 and 2013 were $7 million and $8 million, respectively.

Financial_and_Other_Derivative

Financial and Other Derivative Instruments (Notes)	6 Months Ended
	Jun. 30, 2014
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 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. 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 MTM and recoverable through the PSCR mechanism when settled. This results in the deferral of unrealized gains and losses as Regulatory assets or liabilities until realized.
	The following table presents the fair value of derivative instruments as of June 30, 2014 and December 31, 2013:
		June 30,		December 31,
		2014		2013
		(In millions)
	FTRs — Other current assets	$	7	$	3
	Total derivatives not designated as hedging instrument	$	7	$	3

Asset_Retirement_Obligations_N

Asset Retirement Obligations (Notes)	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Asset Retirement Obligations	'
	ASSET RETIREMENT OBLIGATIONS
	A reconciliation of the asset retirement obligations for the six months ended June 30, 2014 follows:
		(In millions)
	Asset retirement obligations at December 31, 2013	$	1,667
	Accretion	51
	Liabilities incurred	7
	Liabilities settled	(3		)
	Revision in estimated cash flows	(5		)
	Asset retirement obligations at June 30, 2014	$	1,717

Regulatory_Matters_Notes

Regulatory Matters (Notes)	6 Months Ended
	Jun. 30, 2014
Public Utilities, General Disclosures [Abstract]	'
Regulatory Matters	'
	REGULATORY MATTERS
	Refundable Revenue Decoupling/ Deferred Gain Amortization
	In September 2012, the MPSC approved DTE Electric's accounting application to defer for future amortization the gain resulting from the reversal of the Company's $127 million regulatory liability associated with the operation of the RDM. The approved application provided for the amortization of the regulatory liability to income, at a monthly rate of approximately $10.6 million, beginning January 2014. On April 1, 2014, the MPSC approved DTE Electric's accounting application to suspend the amortization of the RDM regulatory liability as of June 30, 2014 and to complete the amortization over the period January 2015 to June 2015. If DTE Electric's base rates are increased prior to July 1, 2015, the Company will cease amortization and refund to customers the remaining unamortized balance of the regulatory liability.
	Transition of the City of Detroit's Public Lighting Department's (PLD) Customers to DTE Electric's Distribution System
	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 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 May 13, 2014, the MPSC approved the TRM as requested and also ordered DTE Electric to include in the TRM the 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. The meter installation phase of the transition was completed in June 2014. On July 1, 2014, former PLD customers became customers of DTE Electric.
	PSCR Proceedings
	The PSCR process is designed to allow DTE Electric to recover all of its power supply costs if incurred under reasonable and prudent policies and practices. DTE Electric's power supply costs include fuel and related transportation costs, purchased and net interchange power costs, nitrogen oxide and sulfur dioxide emission allowances costs, urea costs, transmission costs and MISO costs. The MPSC reviews these costs, policies and practices for prudence in annual plan and reconciliation filings.
	2012 PSCR Year — In March 2013, DTE Electric filed the 2012 PSCR reconciliation calculating a net under-recovery of approximately $87 million that includes an under-recovery of approximately $148 million for the 2011 PSCR year. The reconciliation includes 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 by late 2014 or early 2015.

LongTerm_Debt_Notes

Long-Term Debt (Notes)	6 Months Ended
	Jun. 30, 2014
Long-term Debt, Unclassified [Abstract]	'
Long-term Debt [Text Block]	'
	LONG-TERM DEBT
	Debt Issuances
	In 2014, the following debt was issued:
	Month		Type	Interest Rate	Maturity	Amount
						(In millions)
	June		Mortgage Bonds (a)	3.77%	2026	$	100
	June		Mortgage Bonds (a)	4.60%	2044	150
						$	250
	_______________________________________
	(a)	Proceeds were used for the early redemption of long-term debt, for the repayment of short-term borrowings and for general corporate purposes.
	In July 2014, DTE Electric issued $350 million of 3.375% mortgage bonds due 2025 and $350 million of 4.30% mortgage bonds due 2044. Proceeds will be used for redemption of DTE Electric long-term debt, for the repayment of short-term borrowings and for general corporate purposes.
	Debt Redemptions
	In 2014, the following debt was redeemed:
	Month		Type	Interest Rate	Maturity	Amount
						(In millions)
	March		Mortgage Bonds	Various	2014	$	13
	March		Securitization Bonds	6.62%	2014	100
	April		Tax Exempt Revenue Bonds (a)	2.35%	2024	31
	April		Tax Exempt Revenue Bonds (a)	4.65%	2028	32
	June		Tax Exempt Revenue Bonds (a)	4.88%	2029	36
	June		Tax Exempt Revenue Bonds (a)	6.00%	2036	69
						$	281
	_______________________________________
	(a)	DTE Electric Tax Exempt Revenue Bonds are issued by a public body that loans proceeds to DTE Electric on terms substantially mirroring the Tax Exempt Revenue Bonds.
	In June 2014, DTE Electric called for redemption $200 million of 4.80% senior notes due in February 2015 to be redeemed in July 2014 and $60 million of 5.25% tax exempt revenue bonds due in August 2029 to be redeemed in August 2014.

ShortTerm_Credit_Arrangements_

Short-Term Credit Arrangements and Borrowings (Notes)	6 Months Ended
	Jun. 30, 2014
Short-term Debt [Abstract]	'
Short-Term Credit Arrangements and Borrowings	'
	SHORT-TERM CREDIT ARRANGEMENTS AND BORROWINGS
	DTE Electric has a $300 million unsecured revolving credit agreement with a syndicate of 19 banks that can be used for general corporate borrowings, but is intended to provide liquidity support for the Company's commercial paper program. No one bank provides more than 8.7% of the commitment in the facility. Borrowings under the facility are available at prevailing short-term interest rates. The facility will expire in April 2018. At June 30, 2014, there was $275 million outstanding against the facility, while there were no amounts outstanding against the facility at December 31, 2013.
	The agreement requires the Company to maintain a total funded debt to capitalization ratio of no more than 0.65 to 1. In the agreement, “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 and nonrecourse and junior subordinated 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 June 30, 2014, the total funded debt to total capitalization ratio for DTE Electric was 0.52 to 1 and is in compliance with this financial covenant.

Commitments_and_Contingencies_

Commitments and Contingencies (Notes)	6 Months Ended
	Jun. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and Contingencies	'
	COMMITMENTS AND CONTINGENCIES
	Environmental
	Air — DTE Electric is subject to the EPA ozone and fine particulate transport and acid rain regulations that limit power plant emissions of sulfur dioxide and nitrogen oxides. Since 2005, the EPA and the State of Michigan have issued additional emission reduction regulations relating to ozone, fine particulate, regional haze, mercury, and other air pollution. These rules have led to additional controls on fossil-fueled power plants to reduce nitrogen oxide, sulfur dioxide, mercury and other emissions. To comply with these requirements, DTE Electric spent approximately $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, required further reductions of sulfur dioxide and nitrogen oxides emissions beginning in 2012. On December 30, 2011, the U.S. Court of Appeals for the District of Columbia (D.C.) Circuit (Court of Appeals) 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 of Appeals issued its decision, vacating CSAPR and leaving CAIR in place. The EPA's petition seeking a rehearing of the Court of Appeals' decision regarding the CSAPR was denied on January 24, 2013. On June 24, 2013, the U.S. Supreme Court granted EPA's petition for a review of the Court of Appeals' decision on CSAPR. On April 29, 2014, the U.S. Supreme Court issued its ruling reversing the Court of Appeals' stay decision and remanding the case for further proceedings. The EPA has since requested the Court of Appeals to lift the stay on CSAPR and proposed that phase one of the rule would start effective January 2015. Notwithstanding the U.S. Supreme Court remand decision and potential decision by the Court of Appeals to lift the stay, DTE Electric expects to meet its obligations under CSAPR beginning in 2015. Furthermore, the EPA and a number of states, including Michigan, have started working on the framework of revised CSAPR regulations which may still be proposed in the next few years to address other challenges to the existing CSAPR regulations. DTE Electric will continue to monitor these developments and adjust its compliance strategy accordingly.
	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 all relevant 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 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. On March 3, 2014, the U.S. District Court judge granted again DTE Energy's motion for summary judgment dismissing the civil case related to Monroe Unit 2. On April 3, 2014, the U.S. District Court judge granted motions filed by the EPA and the Sierra Club to amend their New Source Review complaint adding additional claims for Monroe Units 1, 2 and 3, Belle River Units 1 and 2, Trenton Channel Unit 9 and River Rouge Unit 3. On June 30, 2014, the EPA filed a motion requesting certification for appeal of the March 3, 2014 summary judgment decision.
	DTE Energy and DTE Electric believe that all the plants and generating units identified by the EPA and the Sierra Club have complied with all applicable federal environmental regulations. Depending upon the outcome of discussions with the EPA regarding the two NOVs/FOVs, DTE Electric could be required to install additional pollution control equipment at some or all of the power plants in question, implement early retirement of facilities where control equipment is not economical, engage in supplemental environmental programs, and/or pay fines. The Company cannot predict the financial impact or outcome of this matter, or the timing of its resolution.
	In March 2013, the Sierra Club filed suit against DTE Electric alleging violations of the Clean Air Act at four of DTE Electric's coal-fired power plants. The plaintiffs allege 1,499 six-minute periods of excess opacity of air emissions from 2007-2012 at those facilities. The suit asks that the court enjoin the Company 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 six-minute periods from 1,499 to 1,139. DTE Electric filed an answer to the amended complaint on March 11, 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 final rule was issued on May 19, 2014. The final rule specifies a time period exceeding three years to complete studies to determine the type of technology needed to reduce impacts to fish. Final compliance for the installation of the required technology will be determined by each state on a case by case basis. We are currently evaluating the compliance options and working with the State of Michigan on evaluating whether any controls are needed. These evaluations/studies may require modifications to some existing intake structures. It is not possible to quantify the impact of this rulemaking at this time.
	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 September 2015. 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 MGP 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 June 30, 2014 and December 31, 2013, the Company had $8 million accrued for remediation, respectively. Any change in assumptions, such as remediation techniques, nature and extent of contamination and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect the Company’s financial position and cash flows. The Company believes the likelihood of a material change to 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 the 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. The rules are expected to be finalized by December 2014. It is not possible to quantify the impact of those expected rulemakings at this time.
	Other
	In December 2012, 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). Capital costs for pollution controls and/or 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 Electric 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. The state implementation plan process is in the information gathering stage, and DTE Electric is unable to estimate any required emissions reductions at this time.
	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 $1.5 billion in primary coverage and $1.25 billion of excess coverage for stabilization, decontamination, debris removal, repair and/or replacement of property and decommissioning. The combined coverage limit for total property damage is $2.75 billion, subject to a $1 million deductible. The total limit for property damage for non-nuclear events is $2 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 $35 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 that required DTE Electric 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 agreement, including extensions, provides for a claims process and payment of delay-related costs experienced by DTE Electric through 2016. DTE Electric has begun the claims process and claims are being settled and paid on a timely basis. The settlement proceeds reduce the cost of the dry cask storage facility assets and provide reimbursement for related operating expenses. The 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 was scheduled to 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. In March 2014, the COA denied DOE's petition for rehearing. The 1 mill per kWh fee was reduced to zero effective May 16, 2014.
	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.
	Labor Contracts
	There are several bargaining units for the Company's approximately 2,600 represented employees. The majority of the represented employees are under contracts that expire in 2016 and 2017.
	Purchase Commitments
	As of June 30, 2014, 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 $2.3 billion from 2014 through 2033.
	The Company also estimates that 2014 capital expenditures will be approximately $1.6 billion. The Company has made certain commitments in connection with expected capital expenditures.
	Bankruptcies
	The Company purchases and sells electricity from and to governmental entities and numerous companies operating in the steel, automotive, energy, retail 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.
	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 Note 7 for a discussion of contingencies related to regulatory matters.

Retirement_Benefits_and_Truste

Retirement Benefits and Trusteed Assets (Notes)	6 Months Ended
	Jun. 30, 2014
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]	'
Retirement Benefits and Trusted Assets Disclosure [Text Block]	'
	RETIREMENT BENEFITS AND TRUSTEED ASSETS
	The following table details the components of net periodic benefit costs for pension benefits and other postretirement benefits:
		Pension Benefits						Other Postretirement Benefits
		2014			2013			2014			2013
	Three Months Ended June 30	(In millions)
	Service cost	$	17		$	19		$	6		$	9
	Interest cost	40			37			17			16
	Expected return on plan assets	(49		)	(47		)	(21		)	(19		)
	Amortization of:
	Net actuarial loss	26			36			5			12
	Prior service cost (credit)	1			—			(28		)	(28		)
	Net periodic benefit cost (credit)	$	35		$	45		$	(21	)	$	(10	)
		Pension Benefits						Other Postretirement Benefits
		2014			2013			2014			2013
	Six Months Ended June 30	(In millions)
	Service cost	$	34		$	38		$	13		$	21
	Interest cost	80			73			34			34
	Expected return on plan assets	(97		)	(93		)	(42		)	(37		)
	Amortization of:
	Net actuarial loss	53			72			8			24
	Prior service cost (credit)	1			—			(55		)	(45		)
	Net periodic benefit cost (credit)	$	71		$	90		$	(42	)	$	(3	)
	Pension and Other Postretirement Contributions
	During the first six months of 2014, the Company contributed $100 million to its pension plans. At the discretion of management, and depending upon financial market conditions, the Company may make up to an additional $45 million contribution to its pension plans in 2014.
	At the discretion of management, the Company may make up to a $120 million contribution to its other postretirement benefit plans in 2014.

Significant_Accounting_Policie1

Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2014
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 plants. The Company eliminates all intercompany balances and transactions.
	The Company evaluates whether an entity is a VIE whenever reconsideration events occur. The Company consolidates VIEs for which it is the primary beneficiary. If the Company is not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, the Company considers all relevant facts and circumstances, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE’s economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. The Company performs ongoing reassessments of all VIEs to determine if the primary beneficiary status has changed.
	The Company has variable interests in VIEs through certain of its long-term purchase contracts. As of June 30, 2014, 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 significant 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 related to Securitization is reflected on the Company’s Consolidated Statements of Financial Position.
Comprehensive Income, Policy [Policy Text Block]	'
	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 three and six months ended June 30, 2014 include unrealized gains and losses on available-for-sale securities, and changes in benefit obligations, consisting of deferred actuarial losses, prior service costs and transition amounts related to pension and other postretirement benefit plans.
Intangible Assets, Finite-Lived, Policy [Policy Text Block]	'
	Emission allowances and renewable energy credits are charged to expense, using average cost, as the allowances and credits are consumed in the operation of the business.
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 June 30, 2014 and December 31, 2013. 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 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 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. The Company has obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices. Additionally, the Company 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]	'
	The Company 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. The Company 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. The Company has obtained an understanding of how these prices are derived. Additionally, the Company 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 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. The Company has obtained an understanding of how the fair values are derived. The Company also selectively corroborates the fair value of its transactions by comparison of market-based price sources. Discounted cash flow analyses based upon estimated current borrowing rates are also used to determine fair value when quoted market prices are not available. The fair values of notes receivable, excluding capital leases, are estimated using discounted cash flow techniques that incorporate market interest rates as well as assumptions about the remaining life of the loans and credit risk. Depending on the information available, other valuation techniques may be used that rely on internal assumptions and models. Valuation policies and procedures are determined by the Company'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 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. 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 MTM and recoverable through the PSCR mechanism when settled. This results in the deferral of unrealized gains and losses as Regulatory assets or liabilities until realized.

Basis_of_Presentation_Tables

Basis of Presentation (Tables)	6 Months Ended
	Jun. 30, 2014
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]	'
Schedule of Variable Interest Entities [Table Text Block]	'
	The following table summarizes the major balance sheet items as of June 30, 2014 and December 31, 2013 restricted for Securitization that are either (1) assets that can be used only to settle their obligations related to Securitization or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary.
		June 30,		December 31,
		2014		2013
		(In millions)
	ASSETS
	Restricted cash	$	88	$	100
	Accounts receivable	39		34
	Securitized regulatory assets	135		231
	Other long-term assets	2		4
		$	264	$	369
	LIABILITIES
	Accounts payable and accrued current liabilities	$	5	$	7
	Current portion long-term debt	201		196
	Current regulatory liabilities	41		43
	Securitization bonds	—		105
	Other long-term liabilities	8		8
		$	255	$	359

Significant_Accounting_Policie2

Significant Accounting Policies (Tables)	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block]	'
	As shown in the following tables, amounts recorded to accumulated other comprehensive loss for the three and six months ended June 30, 2014 include unrealized gains and losses on available-for-sale securities, and changes in benefit obligations, consisting of deferred actuarial losses, prior service costs and transition amounts related to pension and other postretirement benefit plans.
		Changes in Accumulated Other Comprehensive Loss by Component (a)
		Three Months Ended June 30, 2014
		Net Unrealized Gain/(Loss) on Investments		Benefit Obligations			Total
		(In millions)
	Beginning balance, March 31, 2014	$	1	$	(18	)	$	(17	)
	Other comprehensive income before reclassifications	—		—			—
	Amounts reclassified from Accumulated other comprehensive income	—		—			—
	Net current-period other comprehensive income	—		—			—
	Ending balance, June 30, 2014	$	1	$	(18	)	$	(17	)
		Changes in Accumulated Other Comprehensive Loss by Component (a)
		Six Months Ended June 30, 2014
		Net Unrealized Gain/(Loss) on Investments		Benefit Obligations			Total
		(In millions)
	Beginning balance, December 31, 2013	$	1	$	(17	)	$	(16	)
	Other comprehensive income before reclassifications	—		(1		)	(1		)
	Amounts reclassified from Accumulated other comprehensive income	—		—			—
	Net current-period other comprehensive income	—		(1		)	(1		)
	Ending balance, June 30, 2014	$	1	$	(18	)	$	(17	)
	_______________________________________
	(a) All amounts are net of tax.
Schedule of Finite-Lived Intangible Assets [Table Text Block]	'
	The Company has certain intangible assets relating to emission allowances and renewable energy credits as shown below:
		June 30,		December 31,
		2014		2013
		(In millions)
	Emission allowances	$	2	$	2
	Renewable energy credits	51		51
		53		53
	Less current intangible assets	13		12
		$	40	$	41

Fair_Value_Tables

Fair Value (Tables)	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Schedule of Fair Value, Assets and liabilities measured on a recurring basis [Table Text Block]	'
	The following table presents assets measured and recorded at fair value on a recurring basis as of June 30, 2014 and December 31, 2013:
		30-Jun-14												31-Dec-13
		Level 1			Level 2			Level 3			Net Balance			Level 1		Level 2		Level 3		Net Balance
		(In millions)
	Assets:
	Cash equivalents (a)	$	5		$	96		$	—		$	101		$	2	$	114	$	—	$	116
	Nuclear decommissioning trusts	798			439			—			1,237			779		412		—		1,191
	Other investments (b)	92			50			—			142			91		44		—		135
	Derivative assets — FTRs	—			—			7			7			—		—		3		3
	Total	$	895		$	585		$	7		$	1,487		$	872	$	570	$	3	$	1,445
	Assets:
	Current	$	5		$	96		$	7		$	108		$	2	$	114	$	3	$	119
	Noncurrent	890			489			—			1,379			870		456		—		1,326
	Total Assets	$	895		$	585		$	7		$	1,487		$	872	$	570	$	3	$	1,445
	_______________________________________
	(a)	At June 30, 2014, available-for-sale securities of $101 million, included $88 million and $13 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position. At December 31, 2013, available-for-sale securities of $116 million, included $100 million and $16 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position.
	(b)	Available-for-sale equity securities at both June 30, 2014 and December 31, 2013 of $7 million are included in Other investments on the Consolidated Statements of Financial Position.
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block]	'
	The following table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for the three and six months ended June 30, 2014 and 2013:
		Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
		(In millions)
	Net Assets as of beginning of the period	$	1		$	1		$	3		$	1
	Change in fair value recorded in regulatory assets/liabilities	7			3			11			4
	Purchases, issuances and settlements:
	Settlements	(1		)	(2		)	(7		)	(3		)
	Net Assets as of June 30	$	7		$	2		$	7		$	2
	The amount of total gains (losses) included in regulatory assets and liabilities attributed to the change in unrealized gains (losses) related to assets and liabilities held at June 30, 2014 and 2013	$	7		$	2		$	7		$	2
Fair Value of Financial Instruments [Table Text Block]	'
	The following table presents the carrying amount and fair value of financial instruments as of June 30, 2014 and December 31, 2013:
		30-Jun-14												31-Dec-13
		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	$	13		$	—		$	—		$	13		$	10	$	—	$	—	$	10
	Notes receivable — affiliates	$	—		$	—		$	—		$	—		$	200	$	—	$	—	$	200
	Short-term borrowings — affiliates	$	155		$	—		$	—		$	155		$	58	$	—	$	—	$	58
	Short-term borrowings — other	$	275		$	—		$	275		$	—		—		$	—	$	—	$	—
	Long-term debt, excluding capital leases	$	5,116		$	—		$	5,233		$	352		$	5,146	$	—	$	5,253	$	136
Fair Value of Nuclear Decommissioning Trust Fund Assets [Table Text Block]	'
	The following table summarizes the fair value of the nuclear decommissioning trust fund assets:
		June 30,			December 31,
		2014			2013
		(In millions)
	Fermi 2	$	1,214		$	1,172
	Fermi 1	3			3
	Low-level radioactive waste	20			16
	Total	$	1,237		$	1,191
Schedule of Realized Gain (Loss) [Table Text Block]	'
	The following table sets forth the gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds:
		Three Months Ended June 30,						Six Months Ended June 30,
		2014			2013			2014			2013
		(In millions)
	Realized gains	$	7		$	11		$	16		$	19
	Realized losses	$	(4	)	$	(7	)	$	(11	)	$	(14	)
	Proceeds from sales of securities	$	204		$	173		$	475		$	309
Fair Value and Unrealized Gains for Nuclear Decommissioning Trust Fund [Table Text Block]	'
	The following table sets forth the fair value and unrealized gains for the nuclear decommissioning trust funds:
		30-Jun-14						31-Dec-13
		Fair			Unrealized			Fair			Unrealized
		Value			Gains			Value			Gains
		(In millions)
	Equity securities	$	762		$	220		$	730		$	201
	Debt securities	462			19			442			12
	Cash and cash equivalents	13			—			19			—
		$	1,237		$	239		$	1,191		$	213

Financial_and_Other_Derivative1

Financial and Other Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedges, Assets [Abstract]	'
Fair value of derivative instruments	'
	The following table presents the fair value of derivative instruments as of June 30, 2014 and December 31, 2013:
		June 30,		December 31,
		2014		2013
		(In millions)
	FTRs — Other current assets	$	7	$	3
	Total derivatives not designated as hedging instrument	$	7	$	3

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Schedule of Change in Asset Retirement Obligation [Table Text Block]	'
	A reconciliation of the asset retirement obligations for the six months ended June 30, 2014 follows:
		(In millions)
	Asset retirement obligations at December 31, 2013	$	1,667
	Accretion	51
	Liabilities incurred	7
	Liabilities settled	(3		)
	Revision in estimated cash flows	(5		)
	Asset retirement obligations at June 30, 2014	$	1,717

LongTerm_Debt_Tables

Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2014
Long-term Debt, Unclassified [Abstract]	'
Schedule of Issued Debt [Table Text Block]	'
	In 2014, the following debt was issued:
	Month		Type	Interest Rate	Maturity	Amount
						(In millions)
	June		Mortgage Bonds (a)	3.77%	2026	$	100
	June		Mortgage Bonds (a)	4.60%	2044	150
						$	250
	_______________________________________
	(a)	Proceeds were used for the early redemption of long-term debt, for the repayment of short-term borrowings and for general corporate purposes.
Schedule of Extinguishment of Debt [Table Text Block]	'
	In 2014, the following debt was redeemed:
	Month		Type	Interest Rate	Maturity	Amount
						(In millions)
	March		Mortgage Bonds	Various	2014	$	13
	March		Securitization Bonds	6.62%	2014	100
	April		Tax Exempt Revenue Bonds (a)	2.35%	2024	31
	April		Tax Exempt Revenue Bonds (a)	4.65%	2028	32
	June		Tax Exempt Revenue Bonds (a)	4.88%	2029	36
	June		Tax Exempt Revenue Bonds (a)	6.00%	2036	69
						$	281
	_______________________________________
	(a)	DTE Electric Tax Exempt Revenue Bonds are issued by a public body that loans proceeds to DTE Electric on terms substantially mirroring the Tax Exempt Revenue Bonds.

Retirement_Benefits_and_Truste1

Retirement Benefits and Trusted Assets (Tables)	6 Months Ended
	Jun. 30, 2014
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract]	'
Schedule of Defined Benefit Plans Disclosures [Table Text Block]	'
	The following table details the components of net periodic benefit costs for pension benefits and other postretirement benefits:
		Pension Benefits						Other Postretirement Benefits
		2014			2013			2014			2013
	Three Months Ended June 30	(In millions)
	Service cost	$	17		$	19		$	6		$	9
	Interest cost	40			37			17			16
	Expected return on plan assets	(49		)	(47		)	(21		)	(19		)
	Amortization of:
	Net actuarial loss	26			36			5			12
	Prior service cost (credit)	1			—			(28		)	(28		)
	Net periodic benefit cost (credit)	$	35		$	45		$	(21	)	$	(10	)
		Pension Benefits						Other Postretirement Benefits
		2014			2013			2014			2013
	Six Months Ended June 30	(In millions)
	Service cost	$	34		$	38		$	13		$	21
	Interest cost	80			73			34			34
	Expected return on plan assets	(97		)	(93		)	(42		)	(37		)
	Amortization of:
	Net actuarial loss	53			72			8			24
	Prior service cost (credit)	1			—			(55		)	(45		)
	Net periodic benefit cost (credit)	$	71		$	90		$	(42	)	$	(3	)

Basis_of_Presentation_Details_

Basis of Presentation (Details Textuals) (USD $)	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2013
In Millions, unless otherwise specified	customers	Proceeds from sale of nuclear decommissioning trust funds [Member]	Investment in nuclear decommissioning trust funds [Member]
Organization, Consolidation and Presentation of Financial Statements [Line Items]	'	'	'
Number of Electric Customers	2,100,000	'	'
Prior Period Reclassification Adjustment	'	($282)	$282
Significant Potential Exposure to Loss Due to VIE Long-Term Purchase Contracts	$0	'	'

Basis_of_Presentation_Details

Basis of Presentation (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Assets [Abstract]	'	'
Restricted cash	$88	$100
Accounts receivable	749	723
Securitized regulatory assets	135	231
Other long-term assets	158	149
Total Assets	17,593	17,410
Liabilities [Abstract]	'	'
Current portion long-term debt	215	504
Current regulatory liabilities	148	278
Securitization bonds	0	105
Other long-term liabilities	107	101
Variable Interest Entity, Primary Beneficiary Securitization [Member]	'	'
Assets [Abstract]	'	'
Restricted cash	88	100
Accounts receivable	39	34
Securitized regulatory assets	135	231
Other long-term assets	2	4
Total Assets	264	369
Liabilities [Abstract]	'	'
Accounts payable and accrued current liabilities	5	7
Current portion long-term debt	201	196
Current regulatory liabilities	41	43
Securitization bonds	0	105
Other long-term liabilities	8	8
Total Liabilities	$255	$359

Significant_Accounting_Policie3

Significant Accounting Policies (Accumulated Other Comprehensive Income (Loss)) (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax	($17)	'	($16)	'
Other Comprehensive Income Before Reclassifications	0	'	-1	'
Amounts Reclassified From Accumulated Other Comprehensive Income	0	'	0	'
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, Net of Tax	0	'	-1	'
Accumulated Other Comprehensive Income (Loss), Net of Tax	-17	'	-17	'
Accumulated Net Unrealized Investment Gain (Loss) [Member]	'	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax	1	'	1	'
Other Comprehensive Income Before Reclassifications	0	'	0	'
Amounts Reclassified From Accumulated Other Comprehensive Income	0	0	0	0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, Net of Tax	0	'	0	'
Accumulated Other Comprehensive Income (Loss), Net of Tax	1	'	1	'
Accumulated Defined Benefit Plans Adjustment [Member]	'	'	'	'
Accumulated Other Comprehensive Income (Loss) [Line Items]	'	'	'	'
Accumulated Other Comprehensive Income (Loss), Net of Tax	-18	'	-17	'
Other Comprehensive Income Before Reclassifications	0	'	-1	'
Amounts Reclassified From Accumulated Other Comprehensive Income	0	'	0	'
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, Net of Tax	0	'	-1	'
Accumulated Other Comprehensive Income (Loss), Net of Tax	($18)	'	($18)	'

Significant_Accounting_Policie4

Significant Accounting Policies (Intangible Assets) (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Finite-Lived Intangible Assets [Line Items]	'	'
Finite-Lived Intangible Assets, Gross	$53	$53
Less Current Intangible Assets	13	12
Finite-Lived Intangible Assets, Net	40	41
Emission Allowances [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Finite-Lived Intangible Assets, Gross	2	2
Renewable Energy Credits [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Finite-Lived Intangible Assets, Gross	$51	$51

Significant_Accounting_Policie5

Significant Accounting Policies (Details Textuals) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Significant Accounting Policies [Line Items]	'	'	'	'	'
Effective Income Tax Rate Reconciliation, Percent	37.00%	34.00%	37.00%	35.00%	'
Unrecognized Tax Benefits	$3	'	$3	'	'
DTE Energy [Member]	'	'	'	'	'
Significant Accounting Policies [Line Items]	'	'	'	'	'
Income Taxes Receivable due from DTE Energy	16	'	16	'	23
Allocated Share-based Compensation Expense from DTE Energy	$10	$19	$29	$33	'

Fair_Value_Assets_and_Liabilit

Fair Value (Assets and Liabilities Recorded at Fair Value on a Recurring Basis) (Details) (Fair Value, Measurements, Recurring [Member], USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Cash equivalents	$101	$116
Nuclear decommissioning trusts	1,237	1,191
Other Investments	142	135
Derivative assets - FTRs	7	3
Assets	1,487	1,445
Fair Value, Inputs, Level 1 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Cash equivalents	5	2
Nuclear decommissioning trusts	798	779
Other Investments	92	91
Derivative assets - FTRs	0	0
Assets	895	872
Fair Value, Inputs, Level 2 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Cash equivalents	96	114
Nuclear decommissioning trusts	439	412
Other Investments	50	44
Derivative assets - FTRs	0	0
Assets	585	570
Fair Value, Inputs, Level 3 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Cash equivalents	0	0
Nuclear decommissioning trusts	0	0
Other Investments	0	0
Derivative assets - FTRs	7	3
Assets	7	3
Current Asset [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Assets	108	119
Current Asset [Member] | Fair Value, Inputs, Level 1 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Assets	5	2
Current Asset [Member] | Fair Value, Inputs, Level 2 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Assets	96	114
Current Asset [Member] | Fair Value, Inputs, Level 3 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Assets	7	3
Noncurrent Asset [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Assets	1,379	1,326
Noncurrent Asset [Member] | Fair Value, Inputs, Level 1 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Assets	890	870
Noncurrent Asset [Member] | Fair Value, Inputs, Level 2 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Assets	489	456
Noncurrent Asset [Member] | Fair Value, Inputs, Level 3 [Member]	'	'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'	'
Assets	$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 $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis	'	'	'	'
Beginning Balance	$1	$1	$3	$1
Recorded in regulatory assets/liabilities	7	3	11	4
Purchases issuances and settlements [Abstract]	'	'	'	'
Settlements	-1	-2	-7	-3
Ending Balance	7	2	7	2
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) included in regulatory assets and liabilities	$7	$2	$7	$2

Fair_Value_Fair_Value_of_Finan

Fair Value (Fair Value of Financial Instruments) (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value of Financial Instruments [Line Items]	'	'
Notes receivable, excluding capital leases Carrying Amount	$13	$10
Notes receivable - affiliates Current	0	200
Other Short-term Borrowings	275	0
Long-term debt, excluding capital leases, Carrying Amount	5,116	5,146
Fair Value, Inputs, Level 1 [Member]	'	'
Fair Value of Financial Instruments [Line Items]	'	'
Notes receivable, excluding capital leases Fair Value	0	0
Notes receivable - affiliates, fair value	0	0
Short-term Debt, Fair Value	0	0
Long-term debt, excluding capital leases, Fair Value	0	0
Fair Value, Inputs, Level 2 [Member]	'	'
Fair Value of Financial Instruments [Line Items]	'	'
Notes receivable, excluding capital leases Fair Value	0	0
Notes receivable - affiliates, fair value	0	0
Short-term Debt, Fair Value	275	0
Long-term debt, excluding capital leases, Fair Value	5,233	5,253
Fair Value, Inputs, Level 3 [Member]	'	'
Fair Value of Financial Instruments [Line Items]	'	'
Notes receivable, excluding capital leases Fair Value	13	10
Notes receivable - affiliates, fair value	0	200
Short-term Debt, Fair Value	0	0
Long-term debt, excluding capital leases, Fair Value	352	136
Affiliates [Member]	'	'
Fair Value of Financial Instruments [Line Items]	'	'
Short-term borrowings - affiliates Carrying Amount	155	58
Affiliates [Member] | Fair Value, Inputs, Level 1 [Member]	'	'
Fair Value of Financial Instruments [Line Items]	'	'
Short-term Debt, Fair Value	0	0
Affiliates [Member] | Fair Value, Inputs, Level 2 [Member]	'	'
Fair Value of Financial Instruments [Line Items]	'	'
Short-term Debt, Fair Value	0	0
Affiliates [Member] | Fair Value, Inputs, Level 3 [Member]	'	'
Fair Value of Financial Instruments [Line Items]	'	'
Short-term Debt, Fair Value	$155	$58

Fair_Value_Fair_Value_of_Nucle

Fair Value (Fair Value of Nuclear Decommissioning Trust Fund Assets) (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Decommissioning Fund Investments	$1,237	$1,191
Fermi 2 [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Decommissioning Fund Investments	1,214	1,172
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	20	16
Nuclear Decommissioning Trust Fund [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Decommissioning Fund Investments	$1,237	$1,191

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 $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Nuclear Decommissioning Trust Fund [Member]	'	'	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'	'	'
Realized gains	$7	$11	$16	$19
Realized losses	-4	-7	-11	-14
Proceeds from sales of securities	$204	$173	$475	$309

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 $)	6 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Dec. 31, 2013
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'
Cash and cash equivalents	$13	$19
Nuclear decommissioning trusts	1,237	1,191
Unrealized Gains	239	213
Equity securities [Member]	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'
Equity Securities	762	730
Unrealized Gains	220	201
Debt securities [Member]	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'
Debt securities	462	442
Unrealized Gains	19	12
Cash and cash equivalents [Member]	'	'
Fair Value, Option, Quantitative Disclosures [Line Items]	'	'
Unrealized Gains	$0	$0

Fair_Value_Details_Textuals

Fair Value (Details Textuals) (USD $)

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Accumulated Net Unrealized Investment Gain (Loss) [Member]

Accumulated Net Unrealized Investment Gain (Loss) [Member]

Accumulated Net Unrealized Investment Gain (Loss) [Member]

Accumulated Net Unrealized Investment Gain (Loss) [Member]

Fermi 2 [Member]

Fermi 2 [Member]

Fermi 1 [Member]

Fermi 1 [Member]

Fermi 1 [Member]

Fermi 1 [Member]

Nuclear Decommissioning Trust Fund [Member]

Nuclear Decommissioning Trust Fund [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Fair Value, Measurements, Recurring [Member]

Restricted Assets [Member]

Restricted Assets [Member]

Other Investments [Member]

Other Investments [Member]

Other Investments [Member]

Other Investments [Member]

Equity [Member]

Equity [Member]

Fair Value, Option, Quantitative Disclosures [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash equivalents

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$13

$19

$101

$116

$88

$100

$13

$16

'

'

Available-for-sale Securities, Fair Value Disclosure

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7

7

Transfers Between Levels 1, 2 and 3

0

0

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Average Maturity of Debt Securities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'7 years

'7 years

'

'

'

'

'

'

'

'

Unrealized losses recognized as regulatory assets

'

'

'

'

'

'

'

'

28

31

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other than Temporary Impairment Losses, Investments, Portion Recognized in Earnings, Net

'

'

'

'

'

'

'

'

'

'

0

0

0

0

'

'

'

'

'

'

'

'

'

'

Unrealized Losses on Available for Sale Securities

0

'

0

'

0

0

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Trading Securities, Realized Gain (Loss)

'

'

$7

$8

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Financial_and_Other_Derivative2

Financial and Other Derivative Instruments (Fair Value of Derivative Instruments) (Details) (Not Designated as Hedging Instrument [Member], USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset Fair Value Gross Asset	$7	$3
FTR [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Asset, Current	$7	$3

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Asset retirement obligations beginning of period	$1,667
Accretion	51
Liabilities Incurred	7
Liabilities settled	-3
Revision in estimated cash flows	-5
Asset retirement obligations end of period	$1,717

Regulatory_Matters_Details_Tex

Regulatory Matters (Details Textuals) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2013	Mar. 31, 2014	Jan. 02, 2014	Sep. 30, 2012	Jul. 30, 2012
Public Utilities, General Disclosures [Abstract]	'	'	'	'	'
Defer the Reversal of RDM Liability	'	'	'	$127	'
Monthly Amount to Amortize from Liability to Income	'	'	10.6	'	'
PSCR Under-Recovery from Two Plan Years Prior	87	'	'	'	'
PSCR under-recovery from Three Plan Years Prior	148	'	'	'	'
Fermi 2 Production Level of Full Capacity	'	'	'	'	68.00%
Maximum of challenged Fermi 2 outage charges	'	$32	'	'	'

LongTerm_Debt_Debt_Issuances_D

Long-Term Debt (Debt Issuances) (Details) (USD $)	Jun. 30, 2014
In Millions, unless otherwise specified
Debt Instrument [Line Items]	'
Debt Instrument, Face Amount	$250
Twelve Years [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument, Interest Rate, Stated Percentage	3.77%
Debt Instrument, Face Amount	100
Thirty Years [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument, Interest Rate, Stated Percentage	4.60%
Debt Instrument, Face Amount	$150

LongTerm_Debt_Debt_Redemptions

Long-Term Debt (Debt Redemptions) (Details) (USD $)	6 Months Ended	1 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Mar. 31, 2014	Mar. 31, 2014	Jun. 30, 2014	Apr. 30, 2014	Jun. 30, 2014	Apr. 30, 2014
		Mortgages [Member]	Securitization Bonds [Member]	Tax Exempt Revenue Bonds [Member]	Tax Exempt Revenue Bonds [Member]	Tax-Exempt Revenue Bonds1 [Member]	Tax-Exempt Revenue Bonds1 [Member]
Extinguishment of Debt [Line Items]	'	'	'	'	'	'	'
Debt Instrument, Interest Rate, Stated Percentage	'	'	6.62%	4.88%	2.35%	6.00%	4.65%
Extinguishment of Debt, Amount	$281	$13	$100	$36	$31	$69	$32

LongTerm_Debt_Detail_Textuals

Long-Term Debt (Detail Textuals) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014
Final Maturity of 2025 [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument, Face Amount, Future Issuance	$350
Future Debt Instrument, Interest Rate, Stated Percentage	3.38%
Final Maturity of 2044 [Member]	'
Debt Instrument [Line Items]	'
Debt Instrument, Face Amount, Future Issuance	350
Future Debt Instrument, Interest Rate, Stated Percentage	4.30%
Final Maturity of 2015 [Member]	'
Debt Instrument [Line Items]	'
Future Extinguishment of Debt, Amount	200
Debt Instrument, Interest Rate, Stated Percentage	4.80%
Final Maturity of 2029 [Member]	'
Debt Instrument [Line Items]	'
Future Extinguishment of Debt, Amount	$60
Debt Instrument, Interest Rate, Stated Percentage	5.25%

ShortTerm_Credit_Arrangements_1

Short-Term Credit Arrangements and Borrowings (Details Textuals) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
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	'
Total Funded Debt to Total Capitalization Ratio	0.52	'
Commercial Paper [Member]	'	'
Short-term Debt [Line Items]	'	'
Line of Credit Facility, Amount Outstanding	$275	$0
Unsecured revolving credit facility expiring April 2018 [Member] | Revolving Credit Facility [Member]	'	'
Short-term Debt [Line Items]	'	'
Line of Credit Facility, Maximum Borrowing Capacity	$300	'

Commitments_and_Contingencies_1

Commitments and Contingencies (Details Textuals) (USD $)	0 Months Ended			3 Months Ended	6 Months Ended		12 Months Ended
	19-May-14	16-May-14	Dec. 30, 2013	Dec. 31, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013	Mar. 31, 2013
		kWh			facilities			dte_instances
					kWh
					dte_instances
					employees
Commitments and Contingencies Disclosure [Abstract]	'	'	'	'	'	'	'	'
Environmental Capital Expenditures Through Prior Year End	'	'	'	'	'	'	$2,000,000,000	'
Environmental Capital Expenditures in Current Year	'	'	'	'	280,000,000	'	'	'
Environmental Capital Expenditures In Future Years	'	'	'	'	1,200,000,000	'	'	'
EPA is Alleging DTE Electric Power Plants Violated New Source Performance Standards	'	'	'	'	5	'	'	'
Number of NOVs/FOVs currently being discussed with the EPA	'	'	'	'	2	'	'	'
Sierra Club is Alleging DTE Electric Coal-Fired Power Plants Violated the Clean Air Act	'	'	'	'	4	'	'	'
Exceedances of Opacity Standard	'	'	'	'	1,139	'	'	1,499
Period of excess opacity of air emissions at alleged facilities	'	'	'	'	'	'6 minutes	'	'
Time period to complete studies on cooling water intake structures impacts on fish - EPA ruling	'3 years	'	'	'	'	'	'	'
Number of Former MGP Sites	'	'	'	'	3	'	'	'
Accrual for Environmental Loss Contingencies	'	'	'	8,000,000	8,000,000	'	8,000,000	'
Number of Options to Regulate Coal Ash Residue	'	'	'	'	2	'	'	'
EPA Sulfur Dioxide Ambient AIr Quality Standard	'	'	'	'	'1 hour	'	'	'
Waiting Period of Policy	'	'	'	'	'P12W	'	'	'
Insurance Coverage for Extra Expense When to Necessitate Power Plant when Unavailable	'	'	'	'	490,000,000	'	'	'
Period of Coverage of Policy for Extra Expenses	'	'	'	'	'P3Y	'	'	'
Primary Coverage	'	'	'	'	1,500,000,000	'	'	'
Coverage for Stabilization Decontamination Debris Removal Repair and Replacement of Property and Decommissioning	'	'	'	'	1,250,000,000	'	'	'
Combined Coverage Limit for Total Property Damage	'	'	'	'	2,750,000,000	'	'	'
Insurance Deductible for Nuclear Power Plant	'	'	'	'	1,000,000	'	'	'
Total Limit for Property Damage for Non-Nuclear Event	'	'	'	'	2,000,000,000	'	'	'
Limit for Property Damage for Non-Nuclear Events Aggregate of Extra Expenses	'	'	'	'	327,000,000	'	'	'
Limit for Property Damage for Non-Nuclear Events Aggregate of Extra Expenses of Period	'	'	'	'	'2 years	'	'	'
Time Period for TRIA Insurance after the First Loss from Terrorism	'	'	'	'	'1 year	'	'	'
NEIL Policies Against Terrorism Loss	'	'	'	'	3,200,000,000	'	'	'
Amount per Event Loss Associated with Nuclear Power Plants	'	'	'	'	35,000,000	'	'	'
Maintenance of Public Liability Insurance for Nuclear Power Plants	'	'	'	'	375,000,000	'	'	'
Aggregate Limit of Liabilities Arises From Terrorist Act Outside Scope of Trials Subject to One Industry	'	'	'	'	300,000,000	'	'	'
Maximum Deferred premium charges levied against each licensed nuclear facility	'	'	'	'	127,300,000	'	'	'
Limit Deferred Premium Charges Per Year	'	'	'	'	19,000,000	'	'	'
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	'	'	'	'	'
Company Obligated to Pay DOE Fee of Fermi 2 Electricity Generated and Sold	'	'	'	'	1	'	'	'
New DOE fee for nuclear waste	'	0	'	'	'	'	'	'
Number of Represented Employees	'	'	'	'	2,600	'	'	'
Long-term Purchase Commitment, Amount	'	'	'	'	2,300,000,000	'	'	'
Estimated future capital expenditures for remainder of the year	'	'	'	'	$1,600,000,000	'	'	'

Retirement_Benefits_and_Truste2

Retirement Benefits and Trusted Assets (Details) (USD $)	3 Months Ended		6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Pension Plans, Defined Benefit [Member]	'	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'	'
Service Cost	$17	$19	$34	$38
Interest Cost	40	37	80	73
Expected Return on Plan Assets	-49	-47	-97	-93
Amortization of Net Acutuarial Losses	26	36	53	72
Amortization of Prior Service Cost (Credit)	1	0	1	0
Net Periodic Benefit Cost (Credit)	35	45	71	90
Other Postretirement Benefit Plans, Defined Benefit [Member]	'	'	'	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'	'	'	'
Service Cost	6	9	13	21
Interest Cost	17	16	34	34
Expected Return on Plan Assets	-21	-19	-42	-37
Amortization of Net Acutuarial Losses	5	12	8	24
Amortization of Prior Service Cost (Credit)	-28	-28	-55	-45
Net Periodic Benefit Cost (Credit)	($21)	($10)	($42)	($3)

Retirement_Benefits_and_Truste3

Retirement Benefits and Trusteed Assets (Details Textuals) (USD $)	6 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2014
Pension Plans, Defined Benefit [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Estimated Future Employer Contributions in Current Fiscal Year	$45
Other Postretirement Benefit Plans, Defined Benefit [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Estimated Future Employer Contributions in Current Fiscal Year	120
Qualified Plans [Member] | Pension Plans, Defined Benefit [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Contributions by Employer	$100