Energy Future (TXU) 10-Q 1 Nov 13 2013 Q3 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information	9 Months Ended
	Sep. 30, 2013	Nov. 01, 2013
Document And Entity Information [Abstract]	'	'
Entity Registrant Name	'Energy Future Holdings Corp /TX/	'
Entity Central Index Key	'0001023291	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Non-accelerated Filer	'
Document Type	'10-Q	'
Document Period End Date	30-Sep-13	'
Document Fiscal Year Focus	'2013	'
Document Fiscal Period Focus	'Q3	'
Amendment Flag	'false	'
Entity Common Stock, Shares Outstanding	'	1,669,861,383

Condensed_Statements_Of_Consol

Condensed Statements Of Consolidated Income (Loss) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Operating revenues	$1,893	$1,752	$4,572	$4,358
Fuel, purchased power costs and delivery fees	-852	-850	-2,175	-2,153
Net gain (loss) from commodity hedging and trading activities	58	-3	29	229
Operating costs	-189	-201	-685	-636
Depreciation and amortization	-335	-335	-1,030	-1,015
Selling, general and administrative expenses	-202	-177	-540	-491
Franchise and revenue-based taxes	-18	-19	-51	-55
Other income (Note 13)	5	6	19	25
Other deductions (Note 13)	-36	-42	-40	-54
Interest income	0	1	1	2
Interest expense and related charges (Note 13)	-533	-944	-1,915	-2,746
Loss before income taxes and equity in earnings of unconsolidated subsidiaries	-209	-812	-1,815	-2,536
Income tax benefit	100	296	925	879
Equity in earnings of unconsolidated subsidiaries (net of tax) (Note 2)	114	109	255	249
Net income (loss)	$5	($407)	($635)	($1,408)

Condensed_Statements_Of_Consol1

Condensed Statements Of Consolidated Comprehensive Income (Loss) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Net income (loss)	$5	($407)	($635)	($1,408)
Other comprehensive income (loss), net of tax effects:	'	'	'	'
Effects related to pension and other retirement benefit obligations (net of tax benefit of $1, $18, $2 and $13)	-1	-33	-4	-25
Cash flow hedges derivative value net loss related to hedged transactions recognized during the period (net of tax benefit of $1, $1, $3 and $3)	1	1	5	5
Net effects related to Oncor — reported in equity in earnings of unconsolidated subsidiaries (net of tax benefit of $—, —, — and $1)	1	1	1	2
Total other comprehensive income (loss)	1	-31	2	-18
Comprehensive income (loss)	$6	($438)	($633)	($1,426)

Condensed_Statements_Of_Consol2

Condensed Statements Of Consolidated Comprehensive Income (Loss) (Parenthetical) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Effects related to pension and other retirement benefit costs, tax expense	$1	$18	$2	$13
Cash flow hedges derivative value net loss related to hedged transactions recognized during the period and reported in net income (loss), tax benefit	1	1	3	3
Net effects related to Oncor — reported in equity in earnings of unconsolidated subsidiaries, tax benefit	$0	$0	$0	$1

Condensed_Statements_Of_Consol3

Condensed Statements Of Consolidated Cash Flows (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012
Cash flows — operating activities:	'	'
Net loss	($635)	($1,408)
Adjustments to reconcile net loss to cash provided by (used in) operating activities:	'	'
Depreciation and amortization	1,160	1,161
Deferred income tax benefit, net	-612	-887
Income tax benefit due to audit resolutions (Note 13)	-305	0
Unrealized net loss from mark-to-market valuations of commodity positions	693	1,290
Unrealized net (gain) loss from mark-to-market valuations of interest rate swaps (Note 13)	-903	12
Interest expense on toggle notes payable in additional principal (Notes 5 and 13)	130	177
Amortization of debt related costs, discounts, fair value discounts and losses on dedesignated cash flow hedges (Note 13)	175	183
Equity in earnings of unconsolidated subsidiaries	-255	-249
Distributions of earnings from unconsolidated subsidiaries	148	100
Asset impairments (Note 13)	30	31
Bad debt expense (Note 4)	23	20
Accretion expense related primarily to mining reclamation obligations (Note 13)	24	27
Stock-based incentive compensation expense	5	10
Other, net	2	3
Changes in operating assets and liabilities:	'	'
Margin deposits, net	-197	-321
Other operating assets and liabilities	248	-51
Cash provided by (used in) operating activities	-269	98
Cash flows — financing activities:	'	'
Issuances of long-term debt (Note 5)	0	2,000
Repayments/repurchases of long-term debt (Note 5)	-94	-31
Net short-term borrowings under accounts receivable securitization program (Note 4)	90	80
Decrease in other short-term borrowings (Note 5)	0	-385
Decrease in note payable to unconsolidated subsidiary (Note 11)	0	-20
Settlement of agreements with unconsolidated affiliate (Note 11)	0	-159
Sale/leaseback of equipment	0	15
Contributions from noncontrolling interests	3	6
Debt amendment, exchange and issuance costs and discounts, including third-party fees expensed	-9	-43
Other, net	-5	0
Cash provided by (used in) financing activities	-15	1,463
Cash flows — investing activities:	'	'
Capital expenditures	-372	-526
Nuclear fuel purchases	-59	-155
Proceeds from sales of assets	3	1
Acquisition of combustion turbine trust interest (Note 5)	-40	0
Restricted cash investment used to settle TCEH Demand Notes (Note 11)	680	-680
Other changes in restricted cash	-4	112
Purchases of environmental allowances and credits	-13	-19
Proceeds from sales of nuclear decommissioning trust fund securities	128	56
Investments in nuclear decommissioning trust fund securities	-140	-68
Other, net	4	4
Cash provided by (used in) investing activities	187	-1,275
Net change in cash and cash equivalents	-97	286
Cash and cash equivalents — beginning balance	1,913	826
Cash and cash equivalents — ending balance	$1,816	$1,112

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$1,816	$1,913
Restricted cash (Note 13)	4	680
Trade accounts receivable — net (includes $573 and $445 in pledged amounts related to a VIE (Notes 2 and 4))	808	718
Inventories (Note 13)	400	393
Commodity and other derivative contractual assets (Note 9)	1,056	1,595
Margin deposits related to commodity positions	21	71
Other current assets	64	143
Total current assets	4,169	5,513
Restricted cash (Note 13)	947	947
Receivable from unconsolidated subsidiary (Note 11)	839	825
Investment in unconsolidated subsidiary (Note 2)	5,959	5,850
Other investments (Note 13)	843	767
Property, plant and equipment — net (Note 13)	18,103	18,705
Goodwill (Note 3)	4,952	4,952
Identifiable intangible assets — net (Note 3)	1,697	1,755
Commodity and other derivative contractual assets (Note 9)	159	586
Other noncurrent assets, primarily unamortized debt amendment and issuance costs	1,022	1,070
Total assets	38,690	40,970
Current liabilities:	'	'
Short-term borrowings (includes $172 and $82 related to a VIE (Notes 2 and 5))	2,226	2,136
Long-term debt due currently (Note 5)	38	103
Trade accounts payable	368	394
Net payables due to unconsolidated subsidiary (Note 11)	123	19
Commodity and other derivative contractual liabilities (Note 9)	691	1,044
Margin deposits related to commodity positions	353	600
Accumulated deferred income taxes	34	48
Accrued interest	761	571
Other current liabilities	387	353
Total current liabilities	4,981	5,268
Accumulated deferred income taxes	3,489	2,828
Commodity and other derivative contractual liabilities (Note 9)	782	1,556
Long-term debt, less amounts due currently (Note 5)	38,086	37,815
Other noncurrent liabilities and deferred credits (Note 13)	2,903	4,426
Total liabilities	50,241	51,893
Commitments and Contingencies (Note 6)	'	'
Equity (Note 7):	'	'
EFH Corp. shareholders' equity	-11,656	-11,025
Noncontrolling interests in subsidiaries	105	102
Total equity	-11,551	-10,923
Total liabilities and equity	$38,690	$40,970

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Statement of Financial Position [Abstract]	'	'
Trade accounts receivable from VIE	$573	$445
Short-term borrowings related to VIE	$172	$82

Business_And_Significant_Accou

Business And Significant Accounting Policies	9 Months Ended
	Sep. 30, 2013
Accounting Policies [Abstract]	'
Business And Significant Accounting Policies	'
	BUSINESS AND SIGNIFICANT ACCOUNTING POLICIES
	Description of Business
	References in this report to "we," "our," "us" and "the company" are to EFH Corp. and/or its subsidiaries, as apparent in the context. See "Glossary" for defined terms.
	EFH Corp., a Texas corporation, is a Dallas-based holding company that conducts its operations principally through its TCEH and Oncor subsidiaries. EFH Corp. is a subsidiary of Texas Holdings, which is controlled by the Sponsor Group. TCEH is a holding company for subsidiaries engaged in competitive electricity market activities largely in Texas, including electricity generation, wholesale energy sales and purchases, commodity risk management and trading activities, and retail electricity sales. TCEH is a wholly owned subsidiary of EFCH, which is a holding company and a wholly owned subsidiary of EFH Corp. Oncor is engaged in regulated electricity transmission and distribution operations in Texas. Oncor provides distribution services to REPs, including subsidiaries of TCEH, which sell electricity to residential, business and other consumers. Oncor Holdings, a holding company that holds an approximate 80% equity interest in Oncor, is a wholly owned subsidiary of EFIH, which is a holding company and a wholly owned subsidiary of EFH Corp. Oncor Holdings and its subsidiaries (the Oncor Ring-Fenced Entities) are not consolidated in EFH Corp.'s financial statements in accordance with consolidation accounting standards related to variable interest entities (VIEs) (see Note 2).
	TCEH operates largely in the ERCOT market, and wholesale electricity prices in that market have generally moved with the price of natural gas. Wholesale electricity prices have significant implications to TCEH's profitability and cash flows and, accordingly, the value of its business.
	Various "ring-fencing" measures have been taken to enhance the credit quality of Oncor. Such measures include, among other things: the sale in November 2008 of a 19.75% equity interest in Oncor to Texas Transmission Investment LLC (a limited liability company that owns a 19.75% equity interest in Oncor and is not affiliated with EFH Corp., any of EFH Corp.'s subsidiaries or any member of the Sponsor Group); maintenance of separate books and records for the Oncor Ring-Fenced Entities; Oncor's board of directors being comprised of a majority of independent directors, and prohibitions on the Oncor Ring-Fenced Entities providing credit support to, or receiving credit support from, any member of the Texas Holdings Group. The assets and liabilities of the Oncor Ring-Fenced Entities are separate and distinct from those of the Texas Holdings Group, and none of the assets of the Oncor Ring-Fenced Entities are available to satisfy the debt or contractual obligations of any member of the Texas Holdings Group. Moreover, Oncor's operations are conducted, and its cash flows managed, independently from the Texas Holdings Group.
	We have two reportable segments: the Competitive Electric segment, consisting largely of TCEH, and the Regulated Delivery segment, consisting largely of our investment in Oncor. See Note 12 for further information concerning reportable business segments.
	Liquidity Considerations
	EFH Corp.'s competitive business has been and is expected to continue to be adversely affected by the sustained decline in natural gas prices and its effect on wholesale and retail electricity prices in ERCOT. Further, the remaining natural gas hedges that TCEH entered into when forward market prices of natural gas were significantly higher than current prices will mature in 2013 and 2014. These market conditions challenge the long-term profitability and operating cash flows of EFH Corp.'s competitive businesses and the ability to support their significant interest payments and debt maturities, and could adversely impact their ability to obtain additional liquidity and service, refinance and/or extend the maturities of their outstanding debt.
	Note 5 provides the details of debt activity in 2013 and the principal amounts and maturity dates of EFH Corp.'s and its consolidated subsidiaries' short-term borrowings and long-term debt, which includes the maturity of $3.8 billion of the TCEH Term Loan Facilities in October 2014. At September 30, 2013, TCEH has $1.3 billion of cash and cash equivalents and $171 million of available capacity under its letter of credit facility. Based on forward wholesale power prices in ERCOT, which are subject to the effects of changing market conditions, TCEH may not have sufficient liquidity, absent any financing transactions, to meet its obligations within the next twelve months.
	Discussions with Creditors
	EFH Corp. and its subsidiaries (other than the Oncor Ring-Fenced Entities) continue to consider and evaluate possible transactions and initiatives to address their highly leveraged balance sheets and significant cash interest requirements and have entered into discussions with their lenders and bondholders with respect to such transactions and initiatives. These transactions and initiatives may include, among others, debt for debt exchanges, recapitalizations, amendments to and extensions of debt obligations and exchanges or conversions of debt for preferred or common equity or warrants, including exchanges or conversions of debt of EFH Corp., EFIH, EFCH and TCEH into preferred or common equity or warrants of EFH Corp., EFIH, EFCH, TCEH and/or any of their subsidiaries. These actions could result in holders of EFH Corp., EFIH, EFCH and TCEH debt instruments not recovering the full principal amount of those obligations.
	In March and April 2013, we engaged in discussions with certain unaffiliated holders of first lien senior secured claims against EFCH, TCEH and certain of TCEH's subsidiaries (the TCEH Creditors) with respect to proposed changes to our capital structure. No agreement was reached as part of those discussions, and in September and October 2013, we engaged in further discussions with the TCEH Creditors, certain unaffiliated holders of unsecured claims against EFIH and a significant creditor with claims against TCEH, EFCH, EFIH and EFH Corp. (collectively, the Creditors) with respect to our capital structure, including the possibility of a consensual, prepackaged restructuring transaction. Our objectives in these discussions were to promote a sustainable capital structure and maximize enterprise value of EFH Corp. and its subsidiaries by, among other things, encouraging agreement on a restructuring plan that would minimize time spent in a restructuring through a proactive and organized solution; minimizing any potential adverse tax impacts of a restructuring; maintaining the company in one consolidated group; maintaining focus on operating our businesses, and maintaining the company’s high-performing work force.
	We and the Creditors discussed a number of proposed changes to EFH Corp.'s capital structure. Certain proposals contemplated that some combination of EFH Corp. and certain of its subsidiaries (including EFIH, EFCH and TCEH but excluding the Oncor Ring-Fenced Entities) would implement a plan of reorganization by commencing one or more voluntary cases under Chapter 11 of the United States Bankruptcy Code (the Code). Such proposals would have resulted in a prenegotiated restructuring of EFCH's approximately $32.2 billion principal amount of debt, EFH Corp.’s approximately $650 million principal amount of debt and EFIH’s approximately $7.6 billion principal amount of debt (each as of September 30, 2013 and excluding debt held by affiliates) and contemplated that after the restructuring EFH Corp. would continue to hold all of the equity interests in EFCH and EFIH; EFCH would continue to hold all of the equity interests in TCEH; and EFIH would continue to hold all of the equity interests in Oncor Holdings. Another proposal contemplated that EFIH (excluding Oncor Holdings and its subsidiaries) would implement a plan of reorganization by commencing a stand-alone voluntary case under the Code. Such proposal contemplated that after the restructuring certain creditors of EFIH would own a substantial majority of, and certain creditors of EFH Corp. and the equity holders of EFH Corp. would collectively own a minority of, the equity interests in EFIH. The confirmation of any plans of reorganization in such cases would be subject to applicable regulatory approvals. We and the Creditors have not reached agreement on the terms of any change in our capital structure.
	We are not currently engaged in ongoing negotiations with the principals of any of the Creditors. Although the Creditors are not currently engaged in ongoing negotiations with us, certain of the Creditors have directed their advisors to continue to work with us and our advisors to explore further whether the parties can reach an agreement on the terms of a consensual restructuring. We will continue to consider and evaluate a range of future changes to our capital structure, in addition to the proposed changes described above, which may include filing a voluntary case under Chapter 11 of the Code for some or all of EFH Corp. and its subsidiaries (excluding the Oncor Ring-Fenced Entities).
	Basis of Presentation
	The condensed consolidated financial statements have been prepared in accordance with US GAAP and on the same basis as the audited financial statements included in our 2012 Form 10-K. Investments in unconsolidated subsidiaries, which are 50% or less owned and/or do not meet accounting standards criteria for consolidation, are accounted for under the equity method (see Note 2). Adjustments (consisting of normal recurring accruals) necessary for a fair presentation of the results of operations and financial position have been included therein. All intercompany items and transactions have been eliminated in consolidation. Any acquisitions of outstanding debt for cash, including notes that had been issued in lieu of cash interest, are presented in the financing activities section of the statement of cash flows. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with US GAAP have been omitted pursuant to the rules and regulations of the SEC. Because the condensed consolidated interim financial statements do not include all of the information and footnotes required by US GAAP, they should be read in conjunction with the audited financial statements and related notes included in our 2012 Form 10-K. The results of operations for an interim period may not give a true indication of results for a full year. All dollar amounts in the financial statements and tables in the notes are stated in millions of US dollars unless otherwise indicated.
	Use of Estimates
	Preparation of financial statements requires estimates and assumptions about future events that affect the reporting of assets and liabilities at the balance sheet dates and the reported amounts of revenue and expense, including fair value measurements. In the event estimates and/or assumptions prove to be different from actual amounts, adjustments are made in subsequent periods to reflect more current information.

Variable_Interest_Entities

Variable Interest Entities	9 Months Ended
	Sep. 30, 2013
Consolidation Of Variable Interest Entities [Abstract]	'
Variable Interest Entities	'
	VARIABLE INTEREST ENTITIES
	A variable interest entity (VIE) is an entity with which we have a relationship or arrangement that indicates some level of control over the entity or results in economic risks to us. Accounting standards require consolidation of a VIE if we have (a) the power to direct the significant activities of the VIE and (b) the right or obligation to absorb profit and loss from the VIE (primary beneficiary). In determining the appropriateness of consolidation of a VIE, we evaluate its purpose, governance structure, decision making processes and risks that are passed on to its interest holders. We also examine the nature of any related party relationships among the interest holders of the VIE and the nature of any special rights granted to the interest holders of the VIE.
	As discussed below, our balance sheet includes assets and liabilities of VIEs that meet the consolidation standards. The maximum exposure to loss from our interests in VIEs does not exceed our carrying value.
	Oncor Holdings, an indirect wholly owned subsidiary of EFH Corp. that holds an approximate 80% interest in Oncor, is not consolidated in EFH Corp.'s financial statements, and instead is accounted for as an equity method investment, because the structural and operational ring-fencing measures discussed in Note 1 prevent us from having power to direct the significant activities of Oncor Holdings or Oncor. In accordance with accounting standards, we account for our investment in Oncor Holdings under the equity method, as opposed to the cost method, based on our level of influence over its activities. See below for additional information about our equity method investment in Oncor Holdings. There are no other material investments accounted for under the equity or cost method.
	Consolidated VIEs
	See discussion in Note 4 regarding the VIE related to our accounts receivable securitization program that is consolidated under the accounting standards. We also consolidate Comanche Peak Nuclear Power Company LLC (CPNPC), which was formed by subsidiaries of TCEH and Mitsubishi Heavy Industries Ltd. (MHI) for the purpose of developing two new nuclear generation units at our existing Comanche Peak nuclear-fueled generation facility using MHI's US-Advanced Pressurized Water Reactor technology and to obtain a combined operating license from the NRC. CPNPC is currently financed through capital contributions from the subsidiaries of TCEH and MHI that hold 88% and 12% of CPNPC's equity interests, respectively (see Note 7).
	The carrying amounts and classifications of the assets and liabilities related to our consolidated VIEs are as follows:
	Assets:	September 30,			31-Dec-12			Liabilities:	September 30,			31-Dec-12
		2013							2013
	Cash and cash equivalents	$	37		$	43		Short-term borrowings	$	172		$	82
	Accounts receivable	573			445			Trade accounts payable	1			1
	Property, plant and equipment	138			134			Other current liabilities	13			7
	Other assets, including $3 million and $12 million of current assets	12			16
	Total assets	$	760		$	638		Total liabilities	$	186		$	90
	The assets of our consolidated VIEs can only be used to settle the obligations of the VIE, and the creditors of our consolidated VIEs do not have recourse to our assets to settle the obligations of the VIE.
	Non-Consolidation of Oncor and Oncor Holdings
	Our investment in unconsolidated subsidiary as presented in the balance sheet totaled $5.959 billion and $5.850 billion at September 30, 2013 and December 31, 2012, respectively, and consists almost entirely of our interest in Oncor Holdings, which we account for under the equity method as described above. Oncor provides services, principally electricity distribution, to TCEH's retail operations, and the related revenues represented 28% and 29% of Oncor Holdings' consolidated operating revenues for the nine months ended September 30, 2013 and 2012, respectively.
	See Note 11 for discussion of Oncor Holdings' and Oncor's transactions with EFH Corp. and its other subsidiaries.
	Distributions from Oncor Holdings — Oncor Holdings' distributions of earnings to us totaled $148 million and $100 million for the nine months ended September 30, 2013 and 2012, respectively. Distributions may not be paid except to the extent Oncor maintains a required regulatory capital structure as discussed below. At September 30, 2013, $187 million was eligible to be distributed to Oncor's members after taking into account the regulatory capital structure limit, of which approximately 80% relates to our ownership interest in Oncor. The boards of directors of each of Oncor and Oncor Holdings can withhold distributions to the extent the applicable board determines in good faith that it is necessary to retain such amounts to meet expected future requirements of Oncor and/or Oncor Holdings.
	Oncor's distributions are limited by its regulatory capital structure, which is required to be at or below the assumed debt-to-equity ratio established periodically by the PUCT for ratemaking purposes, which is currently set at 60% debt to 40% equity. At September 30, 2013, Oncor's regulatory capitalization ratio was 58.7% debt and 41.3% equity. The PUCT has the authority to determine what types of debt and equity are included in a utility's debt-to-equity ratio. For purposes of this ratio, debt is calculated as long-term debt plus unamortized gains on reacquired debt less unamortized issuance expenses, premiums and losses on reacquired debt. The debt calculation excludes bonds issued by Oncor Electric Delivery Transition Bond Company LLC, which were issued in 2003 and 2004 to recover specific generation-related regulatory assets and other qualified costs. Equity is calculated as membership interests determined in accordance with US GAAP, excluding the effects of accounting for the Merger (which included recording the initial goodwill and fair value adjustments and the subsequent related impairments and amortization).
	See Note 11 for discussion of a tax sharing agreement with Oncor Holdings.
	Oncor Holdings Financial Statements — Condensed statements of consolidated income of Oncor Holdings and its subsidiaries for the three and nine months ended September 30, 2013 and 2012 are presented below:
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Operating revenues	$	966		$	925		$	2,640		$	2,536
	Operation and maintenance expenses	(315		)	(292		)	(919		)	(873		)
	Depreciation and amortization	(207		)	(201		)	(608		)	(577		)
	Taxes other than income taxes	(112		)	(113		)	(315		)	(313		)
	Other income	4			6			14			20
	Other deductions	(2		)	(1		)	(11		)	(4		)
	Interest income	—			3			2			24
	Interest expense and related charges	(94		)	(96		)	(283		)	(279		)
	Income before income taxes	240			231			520			534
	Income tax expense	(97		)	(95		)	(199		)	(221		)
	Net income	143			136			321			313
	Net income attributable to noncontrolling interests	(29		)	(27		)	(66		)	(64		)
	Net income attributable to Oncor Holdings	$	114		$	109		$	255		$	249
	Assets and liabilities of Oncor Holdings at September 30, 2013 and December 31, 2012 are presented below:
		September 30,			December 31,
		2013			2012
	ASSETS
	Current assets:
	Cash and cash equivalents	$	17		$	45
	Restricted cash	61			55
	Trade accounts receivable — net	404			338
	Trade accounts and other receivables from affiliates	158			53
	Inventories	67			73
	Accumulated deferred income taxes	35			26
	Prepayments and other current assets	82			82
	Total current assets	824			672
	Restricted cash	16			16
	Other investments	85			83
	Property, plant and equipment — net	11,794			11,318
	Goodwill	4,064			4,064
	Regulatory assets — net	1,512			1,788
	Other noncurrent assets	70			78
	Total assets	$	18,365		$	18,019
	LIABILITIES
	Current liabilities:
	Short-term borrowings	$	860		$	735
	Long-term debt due currently	129			125
	Trade accounts payable — nonaffiliates	100			121
	Income taxes payable to EFH Corp.	35			34
Accrued taxes other than income	134			153
Accrued interest	65			95
Other current liabilities	111			110
Total current liabilities	1,434			1,373
Accumulated deferred income taxes	1,881			1,736
Investment tax credits	22			24
Long-term debt, less amounts due currently	5,422			5,400
Other noncurrent liabilities and deferred credits	1,931			1,999
Total liabilities	$	10,690		$	10,532

Goodwill_And_Identifiable_Inta

Goodwill And Identifiable Intangible Assets	9 Months Ended
	Sep. 30, 2013
Goodwill and Intangible Assets Disclosure [Abstract]	'
Goodwill And Identifiable Intangible Assets	'
	GOODWILL AND IDENTIFIABLE INTANGIBLE ASSETS
	Goodwill
	The following table provides information regarding our goodwill balance, all of which relates to the Competitive Electric segment and arose in connection with accounting for the Merger. There were no changes to the goodwill balance for the three and nine months ended September 30, 2013. None of the goodwill is being deducted for tax purposes.
	Goodwill before impairment charges	$	18,342
	Accumulated impairment charges	(13,390		)
	Balance at September 30, 2013 and December 31, 2012	$	4,952
	In the first quarter 2013, we finalized the fair value calculations supporting the $1.2 billion noncash goodwill impairment charge related to the Competitive Electric segment that was recorded in the fourth quarter 2012. No additional impairment was recorded.
	We have determined that in consideration of our most recent forecasts of wholesale power prices in ERCOT, the likelihood of a goodwill impairment has increased. We have initiated an evaluation of goodwill as of September 30, 2013, which will be completed in the fourth quarter 2013 and could result in a noncash goodwill impairment charge in that period.
	Identifiable Intangible Assets
	Identifiable intangible assets, including amounts that arose in connection with accounting for the Merger, are comprised of the following:
			30-Sep-13							31-Dec-12
	Identifiable Intangible Asset		Gross			Accumulated		Net		Gross		Accumulated		Net
			Carrying			Amortization				Carrying		Amortization
			Amount							Amount
	Retail customer relationship		$	463		$	396	$	67	$	463	$	378	$	85
	Favorable purchase and sales contracts		551			333		218		552		314		238
	Capitalized in-service software		357			193		164		356		174		182
	Environmental allowances and credits		598			407		191		594		393		201
	Mining development costs		196			105		91		163		82		81
	Total identifiable intangible assets subject to amortization		$	2,165		$	1,434	731		$	2,128	$	1,341	787
	Retail trade name (not subject to amortization)							955						955
	Mineral interests (not currently subject to amortization)							11						13
	Total identifiable intangible assets							$	1,697					$	1,755
	Amortization expense related to identifiable intangible assets (including income statement line item) consisted of:
	Identifiable Intangible Asset		Income Statement Line		Segment	Three Months Ended September 30,				Nine Months Ended September 30,
						2013		2012		2013		2012
	Retail customer relationship		Depreciation and amortization		Competitive Electric	$	6	$	8	$	18	$	25
	Favorable purchase and sales contracts		Operating revenues/fuel, purchased power costs and delivery fees		Competitive Electric	6		5		19		20
	Capitalized in-service software		Depreciation and amortization		Competitive Electric and Corporate and Other	10		10		31		29
	Environmental allowances and credits		Fuel, purchased power costs and delivery fees		Competitive Electric	5		6		11		15
	Mining development costs		Depreciation and amortization		Competitive Electric	8		7		23		20
	Total amortization expense					$	35	$	36	$	102	$	109
	Estimated Amortization of Identifiable Intangible Assets — The estimated aggregate amortization expense of identifiable intangible assets for each of the next five fiscal years is as follows:
	Year		Estimated Amortization Expense
	2013		$	138
	2014		$	125
	2015		$	115
	2016		$	95
	2017		$	75

Trade_Accounts_Receivable_And_

Trade Accounts Receivable And Accounts Receivable Securitization Program	9 Months Ended
	Sep. 30, 2013
Trade Accounts Receivable and Accounts Receivable Securitization Program [Abstract]	'
Trade Accounts Receivable And Accounts Receivable Securitization Program	'
	TRADE ACCOUNTS RECEIVABLE AND ACCOUNTS RECEIVABLE SECURITIZATION PROGRAM
	On October 29, 2013, we terminated the Accounts Receivable Securitization Program, described in the following paragraphs, and repaid all outstanding obligations under the program. In connection with the termination of the program, TXU Energy repurchased $491 million in accounts receivable from TXU Energy Receivables Company LLC (TXU Energy Receivables Company) for an aggregate purchase price of $474 million, TXU Energy Receivables Company paid TXU Energy $11 million, constituting repayment in full of its outstanding obligations under its subordinated note with TXU Energy, and TXU Energy Receivables Company repaid all of its borrowings from a financial institution providing the financing for the program totaling $126 million.
	Under the Accounts Receivable Securitization Program, TXU Energy (originator) sold all of its trade accounts receivable to TXU Energy Receivables Company, which was an entity created for the special purpose of purchasing receivables from the originator and is a consolidated, wholly owned, bankruptcy-remote subsidiary of TCEH. TXU Energy Receivables Company borrowed funds from a financial institution using the accounts receivable as collateral.
	The trade accounts receivable amounts under the program are reported in the financial statements as pledged balances, and the related funding amounts are reported as short-term borrowings.
	The maximum funding amount available under the program at September 30, 2013 was $200 million, which approximated the expected usage and applied only to receivables related to non-executory retail sales contracts. Program funding increased to $172 million at September 30, 2013 from $82 million at December 31, 2012. Because TCEH's credit ratings were lower than Ba3/BB-, under the terms of the program available funding was reduced by the amount of customer deposits held by the originator, which totaled $33 million at September 30, 2013.
	TXU Energy Receivables Company issued a subordinated note payable to the originator in an amount equal to the difference between the face amount of the accounts receivable purchased, less a discount, and cash paid to the originator. Because the subordinated note was limited to 25% of the uncollected accounts receivable purchased, and the amount of borrowings was limited by terms of the financing agreement, any additional funding to purchase the receivables was sourced from cash on hand, which totaled $37 million at September 30, 2013, and/or capital contributions from TCEH. Under the program, the subordinated note issued by TXU Energy Receivables Company was subordinated to the security interests of the financial institution. The balance of the subordinated note payable, which was eliminated in consolidation, totaled $93 million and $97 million at September 30, 2013 and December 31, 2012, respectively.
	All new trade receivables under the program generated by the originator were continuously purchased by TXU Energy Receivables Company with the proceeds from collections of receivables previously purchased and, as necessary, increased borrowings or funding sources as described immediately above. Changes in the amount of borrowings by TXU Energy Receivables Company reflected seasonal variations in the level of accounts receivable, changes in collection trends and other factors such as changes in sales prices and volumes.
	The discount from face amount on the purchase of receivables from the originator principally funded program fees paid to the financial institution. The program fees consisted primarily of interest costs on the underlying financing and are reported as interest expense and related charges. The discount also funded a servicing fee, which is reported as SG&A expense, paid by TXU Energy Receivables Company to TXU Energy, which provided recordkeeping services and was the collection agent under the program.
	Program fee amounts were as follows:
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Program fees	$	3		$	2		$	6		$	6
	Program fees as a percentage of average funding (annualized)	5.1		%	4.9		%	5.8		%	6.2		%
	Activities of TXU Energy Receivables Company and its predecessor, TXU Receivables Company, were as follows:
		Nine Months Ended September 30,
		2013			2012
	Cash collections on accounts receivable	$	3,200		$	3,501
	Face amount of new receivables purchased (a)	(3,328		)	(3,571		)
	Discount from face amount of purchased receivables	29			8
	Program fees paid to financial institution	(6		)	(6		)
	Servicing fees paid for recordkeeping and collection services	—			(2		)
	Decrease in subordinated notes payable	(4		)	(10		)
	Increase in cash held	17			—
	Other — net	2			—
	Cash flows provided to originator under the program	$	(90	)	$	(80	)
	____________
	(a)	Net of allowance for uncollectible accounts.
	Trade Accounts Receivable
		September 30,			December 31,
		2013			2012
	Wholesale and retail trade accounts receivable	$	825		$	727
	Allowance for uncollectible accounts	(17		)	(9		)
	Trade accounts receivable — reported in balance sheet, including $573 and $445 in pledged retail receivables	$	808		$	718
	Gross trade accounts receivable at September 30, 2013 and December 31, 2012 included unbilled revenues of $272 million and $260 million, respectively.
	Allowance for Uncollectible Accounts Receivable
		Nine Months Ended September 30,
		2013			2012
	Allowance for uncollectible accounts receivable at beginning of period	$	9		$	27
	Increase for bad debt expense	23			20
	Decrease for account write-offs	(15		)	(32		)
	Allowance for uncollectible accounts receivable at end of period	$	17		$	15

ShortTerm_Borrowings_And_LongT

Short-Term Borrowings And Long-Term Debt	9 Months Ended
	Sep. 30, 2013
Debt and Capital Lease Obligations [Abstract]	'
Short-Term Borrowings And Long-Term Debt	'
	SHORT-TERM BORROWINGS AND LONG-TERM DEBT
	Short-Term Borrowings
	At September 30, 2013, outstanding short-term borrowings totaled $2.226 billion, which included $2.054 billion under the TCEH Revolving Credit Facility at a weighted average interest rate of 4.68%, excluding customary fees, and $172 million under the accounts receivable securitization program. On October 29, 2013, we terminated the accounts receivable securitization program and repaid all outstanding obligations under the program (see Note 4).
	At December 31, 2012, outstanding short-term borrowings totaled $2.136 billion, which included $2.054 billion under the TCEH Revolving Credit Facility at a weighted average interest rate of 4.40%, excluding customary fees, and $82 million under the accounts receivable securitization program.
	Credit Facilities
	Credit facilities and related cash borrowings at September 30, 2013 are presented below. Available letter of credit capacity totaled $171 million at September 30, 2013 as discussed below. The facilities are all senior secured facilities of TCEH.
				30-Sep-13
	Facility	Maturity		Facility				Letters of				Cash				Availability
		Date		Limit				Credit				Borrowings
	TCEH Revolving Credit Facility (a)	Oct-16		$	2,054			$	—			$	2,054			$	—
	TCEH Letter of Credit Facility (b)	October 2017 (b)		1,062				—				1,062				—
	Total TCEH			$	3,116			$	—			$	3,116			$	—
	___________
	(a)	Facility used for borrowings for general corporate purposes. Borrowings are classified as short-term borrowings. At September 30, 2013, borrowings under the facility bear interest at LIBOR plus 4.50%, and a commitment fee is payable quarterly in arrears at a rate per annum equal to 1.00% of the average daily unused portion of the facility. In January 2013, commitments previously maturing in 2013 were extended to 2016 as discussed below.
	(b)	Facility, $42 million of which matures in October 2014, used for issuing letters of credit for general corporate purposes, including, but not limited to, providing collateral support under hedging arrangements and other commodity transactions that are not secured by a first-lien interest in the assets of TCEH. The borrowings under this facility have been recorded by TCEH as restricted cash that supports issuances of letters of credit and are classified as long-term debt. At September 30, 2013, the restricted cash totaled $947 million, after reduction for a $115 million letter of credit drawn in 2009 related to an office building financing. At September 30, 2013, the restricted cash supports $776 million in letters of credit outstanding, leaving $171 million in available letter of credit capacity.
	Amendment and Extension of TCEH Revolving Credit Facility — In January 2013, the Credit Agreement governing the TCEH Senior Secured Facilities was amended to extend the maturity date of the $645 million of commitments maturing in October 2013 to October 2016, bringing the maturity date of all commitments under the TCEH Revolving Credit Facility totaling $2.054 billion to October 2016. The extended commitments have the same terms and conditions as the existing commitments expiring in October 2016 under the Credit Agreement. Fees in consideration for the extension were settled through the incurrence of $340 million principal amount of incremental term loans under the TCEH Term Loan Facilities maturing in October 2017. In connection with the extension request, TCEH eliminated its ability to draw letters of credit under the TCEH Revolving Credit Facility. At the date of the extension, there were no outstanding letters of credit under the TCEH Revolving Credit Facility.
	Long-Term Debt
	At September 30, 2013 and December 31, 2012, long-term debt consisted of the following:
		September 30,				December 31,
		2013				2012
	EFH Corp. (parent entity)
	9.75% Fixed Senior Notes due October 15, 2019	$	2			$	115
	10% Fixed Senior Notes due January 15, 2020	3				1,061
	10.875% Fixed Senior Notes due November 1, 2017 (a)	33				64
	11.25 / 12.00% Senior Toggle Notes due November 1, 2017 (a)	27				60
	5.55% Fixed Series P Senior Notes due November 15, 2014 (a)	90				92
	6.50% Fixed Series Q Senior Notes due November 15, 2024 (a)	201				230
	6.55% Fixed Series R Senior Notes due November 15, 2034 (a)	291				291
	8.82% Building Financing due semiannually through February 11, 2022 (b)	46				53
	Unamortized fair value premium related to Building Financing (b)(c)	9				11
	Unamortized fair value discount (c)	(123		)		(137		)
	Total EFH Corp.	579				1,840
	EFIH
	6.875% Fixed Senior Secured First Lien Notes due August 15, 2017	503				503
	10% Fixed Senior Secured First Lien Notes due December 1, 2020	3,482				2,180
	11% Fixed Senior Secured Second Lien Notes due October 1, 2021	406				406
	11.75% Fixed Senior Secured Second Lien Notes due March 1, 2022	1,750				1,750
	11.25 / 12.25% Senior Toggle Notes due December 1, 2018	1,476				1,304
	9.75% Fixed Senior Notes due October 15, 2019	2				141
	Unamortized premium	303				351
	Unamortized discount	(149		)		(131		)
	Total EFIH	7,773				6,504
	EFCH
	9.58% Fixed Notes due in annual installments through December 4, 2019 (d)	35				35
	8.254% Fixed Notes due in quarterly installments through December 31, 2021 (d)	35				39
	1.065% Floating Rate Junior Subordinated Debentures, Series D due January 30, 2037 (e)	1				1
	8.175% Fixed Junior Subordinated Debentures, Series E due January 30, 2037	8				8
	Unamortized fair value discount (c)	(6		)		(7		)
	Total EFCH	73				76
	TCEH
	Senior Secured Facilities:
	3.710% TCEH Term Loan Facilities maturing October 10, 2014 (e)(f)	3,809				3,809
	3.679% TCEH Letter of Credit Facility maturing October 10, 2014 (e)	42				42
	4.709% TCEH Term Loan Facilities maturing October 10, 2017 (a)(e)(f)	15,691				15,351
	4.679% TCEH Letter of Credit Facility maturing October 10, 2017 (e)	1,020				1,020
	11.5% Fixed Senior Secured Notes due October 1, 2020	1,750				1,750
	15% Fixed Senior Secured Second Lien Notes due April 1, 2021	336				336
	15% Fixed Senior Secured Second Lien Notes due April 1, 2021, Series B	1,235				1,235
	10.25% Fixed Senior Notes due November 1, 2015 (a)	1,833				1,833
	10.25% Fixed Senior Notes due November 1, 2015, Series B (a)	1,292				1,292
	10.50 / 11.25% Senior Toggle Notes due November 1, 2016	1,749				1,749
		September 30,				December 31,
		2013				2012
Pollution Control Revenue Bonds:
Brazos River Authority:
5.40% Fixed Series 1994A due May 1, 2029	$	39			$	39
7.70% Fixed Series 1999A due April 1, 2033	111				111
6.75% Fixed Series 1999B due September 1, 2034, remarketing date April 1, 2013 (g)	—				16
7.70% Fixed Series 1999C due March 1, 2032	50				50
8.25% Fixed Series 2001A due October 1, 2030	71				71
8.25% Fixed Series 2001D-1 due May 1, 2033	171				171
0.089% Floating Series 2001D-2 due May 1, 2033 (h)	97				97
0.210% Floating Taxable Series 2001I due December 1, 2036 (i)	62				62
0.089% Floating Series 2002A due May 1, 2037 (h)	45				45
6.75% Fixed Series 2003A due April 1, 2038, remarketing date April 1, 2013 (g)	—				44
6.30% Fixed Series 2003B due July 1, 2032	39				39
6.75% Fixed Series 2003C due October 1, 2038	52				52
5.40% Fixed Series 2003D due October 1, 2029, remarketing date October 1, 2014 (g)	31				31
5.00% Fixed Series 2006 due March 1, 2041	100				100
Sabine River Authority of Texas:
6.45% Fixed Series 2000A due June 1, 2021	51				51
5.20% Fixed Series 2001C due May 1, 2028	70				70
5.80% Fixed Series 2003A due July 1, 2022	12				12
6.15% Fixed Series 2003B due August 1, 2022	45				45
Trinity River Authority of Texas:
6.25% Fixed Series 2000A due May 1, 2028	14				14
Unamortized fair value discount related to pollution control revenue bonds (c)	(107		)		(112		)
Other:
7.48% Fixed Secured Facility Bonds with amortizing payments through January 2017	36				—
7.46% Fixed Secured Facility Bonds with amortizing payments through January 2015	4				12
7% Fixed Senior Notes due March 15, 2013	—				5
Capital leases	56				64
Other	3				3
Unamortized discount	(110		)		(10		)
Unamortized fair value discount (c)	—				(1		)
Total TCEH	29,699				29,498
Total EFH Corp. consolidated	38,124				37,918
Less amount due currently	(38		)		(103		)
Total long-term debt	$	38,086			$	37,815
___________
(a)	Excludes the following debt held by EFIH or EFH Corp. (parent entity) and eliminated in consolidation:
	September 30,				December 31,
	2013				2012
EFH Corp. 10.875% Fixed Senior Notes due November 1, 2017	$	—			$	1,685
EFH Corp. 11.25 / 12.00% Senior Toggle Notes due November 1, 2017	—				3,441
EFH Corp. 5.55% Fixed Series P Senior Notes due November 15, 2014	281				279
EFH Corp. 6.50% Fixed Series Q Senior Notes due November 15, 2024	545				516
EFH Corp. 6.55% Fixed Series R Senior Notes due November 15, 2034	456				456
TCEH 4.709% Term Loan Facilities maturing October 10, 2017	19				19
TCEH 10.25% Fixed Senior Notes due November 1, 2015	213				213
TCEH 10.25% Fixed Senior Notes due November 1, 2015, Series B	150				150
Total	$	1,664			$	6,759
(b)	This financing is the obligation of a subsidiary of EFH Corp. and will be serviced with cash drawn by the beneficiary of a letter of credit that was previously issued to secure the obligation.
(c)	Amount represents unamortized fair value adjustments recorded under purchase accounting.
(d)	EFCH's obligations with respect to these financings are guaranteed by EFH Corp. and secured on a first-priority basis by, among other things, an undivided interest in the Comanche Peak nuclear generation facility.
(e)	Interest rates in effect at September 30, 2013.
(f)	Interest rate swapped to fixed on $18.140 billion principal amount of maturities through October 2014 and up to an aggregate $12.6 billion principal amount from October 2014 through October 2017.
(g)	These series are in the multiannual interest rate mode and are subject to mandatory tender prior to maturity on the mandatory remarketing date. On such date, the interest rate and interest rate period will be reset for the bonds.
(h)	Interest rates in effect at September 30, 2013. These series are in a daily interest rate mode and are classified as long-term as they are supported by long-term irrevocable letters of credit.
(i)	Interest rate in effect at September 30, 2013. This series is in a weekly interest rate mode and is classified as long-term as it is supported by long-term irrevocable letters of credit.
Debt Amounts Due Currently
Amounts due currently (within twelve months) at September 30, 2013 total $38 million and consist of scheduled installment payments on capital leases and debt securities.
Debt Related Activity in 2013
Principal amounts of long-term debt issued in the nine months ended September 30, 2013 totaled $1.731 billion and consisted of $340 million principal amount of incremental term loans under the TCEH Term Loan Facilities discussed in “Amendment and Extension of TCEH Revolving Credit Facility” above and $1.302 billion of EFIH 10% Notes and $89 million of EFIH Toggle Notes issued in exchanges discussed below.
Repayments of long-term debt in the nine months ended September 30, 2013 totaled $94 million and consisted of $86 million of payments of principal at scheduled maturity or mandatory tender and remarketing dates (including $60 million of pollution control revenue bond and $17 million of fixed secured facility bond payments) and $8 million of contractual payments under capital leases.
In April 2013, TCEH acquired for $40 million in cash the owner participant interest in a trust established to lease six natural gas-fueled combustion turbines to TCEH. The interest in the trust was held by an unaffiliated party. The trust was consolidated in the second quarter 2013. No gain or loss was recognized on the transaction. The estimated fair value of the combustion turbine assets of $83 million approximated the total of the estimated fair value of the debt assumed and cash paid. In recording the combustion turbine assets, the fair value was reduced by the remaining deferred lease liability and the unamortized lease valuation reserve established in accounting for the Merger, which were reversed and totaled $18 million. At June 30, 2013, the principal amount of the trust's debt totaled $45 million and is payable in semiannual installments through January 1, 2017.
EFIH Debt Exchanges and Distributions Involving EFH Corp. Debt — In exchanges in January 2013, EFIH and EFIH Finance issued $1.302 billion principal amount of EFIH 10% Senior Secured Notes due 2020 (New EFIH 10% Notes) in exchange for $1.310 billion total principal amount of EFH Corp. and EFIH senior secured notes consisting of: (i) $113 million principal amount of EFH Corp. 9.75% Senior Secured Notes due 2019 (EFH Corp. 9.75% Notes), (ii) $1.058 billion principal amount of EFH Corp. 10% Senior Secured Notes due 2020 (EFH Corp. 10% Notes), and (iii) $139 million principal amount of EFIH 9.75% Senior Secured Notes due 2019 (EFIH 9.75% Notes). The New EFIH 10% Notes have terms and conditions substantially the same as the existing EFIH 10% Notes discussed below. EFIH cancelled the EFIH notes it received in the exchanges.
In connection with these debt exchange transactions, EFH Corp. received the requisite consents from holders of the EFH Corp. 9.75% Notes and EFH Corp. 10% Notes and EFIH received the requisite consents from holders of the EFIH 9.75% Notes to certain amendments to the respective indentures governing such notes. These amendments, among other things, (i) eliminated EFIH's pledge of its 100% ownership of the membership interests it owns in Oncor Holdings as collateral for the EFIH 9.75% Notes, (ii) made EFCH and EFIH unrestricted subsidiaries under the EFH Corp. 9.75% Notes and EFH Corp. 10% Notes, thereby eliminating EFCH's unsecured and EFIH's secured guarantees of the notes, (iii) eliminated substantially all of the restrictive covenants in the indentures and (iv) eliminated certain events of default, modified covenants regarding mergers and consolidations and modified or eliminated certain other provisions in these indentures.
In additional exchanges in January 2013, EFIH and EFIH Finance issued $89 million principal amount of additional 11.25/12.25% Toggle Notes due 2018 (EFIH Toggle Notes) in exchange for $95 million total principal amount of EFH Corp. senior notes consisting of: (i) $31 million principal amount of EFH Corp. 10.875% Senior Notes due 2017 (EFH Corp. 10.875% Notes), (ii) $33 million principal amount of EFH Corp. 11.25%/12.00% Senior Toggle Notes due 2017 (EFH Corp. Toggle Notes), (iii) $2 million principal amount of EFH Corp. 5.55% Series P Notes due 2014 (EFH Corp. 5.55% Notes) and (iv) $29 million principal amount of EFH Corp. 6.50% Series Q Notes due 2024 (EFH Corp. 6.50% Notes). The additional EFIH Toggle Notes have the same terms and conditions as the existing EFIH Toggle Notes discussed below.
In the first quarter 2013, EFIH distributed $6.360 billion principal amount of EFH Corp. debt that it previously received in debt exchanges, including $1.235 billion received in January 2013, as a dividend to EFH Corp., which cancelled the notes, leaving $1.361 billion principal amount of affiliate debt still held by EFIH. The dividend included $1.715 billion principal amount of EFH Corp. 10.875% Notes, $3.474 billion principal amount of EFH Corp. Toggle Notes, $1.058 billion principal amount of EFH Corp. 10% Notes and $113 million principal amount of EFH Corp. 9.75% Notes.
Accounting and Income Tax Effects of the January 2013 Debt Exchanges — In consideration of the circumstances and terms of the exchanges, accounting rules require that the net loss on the exchanges, which totaled $21 million, be deferred and amortized to interest expense over the life of the debt issued. The deferred loss is reported as debt discount associated with the EFIH 10% Notes and EFIH Toggle Notes. For federal income tax purposes, the transactions resulted in cancellation of debt income of $11 million that was offset by operating losses.
Information Regarding Other Significant Outstanding Debt
TCEH Senior Secured Facilities — Borrowings under the TCEH Senior Secured Facilities totaled $22.616 billion at September 30, 2013 and consisted of:
•	$3.809 billion of TCEH Term Loan Facilities maturing in October 2014 with interest payable at LIBOR plus 3.50%;
•	$15.691 billion of TCEH Term Loan Facilities maturing in October 2017 with interest payable at LIBOR plus 4.50%;
•	$42 million of cash borrowed under the TCEH Letter of Credit Facility maturing in October 2014 with interest payable at LIBOR plus 3.50% (see discussion under "Credit Facilities" above);
•	$1.020 billion of cash borrowed under the TCEH Letter of Credit Facility maturing in October 2017 with interest payable at LIBOR plus 4.50% (see discussion under "Credit Facilities" above), and
•	Amounts borrowed under the TCEH Revolving Credit Facility, which may be reborrowed from time to time until October 2016 and represent the entire amount of commitments under the facility totaling $2.054 billion at September 30, 2013. See "Credit Facilities" above for discussion regarding the maturity date extension of $645 million in commitments from 2013 to 2016.
Each of the loans described above that matures in 2016 or 2017 includes a "springing maturity" provision pursuant to which (i) in the event that more than $500 million aggregate principal amount of the TCEH 10.25% Notes due in 2015 (other than notes held by EFH Corp. or its controlled affiliates at March 31, 2011 to the extent held at the determination date as defined in the Credit Agreement) or more than $150 million aggregate principal amount of the TCEH Toggle Notes due in 2016 (other than notes held by EFH Corp. or its controlled affiliates at March 31, 2011 to the extent held at the determination date as defined in the Credit Agreement), as applicable, remain outstanding as of 91 days prior to the maturity date of the applicable notes and (ii) TCEH's total debt to Adjusted EBITDA ratio (as defined in the TCEH Senior Secured Facilities) is greater than 6.00 to 1.00 at the applicable determination date, then the maturity date of the extended loans will automatically change to 90 days prior to the maturity date of the applicable notes.
Under the terms of the TCEH Senior Secured Facilities, the commitments of the lenders to make loans to TCEH are several and not joint. Accordingly, if any lender fails to make loans to TCEH, TCEH's available liquidity could be reduced by an amount up to the aggregate amount of such lender's commitments under the TCEH Senior Secured Facilities.
The TCEH Senior Secured Facilities are fully and unconditionally guaranteed jointly and severally on a senior secured basis by EFCH, and subject to certain exceptions, each existing and future direct or indirect wholly owned US subsidiary of TCEH. The TCEH Senior Secured Facilities, along with the TCEH Senior Secured Notes and certain commodity hedging transactions and the interest rate swaps described under "TCEH Interest Rate Swap Transactions" below, are secured on a first-priority basis by (i) substantially all of the current and future assets of TCEH and TCEH's subsidiaries who are guarantors of such facilities and (ii) pledges of the capital stock of TCEH and certain current and future direct or indirect subsidiaries of TCEH.
TCEH 11.5% Senior Secured Notes — At September 30, 2013, the principal amount of the TCEH 11.5% Senior Secured Notes totaled $1.750 billion. The notes mature in October 2020, with interest payable in cash quarterly in arrears on January 1, April 1, July 1 and October 1, at a fixed rate of 11.5% per annum. The notes are fully and unconditionally guaranteed on a joint and several basis by EFCH and each subsidiary of TCEH that guarantees the TCEH Senior Secured Facilities (collectively, the Guarantors). The notes are secured, on a first-priority basis, by security interests in all of the assets of TCEH, and the guarantees are secured on a first-priority basis by all of the assets and equity interests held by the Guarantors, in each case, to the extent such assets and equity interests secure obligations under the TCEH Senior Secured Facilities (the TCEH Collateral), subject to certain exceptions and permitted liens.
The notes are (i) senior obligations and rank equally in right of payment with all senior indebtedness of TCEH, (ii) senior in right of payment to all existing or future unsecured and second-priority secured debt of TCEH to the extent of the value of the TCEH Collateral and (iii) senior in right of payment to any future subordinated debt of TCEH. These notes are effectively subordinated to all secured obligations of TCEH that are secured by assets other than the TCEH Collateral, to the extent of the value of the assets securing such obligations.
TCEH 15% Senior Secured Second Lien Notes (including Series B) — At September 30, 2013, the principal amount of the TCEH 15% Senior Secured Second Lien Notes totaled $1.571 billion. These notes mature in April 2021, with interest payable in cash quarterly in arrears on January 1, April 1, July 1 and October 1 at a fixed rate of 15% per annum. The notes are fully and unconditionally guaranteed on a joint and several basis by EFCH and, subject to certain exceptions, each subsidiary of TCEH that guarantees the TCEH Senior Secured Facilities. The notes are secured, on a second-priority basis, by security interests in all of the assets of TCEH, and the guarantees (other than the guarantee of EFCH) are secured on a second-priority basis by all of the assets and equity interests of all of the Guarantors other than EFCH (collectively, the Subsidiary Guarantors), in each case, to the extent such assets and security interests secure obligations under the TCEH Senior Secured Facilities on a first-priority basis, subject to certain exceptions (including the elimination of the pledge of equity interests of any Subsidiary Guarantor to the extent that separate financial statements would be required to be filed with the SEC for such Subsidiary Guarantor under Rule 3-16 of Regulation S-X) and permitted liens. The guarantee from EFCH is not secured.
The notes are senior obligations of the issuer and rank equally in right of payment with all senior indebtedness of TCEH, are senior in right of payment to all existing or future unsecured debt of TCEH to the extent of the value of the TCEH Collateral (after taking into account any first-priority liens on the TCEH Collateral) and are senior in right of payment to any future subordinated debt of TCEH. These notes are effectively subordinated to TCEH's obligations under the TCEH Senior Secured Facilities, the TCEH Senior Secured Notes and TCEH's commodity and interest rate hedges that are secured by a first-priority lien on the TCEH Collateral and any future obligations subject to first-priority liens on the TCEH Collateral, to the extent of the value of the TCEH Collateral, and to all secured obligations of TCEH that are secured by assets other than the TCEH Collateral, to the extent of the value of the assets securing such obligations.
TCEH 10.25% Senior Notes (including Series B) and 10.50/11.25% Senior Toggle Notes (collectively, the TCEH Senior Notes) — At September 30, 2013, the principal amount of the TCEH Senior Notes totaled $4.874 billion, excluding $363 million aggregate principal amount held by EFH Corp. and EFIH, and the notes are fully and unconditionally guaranteed on a joint and several unsecured basis by TCEH's direct parent, EFCH (which owns 100% of TCEH), and by each subsidiary that guarantees the TCEH Senior Secured Facilities. The TCEH 10.25% Notes mature in November 2015, with interest payable in cash semi-annually in arrears on May 1 and November 1 at a fixed rate of 10.25% per annum. The TCEH Toggle Notes mature in November 2016, with interest payable semi-annually in arrears on May 1 and November 1 at a fixed rate of 10.50% per annum .
EFIH 6.875% Senior Secured Notes — At September 30, 2013, the principal amount of the EFIH 6.875% Notes totaled $503 million. These notes mature in August 2017, with interest payable in cash semiannually in arrears on February 15 and August 15 at a fixed rate of 6.875% per annum. The EFIH 6.875% Notes are secured on a first-priority basis by EFIH's pledge of its 100% ownership of the membership interests in Oncor Holdings (the EFIH Collateral) on an equal and ratable basis with the EFIH 10% Notes.
The EFIH 6.875% Notes are senior obligations of EFIH and rank equally in right of payment with all senior indebtedness of EFIH and are senior in right of payment to any future subordinated indebtedness of EFIH. The EFIH 6.875% Notes are effectively senior to all second lien and unsecured indebtedness of EFIH, to the extent of the value of the EFIH Collateral, and are effectively subordinated to any indebtedness of EFIH secured by assets of EFIH other than the EFIH Collateral, to the extent of the value of such assets. Furthermore, the EFIH 6.875% Notes are structurally subordinated to all indebtedness and other liabilities of EFIH's subsidiaries (other than EFIH Finance), including Oncor Holdings and its subsidiaries. The holders of the EFIH 6.875% Notes vote as a separate class from the holders of the EFIH 10% Notes.
The EFIH 6.875% Notes were issued in private placements and are not registered under the Securities Act. EFIH has agreed to use its commercially reasonable efforts to register with the SEC notes having substantially identical terms as the EFIH 6.875% Notes (except for provisions relating to transfer restrictions and payment of additional interest) as part of an offer to exchange freely tradable notes for the EFIH 6.875% Notes. Because the exchange offer has not yet been completed, the annual interest rate on the EFIH 6.875% Notes increased by 25 basis points (to 7.125%) on August 15, 2013 and will increase by an additional 25 basis points (to 7.375%) on November 15, 2013. The interest rate on the EFIH 6.875% Notes will remain at that level until completion of the exchange offer, at which time the interest rate on the notes will revert to 6.875%.
EFIH 10% Senior Secured Notes — At September 30, 2013, the principal amount of the EFIH 10% Notes totaled $3.482 billion. The notes mature in December 2020, with interest payable in cash semiannually in arrears on June 1 and December 1 at a fixed rate of 10% per annum. The notes are secured by the EFIH Collateral on an equal and ratable basis with the EFIH 6.875% Notes.
The EFIH 10% Notes are senior obligations of EFIH and rank equally in right of payment with all existing and future senior indebtedness of EFIH, including the EFIH 6.875% Notes. The EFIH 10% Notes have substantially the same terms, covenants and events of default as the EFIH 6.875% Notes. The holders of the EFIH 10% Notes vote as a separate class from the holders of the EFIH 6.875% Notes.
EFIH 11% Senior Secured Second Lien Notes — At September 30, 2013, the principal amount of the EFIH 11% Notes totaled $406 million. The notes mature in October 2021, with interest payable in cash semiannually in arrears on May 15 and November 15 at a fixed rate of 11% per annum. The EFIH 11% Notes are secured on a second-priority basis by the EFIH Collateral on an equal and ratable basis with the EFIH 11.75% Notes.
The EFIH 11% Notes are senior obligations of EFIH and EFIH Finance and rank equally in right of payment with all senior indebtedness of EFIH and are effectively senior in right of payment to all existing or future unsecured debt of EFIH to the extent of the value of the EFIH Collateral. The notes have substantially the same terms, covenants and events of default as the EFIH 11.75% Notes discussed below, and the holders of the EFIH 11% Notes will generally vote as a single class with the holders of the EFIH 11.75% Notes.
EFIH 11.75% Senior Secured Second Lien Notes — At September 30, 2013, the principal amount of the EFIH 11.75% Notes totaled $1.750 billion. These notes mature in March 2022, with interest payable in cash semiannually in arrears on March 1 and September 1 at a fixed rate of 11.75% per annum. The EFIH 11.75% Notes are secured on a second-priority basis by the EFIH Collateral on an equal and ratable basis with the EFIH 11% Notes. The EFIH 11.75% Notes have substantially the same covenants as the EFIH 11% Notes, and the holders of the EFIH 11.75% Notes will generally vote as a single class with the holders of the EFIH 11% Notes.
The EFIH 11.75% Notes were issued in private placements and are not registered under the Securities Act. EFIH has agreed to use its commercially reasonable efforts to register with the SEC notes having substantially identical terms as the EFIH 11.75% Notes (except for provisions relating to transfer restrictions and payment of additional interest) as part of an offer to exchange freely tradable notes for the EFIH 11.75% Notes. Because the exchange offer has not yet been completed, the annual interest rate on the EFIH 11.75% Notes increased by 25 basis points (to 12.00%) on February 5, 2013 and by an additional 25 basis points (to 12.25%) on May 6, 2013. The interest rate on the EFIH 11.75% Notes will remain at that level until completion of the exchange offer, at which time the interest rate on the notes will revert to 11.75%.
EFIH 11.25/12.25% Senior Toggle Notes — At September 30, 2013, the principal amount of the EFIH Toggle Notes totaled $1.476 billion. These notes mature in December 2018, with interest payable semiannually in arrears on June 1 and December 1 at a fixed rate of 11.25% per annum for cash interest and 12.25% per annum for PIK Interest. For any interest period until June 1, 2016, EFIH may elect to pay interest on the Toggle Notes (i) entirely in cash; (ii) by increasing the principal amount of the notes or by issuing new EFIH Toggle Notes (PIK Interest); or (iii) 50% in cash and 50% in PIK Interest. Once EFIH makes a PIK election, which it did effective with the June 1, 2013 interest payment, the election is valid for each succeeding interest payment period until EFIH revokes the election.
The EFIH Toggle Notes were issued in private placements and are not registered under the Securities Act. EFIH has agreed to use its commercially reasonable efforts to register with the SEC notes having substantially identical terms as the EFIH Toggle Notes (except for provisions relating to transfer restrictions and payment of additional interest) as part of an offer to exchange freely tradable notes for the EFIH Toggle Notes. If an exchange offer for the notes is not completed within 365 days after the date (December 5, 2012) the initial EFIH Toggle notes were issued (a Registration Default), the annual interest rate on the notes will increase by 25 basis points for the first 90-day period during which a Registration Default continues, and thereafter, the annual interest rate on the notes will increase by 50 basis points for the remaining period during which the Registration Default continues. If the Registration Default is cured, the interest rate on the notes will revert to the original level.
EFH Corp. 10.875% Senior Notes and 11.25/12.00% Senior Toggle Notes — At September 30, 2013, the collective principal amount of these notes totaled $60 million. The notes are fully and unconditionally guaranteed on a joint and several senior unsecured basis by EFCH and EFIH. The notes mature in November 2017, with interest payable in cash semi-annually in arrears on May 1 and November 1 at a fixed rate for the 10.875% Notes of 10.875% per annum and at a fixed rate for the Toggle Notes of 11.25% per annum.
Fair Value of Long-Term Debt
At September 30, 2013 and December 31, 2012, the estimated fair value of our long-term debt (excluding capital leases) totaled $23.625 billion and $25.890 billion, respectively, and the carrying amount totaled $38.068 billion and $37.854 billion, respectively. At September 30, 2013 and December 31, 2012, the estimated fair value of our short-term borrowings under the TCEH Revolving Credit Facilities totaled $1.371 billion and $1.500 billion, respectively, and the carrying amount totaled $2.054 billion. We determine fair value in accordance with accounting standards as discussed in Note 8, and at September 30, 2013, our debt fair value represents Level 2 valuations. We obtain security pricing from a vendor who uses broker quotes and third-party pricing services to determine fair values. Where relevant, these prices are validated through subscription services such as Bloomberg.
TCEH Interest Rate Swap Transactions
TCEH employs interest rate swaps to hedge exposure to its variable rate debt. As reflected in the table below, at September 30, 2013, TCEH has entered into the following series of interest rate swap transactions that effectively fix the interest rates at between 5.5% and 9.3%.
Fixed Rates					Expiration Dates		Notional Amount
5.5	%	-	9.30%		October 2013 through October 2014			$	18.14		billion (a)
6.8	%	-	9.00%		October 2015 through October 2017			$	12.6		billion (b)
___________
(a)	Swaps related to an aggregate $1.6 billion principal amount of debt expired in 2013. Per the terms of the transactions, the notional amount of swaps entered into in 2011 grew by $1.280 billion in 2013, substantially offsetting the expired swaps.
(b)	These swaps are effective from October 2014 through October 2017. The $12.6 billion notional amount of swaps includes $3 billion that expires in October 2015 with the remainder expiring in October 2017.
TCEH has also entered into interest rate basis swap transactions that further reduce the fixed borrowing costs achieved through the interest rate swaps. Basis swaps in effect at September 30, 2013 totaled $11.967 billion notional amount. The basis swaps relate to debt outstanding through 2014.
The interest rate swap counterparties are secured on an equal and ratable basis by the same collateral pledged to the lenders under the TCEH Senior Secured Facilities and the TCEH Senior Secured Notes.
The interest rate swaps have resulted in net gains (losses) reported in interest expense and related charges as follows:
	Three Months Ended September 30,								Nine Months Ended September 30,
	2013				2012				2013				2012
Realized net loss	$	(160	)		$	(168	)		$	(466	)		$	(505	)
Unrealized net gain (loss)	413				(20		)		899				(16		)
Total	$	253			$	(188	)		$	433			$	(521	)
The cumulative unrealized mark-to-market net liability related to all TCEH interest rate swaps totaled $1.167 billion and $2.065 billion at September 30, 2013 and December 31, 2012, respectively, of which $57 million and $65 million (both pretax), respectively, were reported in accumulated other comprehensive income. See Note 8.

Commitments_And_Contingencies

Commitments And Contingencies	9 Months Ended
	Sep. 30, 2013
Commitments and Contingencies Disclosure [Abstract]	'
Commitments And Contingencies	'
	COMMITMENTS AND CONTINGENCIES
	Guarantees
	We have entered into contracts that contain guarantees to unaffiliated parties that could require performance or payment under certain conditions. Material guarantees are discussed below.
	Disposed TXU Gas Company operations — In connection with the sale of the assets of TXU Gas Company to Atmos Energy Corporation (Atmos) in October 2004, EFH Corp. agreed to indemnify Atmos, until October 1, 2014, for up to $500 million for any liability related to assets retained by TXU Gas Company, including certain inactive gas plant sites not acquired by Atmos, and up to $1.4 billion for contingent liabilities associated with preclosing tax and employee related matters. The maximum aggregate amount under these indemnities that we may be required to pay is $1.9 billion. To date, we have not been required to make any payments to Atmos under any of these indemnity obligations, and no such payments are currently anticipated.
	See Note 5 for discussion of guarantees and security for certain of our debt.
	Letters of Credit
	At September 30, 2013, TCEH had outstanding letters of credit under its credit facilities totaling $776 million as follows:
	•	$353 million to support risk management and trading margin requirements in the normal course of business, including over-the-counter hedging transactions and collateral postings with ERCOT;
	•	$208 million to support floating rate pollution control revenue bond debt with an aggregate principal amount of $204 million (the letters of credit are available to fund the payment of such debt obligations and expire in 2014);
	•	$65 million to support TCEH's REP financial requirements with the PUCT, and
	•	$150 million for miscellaneous credit support requirements.
	Litigation
	Aurelius Capital Master, Ltd. and ACP Master, Ltd. (Aurelius) filed a lawsuit in March 2013, amended in May 2013, in the United States District Court for the Northern District of Texas (Dallas Division) against EFCH as a nominal defendant and each of the current directors and a former director of EFCH. In the lawsuit, Aurelius, as a creditor under the TCEH Senior Secured Facilities and certain TCEH secured bonds, both of which are guaranteed by EFCH, filed a derivative claim against EFCH and its directors. Aurelius alleges that the directors of EFCH breached their fiduciary duties to EFCH and its creditors, including Aurelius, by permitting TCEH to make certain loans "without collecting fair and reasonably equivalent value." The lawsuit seeks recovery for the benefit of EFCH. EFCH and the directors have filed a motion to dismiss this lawsuit, which has been fully briefed and is pending before the district court. We cannot predict the outcome of this proceeding, including the financial effects, if any.
	Litigation Related to Generation Facilities — In November 2010, an administrative appeal challenging the decision of the TCEQ to renew and amend Oak Grove Management Company LLC's (Oak Grove) (a wholly owned subsidiary of TCEH) Texas Pollutant Discharge Elimination System (TPDES) permit related to water discharges was filed by Robertson County: Our Land, Our Lives and Roy Henrichson in the Travis County, Texas District Court. Plaintiffs sought a reversal of the TCEQ's order and a remand back to the TCEQ for further proceedings. The district court affirmed the TCEQ's issuance of the TPDES permit to Oak Grove. In December 2012, plaintiffs appealed the district court's decision to the Third Court of Appeals in Austin, Texas. The case has been fully briefed, but the Court has not issued a decision and no date for oral argument has been scheduled. While we cannot predict the timing or outcome of this proceeding, we believe the renewal and amendment of the Oak Grove TPDES permit are protective of the environment and were in accordance with applicable law.
	In September 2010, the Sierra Club filed a lawsuit in the United States District Court for the Eastern District of Texas (Texarkana Division) against EFH Corp. and Luminant Generation Company LLC (a wholly owned subsidiary of TCEH) for alleged violations of the Clean Air Act (CAA) at Luminant's Martin Lake generation facility. In May 2012, the Sierra Club filed a lawsuit in the US District Court for the Western District of Texas (Waco Division) against EFH Corp. and Luminant Generation Company LLC for alleged violations of the CAA at Luminant's Big Brown generation facility. The Big Brown case is currently scheduled for trial in February 2014. The Martin Lake case does not have a trial date. While we are unable to estimate any possible loss or predict the outcome, we believe that the Sierra Club's claims are without merit, and we intend to vigorously defend these lawsuits. In addition, in December 2010 and again in October 2011, the Sierra Club informed Luminant that it may sue Luminant for allegedly violating CAA provisions in connection with Luminant's Monticello generation facility. In May 2012, the Sierra Club informed us that it may sue us for allegedly violating CAA provisions in connection with Luminant's Sandow 4 generation facility. While we cannot predict whether the Sierra Club will actually file suit regarding Monticello or Sandow 4 or the outcome of any resulting proceedings, we believe we have complied with the requirements of the CAA at all of our generation facilities.
	Litigation Related to EPA Reviews — In June 2008, the EPA issued an initial request for information to TCEH under the EPA's authority under Section 114 of the CAA. The stated purpose of the request is to obtain information necessary to determine compliance with the CAA, including New Source Review Standards and air permits issued by the TCEQ for the Big Brown, Monticello and Martin Lake generation facilities. In April 2013, we received an additional information request from the EPA under Section 114 related to the Big Brown, Martin Lake and Monticello facilities as well as an initial information request related to the Sandow 4 generation facility. Historically, as the EPA has pursued its New Source Review enforcement initiative, companies that have received a large and broad request under Section 114, such as the request received by TCEH, have in many instances subsequently received a notice of violation from the EPA, which has in some cases progressed to litigation or settlement.
	In July 2012, the EPA sent us a notice of violation alleging noncompliance with the CAA's New Source Review Standards and the air permits at our Martin Lake and Big Brown generation facilities. In September 2012, we filed a petition for review in the United States Court of Appeals for the Fifth Circuit (Fifth Circuit Court) seeking judicial review of the EPA's notice of violation. Given recent legal precedent subjecting agency orders like the notice of violation to judicial review, we filed the petition for review to preserve our ability to challenge the EPA's issuance of the notice and its defects. In October 2012, the EPA filed a motion to dismiss our petition. In December 2012, the Fifth Circuit Court issued an order that will delay a ruling on the EPA's motion to dismiss until after the case has been fully briefed and oral argument, if any, is held.
	In July 2013, the EPA sent us a second notice of violation alleging noncompliance with the CAA's New Source Review Standards at our Martin Lake and Big Brown generation facilities. In July 2013, we filed a petition for review in the Fifth Circuit Court seeking judicial review of the EPA's July 2013 notice of violation. In September 2013, the Fifth Circuit Court consolidated the petitions for review of the July 2012 and July 2013 notices of violation and established a briefing schedule for the consolidated cases.
	In August 2013, the United States Department of Justice, acting as the attorneys for the EPA, filed a civil enforcement lawsuit against Luminant Generation Company LLC and Big Brown Power Company LLC in federal district court in Dallas, alleging violations of the CAA at our Big Brown and Martin Lake generation facilities. In September 2013, we filed a motion to stay this lawsuit pending the outcome of the Fifth Circuit Court's review of the July 2012 and July 2013 notices of violation. We believe that we have complied with all requirements of the CAA and intend to vigorously defend these allegations. We cannot predict the outcome of these proceedings, including the financial effects, if any.
	Cross-State Air Pollution Rule (CSAPR)
	In July 2011, the EPA issued the CSAPR, compliance with which would have required significant additional reductions of sulfur dioxide (SO2) and nitrogen oxides (NOx) emissions from our fossil-fueled generation units. In September 2011, we filed a petition for review in the US Court of Appeals for the District of Columbia Circuit (D.C. Circuit Court) challenging the CSAPR as it applies to Texas. If the CSAPR had taken effect, it would have caused us to, among other actions, idle two lignite/coal-fueled generation units and cease certain lignite mining operations by the end of 2011.
	In February 2012, the EPA released a final rule (Final Revisions) and a proposed rule revising certain aspects of the CSAPR, including increases in the emissions budgets for Texas and our generation assets as compared to the July 2011 version of the rule. In April 2012, we filed in the D.C. Circuit Court a petition for review of the Final Revisions on the ground, among others, that the rules do not include all of the budget corrections we requested from the EPA. The parties to the case agreed that the case should be held in abeyance pending the conclusion of the CSAPR rehearing proceeding discussed below. In June 2012, the EPA finalized the proposed rule (Second Revised Rule). As compared to the proposed revisions to the CSAPR issued by the EPA in October 2011, the Final Revisions and the Second Revised Rule finalize emissions budgets for our generation assets that are approximately 6% lower for SO2, 3% higher for annual NOx and 2% higher for seasonal NOx.
	In August 2012, the D.C. Circuit Court vacated the CSAPR, remanding it to the EPA for further proceedings. As a result, the CSAPR, the Final Revisions and the Second Revised Rule do not impose any immediate requirements on us, the State of Texas, or other affected parties. The D.C. Circuit Court's order stated that the EPA was expected to continue administering the CAIR (the predecessor rule to the CSAPR) pending the EPA's further consideration of the rule. In October 2012, the EPA and certain other parties that supported the CSAPR filed petitions with the D.C. Circuit Court seeking review by the full court of the panel's decision to vacate and remand the CSAPR. In January 2013, the D.C. Circuit Court denied these requests for rehearing, concluding the CSAPR rehearing proceeding. In March 2013, the EPA and certain other parties that supported the CSAPR submitted petitions to the US Supreme Court seeking its review of the D.C. Circuit Court decision. In June 2013, the US Supreme Court granted review of the D.C. Circuit Court's decision. The court is scheduled to hear oral arguments in the case in December 2013. We cannot predict the outcome of the review by the US Supreme Court.
	State Implementation Plan (SIP)
	In September 2010, the EPA disapproved a portion of the SIP pursuant to which the TCEQ implements its program to achieve the requirements of the CAA. The EPA disapproved the Texas standard permit for pollution control projects (PCP). We hold several permits issued pursuant to the TCEQ standard permit conditions for pollution control projects. We challenged the EPA's disapproval by filing a lawsuit in the Fifth Circuit Court arguing that the TCEQ's adoption of the standard permit conditions for pollution control projects was consistent with the CAA. In March 2012, the Fifth Circuit Court vacated the EPA's disapproval of the Texas standard permit for pollution control projects and remanded the matter to the EPA for expedited reconsideration. In September 2013, the State of Texas filed a motion with the Fifth Circuit Court requesting that the Court amend and enforce its judgment in this case by requiring the EPA to satisfy the Court's judgment by taking action on the pending SIP revision regarding Texas' PCP standard permit no later than December 31, 2013. We cannot predict the timing or outcome of the EPA's reconsideration, including the financial effects, if any.
	In November 2010, the EPA disapproved a different portion of the SIP under which the TCEQ had been phasing out a long-standing exemption for certain emissions that unavoidably occur during startup, shutdown and maintenance activities and replacing that exemption with a more limited affirmative defense that will itself be phased out and replaced by TCEQ-issued generation facility-specific permit conditions. We, like many other electricity generation facility operators in Texas, have asserted applicability of the exemption or affirmative defense, and the TCEQ has not objected to that assertion. We have also applied for and received the generation facility-specific permit amendments. We challenged the EPA's disapproval of Texas' affirmative defense for planned maintenance, startup and shutdown by filing a lawsuit in the Fifth Circuit Court arguing that the TCEQ's adoption of the affirmative defense and phase-out of that affirmative defense as permits are issued is consistent with the CAA. In July 2012, the Fifth Circuit Court denied our challenge and ruled that the EPA's actions were in accordance with the CAA. In October 2012, the Fifth Circuit Court panel withdrew its opinion and issued a second, expanded opinion that again upheld the EPA's disapproval. In November 2012, we filed a petition with the Fifth Circuit Court asking for review by the full Fifth Circuit Court of the panel's second opinion. Other parties to the proceedings also filed a petition with the Fifth Circuit Court asking the panel to reconsider its decision. In March 2013, the Fifth Circuit Court panel withdrew its second opinion and issued a third opinion that again upheld the EPA's actions. In April 2013, the Fifth Circuit Court also denied our November 2012 petition for rehearing of the panel's second opinion and denied the request by other parties for the panel to reconsider its second decision. Following the issuance of the mandate, we filed a motion to recall the mandate, which was denied in a single-judge order. In June 2013, we submitted a petition to the US Supreme Court seeking its review of the Fifth Circuit Court's decision to uphold EPA's disapproval of Texas' affirmative defense for planned maintenance, startup and shutdown. In October 2013, the US Supreme Court denied our petition for review of that portion of the Fifth Circuit Court's decision. The decision is not anticipated to have a material effect on our results of operations, liquidity or financial condition.
	Other Matters
	We are involved in various legal and administrative proceedings in the normal course of business, the ultimate resolutions of which, in the opinion of management, are not anticipated to have a material effect on our results of operations, liquidity or financial condition.

Equity

Equity	9 Months Ended
	Sep. 30, 2013
Stockholders' Equity Note [Abstract]	'
Equity	'
	EQUITY
	Dividend Restrictions
	EFH Corp. has not declared or paid any dividends since the Merger.
	The indenture governing the EFH Corp. 10.875% Notes and EFH Corp. Toggle Notes includes covenants that, among other things and subject to certain exceptions, restrict our ability to pay dividends or make other distributions in respect of our common stock. Accordingly, our net income is restricted from being used to make distributions on our common stock unless such distributions are expressly permitted under these indentures and/or on a pro forma basis, after giving effect to such distribution, EFH Corp.'s consolidated leverage ratio is equal to or less than 7.0 to 1.0. For purposes of this calculation, "consolidated leverage ratio" is defined as the ratio of consolidated total debt (as defined in the indenture) to Adjusted EBITDA, in each case, consolidated with its subsidiaries other than Oncor Holdings and its subsidiaries. EFH Corp.'s consolidated leverage ratio was 12.3 to 1.0 at September 30, 2013.
	The indentures governing the EFIH Notes generally restrict EFIH from making any cash distribution to EFH Corp. for the ultimate purpose of making a cash dividend on our common stock unless at the time, and after giving effect to such dividend, EFIH's consolidated leverage ratio is equal to or less than 6.0 to 1.0. Under the indentures governing the EFIH Notes, the term "consolidated leverage ratio" is defined as the ratio of EFIH's consolidated total debt (as defined in the indentures) to EFIH's Adjusted EBITDA on a consolidated basis (including Oncor's Adjusted EBITDA). EFIH's consolidated leverage ratio was 7.7 to 1.0 at September 30, 2013. In addition, the EFIH Notes generally restrict EFIH's ability to make distributions or loans to EFH Corp., unless such distributions or loans are expressly permitted under the indentures governing the EFIH Notes.
	The TCEH Senior Secured Facilities generally restrict TCEH from making any cash distribution to any of its parent companies for the ultimate purpose of making a cash dividend on our common stock unless at the time, and after giving effect to such distribution, TCEH's consolidated total debt (as defined in the TCEH Senior Secured Facilities) to Adjusted EBITDA would be equal to or less than 6.5 to 1.0. At September 30, 2013, the ratio was 10.6 to 1.0.
	In addition, the TCEH Senior Secured Facilities and indentures governing the TCEH Senior Notes, TCEH Senior Secured Notes and TCEH Senior Secured Second Lien Notes generally restrict TCEH's ability to make distributions or loans to any of its parent companies, EFCH and EFH Corp., unless such distributions or loans are expressly permitted under the TCEH Senior Secured Facilities and the indentures governing such notes.
	Under applicable law, we are also prohibited from paying any dividend to the extent that immediately following payment of such dividend, there would be no statutory surplus or we would be insolvent.
	Noncontrolling Interests
	As discussed in Note 2, we consolidate a joint venture formed in 2009 for the purpose of developing two new nuclear generation units, which results in a noncontrolling interests component of equity. Net loss attributable to the noncontrolling interests was immaterial for the nine months ended September 30, 2013 and 2012.
	Equity
	The following table presents the changes to equity for the nine months ended September 30, 2013:
		EFH Corp. Shareholders’ Equity
		Common Stock (a)			Additional Paid-in Capital			Retained Earnings (Deficit)			Accumulated Other Comprehensive Income (Loss)			Noncontrolling Interests		Total Equity
	Balance at December 31, 2012	$	2		$	7,959		$	(18,939	)	$	(47	)	$	102	$	(10,923	)
	Net loss	—			—			(635		)	—			—		(635		)
	Effects of stock-based incentive compensation plans	—			5			—			—			—		5
	Repurchases of stock	—			(5		)	—			—			—		(5		)
	Change in unrecognized losses related to pension and OPEB plans (Note 10)	—			—			—			(4		)	—		(4		)
	Net effects of cash flow hedges	—			—			—			5			—		5
	Net effects related to Oncor	—			—			—			1			—		1
	Investment by noncontrolling interests	—			—			—			—			3		3
	Other	—			2			—			—			—		2
	Balance at September 30, 2013	$	2		$	7,961		$	(19,574	)	$	(45	)	$	105	$	(11,551	)
	____________
	(a)	Authorized shares totaled 2,000,000,000 at September 30, 2013. Outstanding shares totaled 1,669,861,383 and 1,680,539,245 at September 30, 2013 and December 31, 2012, respectively.
	The following table presents the changes to equity for the nine months ended September 30, 2012:
		EFH Corp. Shareholders’ Equity
		Common Stock (a)			Additional Paid-in Capital			Retained Earnings (Deficit)			Accumulated Other Comprehensive Income (Loss)			Noncontrolling Interests		Total Equity
	Balance at December 31, 2011	$	2		$	7,947		$	(15,579	)	$	(222	)	$	95	$	(7,757	)
	Net loss	—			—			(1,408		)	—			—		(1,408		)
	Effects of stock-based incentive compensation plans	—			11			—			—			—		11
	Change in unrecognized losses related to pension and OPEB plans	—			—			—			(25		)	—		(25		)
	Net effects of cash flow hedges	—			—			—			5			—		5
	Net effects related to Oncor	—			—			—			2			—		2
	Investment by noncontrolling interests	—			—			—			—			6		6
	Balance at September 30, 2012	$	2		$	7,958		$	(16,987	)	$	(240	)	$	101	$	(9,166	)
	____________
	(a)	Authorized shares totaled 2,000,000,000 at September 30, 2012. Outstanding shares totaled 1,680,539,245 and 1,679,539,245 at September 30, 2012 and December 31, 2011, respectively.
	Accumulated Other Comprehensive Income (Loss)
	The following table presents the changes to accumulated other comprehensive income (loss) for the nine months ended September 30, 2013. There was no other comprehensive income (loss) before reclassification for the period.
		Dedesignated Cash Flow Hedges – Interest Rate Swaps (Note 9)			Pension and Other Postretirement Employee Benefit Liabilities Adjustments (Note 10)			Accumulated Other Comprehensive Income (Loss)
	Balance at December 31, 2012	$	(64	)	$	17		$	(47	)
	Amounts reclassified from accumulated other comprehensive income (loss) and reported in:
	Operating costs	—			(4		)	(4		)
	Depreciation and amortization	2			—			2
	Selling, general and administrative expenses	—			(2		)	(2		)
	Interest expense and related charges	6			—			6
	Equity in earnings of unconsolidated subsidiaries	2			(1		)	1
	Income tax benefit (expense)	(3		)	2			(1		)
	Total amount reclassified from accumulated other comprehensive income (loss) during the period	7			(5		)	2
	Balance at September 30, 2013	$	(57	)	$	12		$	(45	)

Fair_Value_Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2013
Fair Value Disclosures [Abstract]	'
Fair Value Measurements	'
	FAIR VALUE MEASUREMENTS
	Accounting standards related to the determination of fair value define fair value 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. We use a "mid-market" valuation convention (the mid-point price between bid and ask prices) as a practical expedient to measure fair value for the majority of our assets and liabilities subject to fair value measurement on a recurring basis. We primarily use the market approach for recurring fair value measurements and use valuation techniques to maximize the use of observable inputs and minimize the use of unobservable inputs.
	We categorize our assets and liabilities recorded at fair value based upon the following fair value hierarchy:
	•	Level 1 valuations use quoted prices in active markets for identical assets or liabilities that are accessible at the measurement date. An active market is a market in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing information on an ongoing basis. Our Level 1 assets and liabilities include exchange-traded commodity contracts. For example, some of our derivatives are NYMEX or ICE futures and swaps transacted through clearing brokers for which prices are actively quoted.
	•	Level 2 valuations use inputs that, in the absence of actively quoted market prices, are observable for the asset or liability, either directly or indirectly. Level 2 inputs include: (a) quoted prices for similar assets or liabilities in active markets, (b) quoted prices for identical or similar assets or liabilities in markets that are not active, (c) inputs other than quoted prices that are observable for the asset or liability such as interest rates and yield curves observable at commonly quoted intervals and (d) inputs that are derived principally from or corroborated by observable market data by correlation or other means. Our Level 2 valuations utilize over-the-counter broker quotes, quoted prices for similar assets or liabilities that are corroborated by correlations or other mathematical means and other valuation inputs. For example, our Level 2 assets and liabilities include forward commodity positions at locations for which over-the-counter broker quotes are available.
	•	Level 3 valuations use unobservable inputs for the asset or liability. Unobservable inputs are used to the extent observable inputs are not available, thereby allowing for situations in which there is little, if any, market activity for the asset or liability at the measurement date. We use the most meaningful information available from the market combined with internally developed valuation methodologies to develop our best estimate of fair value. For example, our Level 3 assets and liabilities include certain derivatives whose values are derived from pricing models that utilize multiple inputs to the valuations, including inputs that are not observable or easily corroborated through other means. See further discussion below.
	Our valuation policies and procedures are developed, maintained and validated by a centralized risk management group that reports to the Chief Financial Officer, who also functions as the Chief Risk Officer. Risk management functions include commodity price reporting and validation, valuation model validation, risk analytics, risk control, credit risk management and risk reporting.
	We utilize several different valuation techniques to measure the fair value of assets and liabilities, relying primarily on the market approach of using prices and other market information for identical and/or comparable assets and liabilities for those items that are measured on a recurring basis. These methods include, among others, the use of broker quotes and statistical relationships between different price curves.
	In utilizing broker quotes, we attempt to obtain multiple quotes from brokers (generally non-binding) that are active in the commodity markets in which we participate (and require at least one quote from two brokers to determine a pricing input as observable); however, not all pricing inputs are quoted by brokers. The number of broker quotes received for certain pricing inputs varies depending on the depth of the trading market, each individual broker's publication policy, recent trading volume trends and various other factors. In addition, for valuation of interest rate swaps, we use generally accepted interest rate swap valuation models utilizing month-end interest rate curves.
	Probable loss of default by either us or our counterparties is considered in determining the fair value of derivative assets and liabilities. These non-performance risk adjustments take into consideration credit enhancements and the credit risks associated with our credit standing and the credit standing of our counterparties (see Note 9 for additional information regarding credit risk associated with our derivatives). We utilize published credit ratings, default rate factors and bond trading values in calculating these fair value measurement adjustments.
	Certain derivatives and financial instruments are valued utilizing option pricing models that take into consideration multiple inputs including, but not limited to, commodity prices, volatility factors, discount rates and other market based factors. Additionally, when there is not a sufficient amount of observable market data, valuation models are developed that incorporate proprietary views of market factors. Significant unobservable inputs used to develop the valuation models include volatility curves, correlation curves, illiquid pricing locations and credit/non-performance risk assumptions. Those valuation models are generally used in developing long-term forward price curves for certain commodities. We believe the development of such curves is consistent with industry practice; however, the fair value measurements resulting from such curves are classified as Level 3.
	The significant unobservable inputs and valuation models are developed by employees trained and experienced in market operations and fair value measurement and validated by the company's risk management group, which also further analyzes any significant changes in Level 3 measurements. Significant changes in the unobservable inputs could result in significant upward or downward changes in the fair value measurement.
	With respect to amounts presented in the following fair value hierarchy tables, the fair value measurement of an asset or liability (e.g., a contract) is required to fall in its entirety in one level, based on the lowest level input that is significant to the fair value measurement. Certain assets and liabilities would be classified in Level 2 instead of Level 3 of the hierarchy except for the effects of credit reserves and non-performance risk adjustments, respectively. Assessing the significance of a particular input to the fair value measurement in its entirety requires judgment, considering factors specific to the asset or liability being measured.
	Assets and liabilities measured at fair value consisted of the following:
	30-Sep-13
		Level 1			Level 2				Level 3 (a)				Reclassification (b)				Total
	Assets:
	Commodity contracts	$	140		$	941			$	48			$	2			$	1,131
	Interest rate swaps	—			84				—				—				84
	Nuclear decommissioning trust –	299			172				—				—				471
	equity securities (c)
	Nuclear decommissioning trust –	—			266				—				—				266
	debt securities (c)
	Total assets	$	439		$	1,463			$	48			$	2			$	1,952
	Liabilities:
	Commodity contracts	$	129		$	26			$	52			$	2			$	209
	Interest rate swaps	—			97				1,167				—				1,264
	Total liabilities	$	129		$	123			$	1,219			$	2			$	1,473
	31-Dec-12
		Level 1			Level 2				Level 3 (a)				Total
	Assets:
	Commodity contracts	$	180		$	1,784			$	83			$	2,047
	Interest rate swaps	—			134				—				134
	Nuclear decommissioning trust – equity securities (c)	249			144				—				393
	Nuclear decommissioning trust – debt securities (c)	—			261				—				261
	Total assets	$	429		$	2,323			$	83			$	2,835
	Liabilities:
	Commodity contracts	$	208		$	121			$	54			$	383
	Interest rate swaps	—			2,217				—				2,217
	Total liabilities	$	208		$	2,338			$	54			$	2,600
	____________
	(a)	See table below for description of Level 3 assets and liabilities.
	(b)	Fair values are determined on a contract basis, but certain contracts result in a current asset and a noncurrent liability, or vice versa, as presented in the balance sheet.
	(c)	The nuclear decommissioning trust investment is included in the other investments line in the balance sheet. See Note 13.
	Commodity contracts consist primarily of natural gas, electricity, fuel oil, uranium and coal derivative instruments entered into for hedging purposes and include physical contracts that have not been designated "normal" purchases or sales. See Note 9 for further discussion regarding the company's use of derivative instruments.
	Interest rate swaps include variable-to-fixed rate swap instruments that are economic hedges of interest on long-term debt as well as interest rate basis swaps designed to effectively reduce the hedged borrowing costs. See Note 5 for discussion of interest rate swaps.
	Nuclear decommissioning trust assets represent securities held for the purpose of funding the future retirement and decommissioning of the nuclear generation units. These investments include equity, debt and other fixed-income securities consistent with investment rules established by the NRC and the PUCT.
	There were no significant transfers between Level 1 and Level 2 of the fair value hierarchy for the three and nine months ended September 30, 2013 and 2012. See the table of changes in fair values of Level 3 assets and liabilities below for discussion of transfers between Level 2 and Level 3.
	The following tables present the fair value of the Level 3 assets and liabilities by major contract type and the significant unobservable inputs used in the valuations at September 30, 2013 and December 31, 2012:
	30-Sep-13
			Fair Value
	Contract Type (a)		Assets			Liabilities				Total				Valuation Technique		Significant Unobservable Input		Range (b)
	Electricity purchases and sales		$	5		$	(2	)		$	3			Valuation Model		Illiquid pricing locations (c)		$30 to $45/ MWh
																Hourly price curve shape (d)		$20 to $70/ MWh
	Electricity spread options		—			(19		)		(19		)		Option Pricing Model		Gas to power correlation (e)		45% to 100%
																Power volatility (f)		10% to 30%
	Electricity congestion revenue rights		37			(5		)		32				Market Approach (g)		Illiquid price differences between settlement points (h)		$0.00 to $30.00
	Coal purchases		1			(12		)		(11		)		Market Approach (g)		Illiquid price variances between mines (i)		$0.00 to $1.00
																Probability of default (j)		0% to 40%
																Recovery rate (k)		0% to 40%
	Interest rate swaps		—			(1,167		)		(1,167		)		Valuation Model		Nonperformance risk adjustment (l)		30% to 35%
	Other		5			(14		)		(9		)
	Total		$	48		$	(1,219	)		$	(1,171	)
31-Dec-12
		Fair Value
Contract Type (a)		Assets			Liabilities				Total				Valuation Technique		Significant Unobservable Input		Range (b)
Electricity purchases and sales		$	5		$	(9	)		$	(4	)		Valuation Model		Illiquid pricing locations (c)		$20 to $40/ MWh
															Hourly price curve shape (d)		$20 to $50/ MWh
Electricity spread options		34			(10		)		24				Option Pricing Model		Gas to power correlation (e)		20% to 90%
															Power volatility (f)		20% to 40%
Electricity congestion revenue rights		41			(2		)		39				Market Approach (g)		Illiquid price differences between settlement points (h)		$0.00 to $0.50
Coal purchases		—			(32		)		(32		)		Market Approach (g)		Illiquid price variances between mines (i)		$0.00 to $1.00
															Probability of default (j)		5% to 40%
															Recovery rate (k)		0% to 40%
Other		3			(1		)		2
Total		$	83		$	(54	)		$	29
____________
(a)	Electricity purchase and sales contracts include wind generation agreements and hedging positions in the ERCOT west region as well as power contracts, the valuations of which include unobservable inputs related to the hourly shaping of the price curve. Electricity spread option contracts consist of physical electricity call options. Electricity congestion revenue rights contracts consist of forward purchase contracts (swaps and options) used to hedge electricity price differences between settlement points within ERCOT. Coal purchase contracts relate to western (Powder River Basin) coal. Interest rate swaps are held by TCEH to hedge exposure to its variable rate debt.
(b)	The range of the inputs may be influenced by factors such as time of day, delivery period, season and location.
(c)	Based on the historical range of forward average monthly ERCOT West Hub prices.
(d)	Based on the historical range of forward average hourly ERCOT North Hub prices.
(e)	Estimate of the historical range based on forward natural gas and on-peak power prices for the ERCOT hubs most relevant to our spread options.
(f)	Based on historical forward price changes.
(g)	While we use the market approach, there is either insufficient market data to consider the valuation liquid or the significance of credit reserves or non-performance risk adjustments results in a Level 3 designation.
(h)	Based on the historical price differences between settlement points in the ERCOT North Hub and the ERCOT West Hub.
(i)	Based on the historical range of price variances between mine locations.
(j)	Estimate of the range of probabilities of default based on past experience and the length of the contract as well as our and counterparties' credit ratings.
(k)	Estimate of the default recovery rate based on historical corporate rates.
(l)	Estimate of nonperformance risk adjustment based on TCEH senior secured bond trading values. See discussion immediately below regarding transfers into Level 3.
The following table presents the changes in fair value of the Level 3 assets and liabilities for the three and nine months ended September 30, 2013 and 2012. Transfers into Level 3 during 2013 as noted below reflect a nonperformance risk adjustment in the valuation of the TCEH interest rate swaps, which are secured by a first-lien interest in the same assets of TCEH (on a pari passu basis) with the TCEH Senior Secured Facilities and the TCEH Senior Secured Notes (see Note 5). At September 30, 2013, the estimated fair value of these interest rate swaps totaled $1.518 billion before consideration of nonperformance risk adjustment and $1.167 billion after consideration of such adjustment. The amount of the nonperformance risk adjustment was after consideration of derivative assets related to contracts with the same counterparties that are also secured by a first-lien interest in the assets of TCEH, and a master netting agreement is in place that provides for netting and setoff of amounts related to these contracts.
	Three Months Ended September 30,							Nine Months Ended September 30,
	2013			2012				2013				2012
Net asset balance at beginning of period	$	88		$	12			$	29			$	53
Total unrealized valuation gains (losses)	(24		)	12				(41		)		(5		)
Purchases, issuances and settlements (a):
Purchases	6			17				66				30
Issuances	—			(4		)		(6		)		(15		)
Settlements	(62		)	(56		)		(45		)		(34		)
Transfers into Level 3 (b)	(1,179		)	3				(1,178		)		(42		)
Transfers out of Level 3 (b)	—			—				4				(3		)
Net change (c)	(1,259		)	(28		)		(1,200		)		(69		)
Net liability balance at end of period	$	(1,171	)	$	(16	)		$	(1,171	)		$	(16	)
Unrealized valuation gains (losses) relating to instruments held at end of period	$	254		$	15			$	280			$	(22	)
____________
(a)	Settlements reflect reversals of unrealized mark-to-market valuations previously recognized in net income. Purchases and issuances reflect option premiums paid or received.
(b)	Includes transfers due to changes in the observability of significant inputs. Transfers in and out occur at the end of each quarter, which is when the assessments are performed. All Level 3 transfers during the periods presented are in and out of Level 2.
(c)	Substantially all changes in values of commodity contracts are reported in the income statement in net gain (loss) from commodity hedging and trading activities. Changes in values of interest rate swaps are reported in the income statement in interest expense and related charges. Activity excludes changes in fair value in the month the position settled as well as amounts related to positions entered into and settled in the same month.

Commodity_And_Other_Derivative

Commodity And Other Derivative Contractual Assets And Liabilities	9 Months Ended
	Sep. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Commodity And Other Derivative Contractual Assets And Liabilities	'
	COMMODITY AND OTHER DERIVATIVE CONTRACTUAL ASSETS AND LIABILITIES
	Strategic Use of Derivatives
	We transact in derivative instruments, such as options, swaps, futures and forward contracts, primarily to manage electricity price risk and interest rate risk exposure. Our principal activities involving derivatives consist of a natural gas hedging program and the hedging of interest costs on our long-term debt. See Note 8 for a discussion of the fair value of all derivatives.
	Natural Gas Hedging Program — TCEH has a natural gas hedging program designed to reduce exposure to changes in future electricity prices due to changes in the price of natural gas, thereby hedging future revenues from electricity sales and related cash flows. In ERCOT, the wholesale price of electricity has generally moved with the price of natural gas. Under the program, TCEH has entered into market transactions involving natural gas-related financial instruments and has sold forward natural gas through 2014. These transactions are intended to hedge a portion of electricity price exposure related to expected lignite/coal- and nuclear-fueled generation for this period. Unrealized gains and losses arising from changes in the fair value of the instruments under the program as well as realized gains and losses upon settlement of the instruments are reported in the income statement in net gain (loss) from commodity hedging and trading activities.
	Interest Rate Swap Transactions — Interest rate swap agreements are used to reduce exposure to interest rate changes by converting floating-rate debt to fixed rates, thereby hedging future interest costs and related cash flows. Interest rate basis swaps are used to effectively reduce the hedged borrowing costs. Unrealized gains and losses arising from changes in the fair value of the swaps as well as realized gains and losses upon settlement of the swaps are reported in the income statement in interest expense and related charges. See Note 5 for additional information about interest rate swap agreements.
	Other Commodity Hedging and Trading Activity — TCEH also enters into derivatives, including electricity, natural gas, fuel oil, uranium, emission and coal instruments, generally for shorter-term hedging purposes. To a limited extent, TCEH also enters into derivative transactions for proprietary trading purposes, principally in natural gas and electricity markets.
	Financial Statement Effects of Derivatives
	Substantially all derivative contractual assets and liabilities arise from mark-to-market accounting consistent with accounting standards related to derivative instruments and hedging activities. The following tables provide detail of commodity and other derivative contractual assets and liabilities (with the column totals representing the net positions of the contracts) as reported in the balance sheets at September 30, 2013 and December 31, 2012:
	30-Sep-13
		Derivative assets								Derivative liabilities
		Commodity contracts				Interest rate swaps				Commodity contracts				Interest rate swaps				Total
	Current assets	$	972			$	84			$	—			$	—			$	1,056
	Noncurrent assets	159				—				—				—				159
	Current liabilities	(2		)		—				(204		)		(485		)		(691		)
	Noncurrent liabilities	—				—				(3		)		(779		)		(782		)
	Net assets (liabilities)	$	1,129			$	84			$	(207	)		$	(1,264	)		$	(258	)
	31-Dec-12
		Derivative assets								Derivative liabilities
		Commodity contracts				Interest rate swaps				Commodity contracts				Interest rate swaps				Total
	Current assets	$	1,461			$	134			$	—			$	—			$	1,595
	Noncurrent assets	586				—				—				—				586
	Current liabilities	—				—				(366		)		(678		)		(1,044		)
	Noncurrent liabilities	—				—				(17		)		(1,539		)		(1,556		)
	Net assets (liabilities)	$	2,047			$	134			$	(383	)		$	(2,217	)		$	(419	)
	At September 30, 2013 and December 31, 2012, there were no derivative positions accounted for as cash flow or fair value hedges.
	The following table presents the pretax effect of derivatives on net income (gains (losses)), including realized and unrealized effects:
			Three Months Ended September 30,								Nine Months Ended September 30,
	Derivative (income statement presentation)		2013				2012				2013				2012
	Commodity contracts (Net gain (loss) from commodity hedging and trading activities) (a)		$	98			$	(95	)		$	54			$	130
	Interest rate swaps (Interest expense and related charges) (b)		253				(188		)		433				(520		)
	Net gain (loss)		$	351			$	(283	)		$	487			$	(390	)
	____________
	(a)	Amount represents changes in fair value of positions in the derivative portfolio during the period, as realized amounts related to positions settled are assumed to equal reversals of previously recorded unrealized amounts.
	(b)	Includes unrealized mark-to-market net gain (loss) as well as the net realized effect on interest paid/accrued, both reported in "Interest Expense and Related Charges" (see Note 13).
	The following table presents the pretax effect (all losses) on net income and other comprehensive income (OCI) of derivative instruments previously accounted for as cash flow hedges. There were no amounts recognized in OCI for the three and nine months ended September 30, 2013 and 2012.
	Derivative type (income statement presentation of loss reclassified from accumulated OCI into income)		Three Months Ended September 30,								Nine Months Ended September 30,
			2013				2012				2013				2012
	Interest rate swaps (Interest expense and related charges)		$	(1	)		$	(1	)		$	(6	)		$	(6	)
	Interest rate swaps (Depreciation and amortization)		(1		)		(1		)		(2		)		(2		)
	Total		$	(2	)		$	(2	)		$	(8	)		$	(8	)
	Accumulated other comprehensive income related to cash flow hedges (excluding Oncor's interest rate hedge) at September 30, 2013 and December 31, 2012 totaled $38 million and $43 million in net losses (after-tax), respectively, substantially all of which relates to interest rate swaps previously accounted for as cash flow hedges. We expect that $2 million of net losses (after-tax) related to cash flow hedges included in accumulated other comprehensive income at September 30, 2013 will be reclassified into net income during the next twelve months as the related hedged transactions affect net income.
	Balance Sheet Presentation of Derivatives
	Consistent with elections under US GAAP to present amounts on a gross basis, we report derivative assets and liabilities in the balance sheet without taking into consideration netting arrangements we have with counterparties. This presentation can result in significant volatility in derivative assets and liabilities because we may enter into offsetting positions with the same counterparties, resulting in both assets and liabilities, and the underlying commodity prices can change significantly from period to period.
	Margin deposits that contractually offset these derivative instruments are reported separately in the balance sheet. Margin deposits received from counterparties are either used for working capital or other corporate purposes or are deposited in a separate restricted cash account. At September 30, 2013 and December 31, 2012, essentially all margin deposits held were unrestricted.
	We maintain standardized master netting agreements with certain counterparties that allow for the netting of positive and negative exposures. Generally, we utilize the International Swaps and Derivatives Association (ISDA) standardized contract for financial transactions, the Edison Electric Institute standardized contract for physical power transactions and the North American Energy Standards Board (NAESB) standardized contract for physical natural gas transactions. These contain credit enhancements that allow for the right to offset assets and liabilities with other financial instruments and collateral received in order to reduce credit exposure between us and the counterparty. These agreements contain specific language related to margin requirements, monthly settlement netting, cross-commodity netting and early termination netting, which is negotiated with the contract counterparty.
	Certain entities are counterparties to both our natural gas hedge program positions and our interest rate swaps and have entered into master agreements that provide for netting and setoff of amounts related to these positions.
	The following tables reconcile our derivative assets and liabilities as presented in the consolidated balance sheet to net amounts after taking into consideration netting arrangements with counterparties and financial collateral:
	30-Sep-13
			Amounts Presented in Balance Sheet				Offsetting Financial Instruments (a)				Financial Collateral (Received) Pledged (b)				Net Amounts (c)
	Derivative assets:
	Commodity contracts		$	1,131			$	(613	)		$	(351	)		$	167
	Interest rate swaps		84				(84		)		—				—
	Total derivative assets		1,215				(697		)		(351		)		167
	Derivative liabilities:
	Commodity contracts		(209		)		180				11				(18		)
	Interest rate swaps		(1,264		)		517				—				(747		)
	Total derivative liabilities		(1,473		)		697				11				(765		)
	Net amounts		$	(258	)		$	—			$	(340	)		$	(598	)
	31-Dec-12
			Amounts Presented in Balance Sheet				Offsetting Financial Instruments (a)				Financial Collateral (Received) Pledged (b)				Net Amounts
	Derivative assets:
	Commodity contracts		$	2,047			$	(1,263	)		$	(597	)		$	187
	Interest rate swaps		134				(134		)		—				—
Total derivative assets		2,181				(1,397		)		(597		)		187
Derivative liabilities:
Commodity contracts		(383		)		319				29				(35		)
Interest rate swaps		(2,217		)		1,078				—				(1,139		)
Total derivative liabilities		(2,600		)		1,397				29				(1,174		)
Net amounts		$	(419	)		$	—			$	(568	)		$	(987	)
____________
(a)	Offsetting financial instruments with respect to commodity contracts include amounts related to interest rate swaps and vice versa. Amounts exclude trade accounts receivable and payable related to settled financial instruments.
(b)	Financial collateral consists entirely of cash margin deposits.
(c)	Includes net liability positions totaling approximately $1.2 billion (before nonperformance risk adjustment) related to counterparties with positions that are secured by a first-lien interest in the same assets of TCEH (on a pari passu basis) with the TCEH Senior Secured Facilities and the TCEH Senior Secured Notes.
Derivative Volumes
The following table presents the gross notional amounts of derivative volumes at September 30, 2013 and December 31, 2012:
		30-Sep-13				31-Dec-12
Derivative type		Notional Volume								Unit of Measure
Interest rate swaps:
Floating/fixed (a)		$	32,440			$	32,760			Million US dollars
Basis		$	11,967			$	11,967			Million US dollars
Natural gas:
Natural gas forward sales and purchases (b)		452				875				Million MMBtu
Locational basis swaps		337				495				Million MMBtu
All other		2,021				1,549				Million MMBtu
Electricity		21,663				76,767				GWh
Congestion Revenue Rights (c)		82,156				111,185				GWh
Coal		11				13				Million US tons
Fuel oil		28				47				Million gallons
Uranium		575				441				Thousand pounds
____________
(a)	Includes notional amount of interest rate swaps with maturity dates through October 2014 as well as notional amount of swaps effective from October 2014 with maturity dates through October 2017 (see Note 5).
(b)	Represents gross notional forward sales, purchases and options transactions in the natural gas hedging program. The net amount of these transactions was approximately 210 million MMBtu and 360 million MMBtu at September 30, 2013 and December 31, 2012, respectively.
(c)	Represents gross forward purchases associated with instruments used to hedge electricity price differences between settlement points within ERCOT.
Credit Risk-Related Contingent Features of Derivatives
The agreements that govern our derivative instrument transactions may contain certain credit risk-related contingent features that could trigger liquidity requirements in the form of cash collateral, letters of credit or some other form of credit enhancement. Certain of these agreements require the posting of collateral if our credit rating is downgraded by one or more credit rating agencies; however, due to our credit ratings being below investment grade, substantially all of such collateral posting requirements are already effective.
At September 30, 2013 and December 31, 2012, the fair value of liabilities related to derivative instruments under agreements with credit risk-related contingent features that were not fully cash collateralized totaled $40 million and $58 million, respectively. The liquidity exposure associated with these liabilities was reduced by cash and letter of credit postings with the counterparties totaling $9 million and $12 million at September 30, 2013 and December 31, 2012, respectively. If all the credit risk-related contingent features related to these derivatives had been triggered, including cross default provisions, at September 30, 2013 and December 31, 2012, the remaining liquidity requirements would have totaled $8 million and none, respectively.
In addition, certain derivative agreements that are collateralized primarily with liens on certain of our assets include indebtedness cross-default provisions that could result in the settlement of such contracts if there were a failure under other financing arrangements to meet payment terms or to comply with other covenants that could result in the acceleration of such indebtedness. At September 30, 2013 and December 31, 2012, the fair value of derivative liabilities subject to such cross-default provisions, largely related to interest rate swaps, totaled $1.289 billion and $2.299 billion, respectively, before consideration of the amount of assets subject to the liens. No cash collateral or letters of credit were posted with these counterparties at September 30, 2013 and December 31, 2012 to reduce the liquidity exposure. If all the credit risk-related contingent features related to these derivatives, including amounts related to cross-default provisions, had been triggered at September 30, 2013 and December 31, 2012, the remaining related liquidity requirement after reduction for derivative assets under netting arrangements but before consideration of the amount of assets subject to the liens would have totaled $1.102 billion and $1.141 billion, respectively. See Note 5 for a description of other obligations that are supported by liens on certain of our assets.
As discussed immediately above, the aggregate fair values of liabilities under derivative agreements with credit risk-related contingent features, including cross-default provisions, totaled $1.329 billion and $2.357 billion at September 30, 2013 and December 31, 2012, respectively. These amounts are before consideration of cash and letter of credit collateral posted, net accounts receivable and derivative assets under netting arrangements and assets subject to related liens.
Some commodity derivative contracts contain credit risk-related contingent features that do not provide for specific amounts to be posted if the features are triggered. These provisions include material adverse change, performance assurance, and other clauses that generally provide counterparties with the right to request additional credit enhancements. The amounts disclosed above exclude credit risk-related contingent features that do not provide for specific amounts or exposure calculations.
Concentrations of Credit Risk Related to Derivatives
We have concentrations of credit risk with the counterparties to our derivative contracts. At September 30, 2013, total credit risk exposure to all counterparties related to derivative contracts totaled $1.352 billion (including associated accounts receivable). The net exposure to those counterparties totaled $276 million at September 30, 2013 after taking into effect netting arrangements, setoff provisions and collateral. At September 30, 2013, the credit risk exposure to the banking and financial sector represented 88% of the total credit risk exposure and 59% of the net exposure, a significant amount of which is related to the natural gas hedging program, and the largest net exposure to a single counterparty totaled $50 million.
Exposure to banking and financial sector counterparties is considered to be within an acceptable level of risk tolerance because all of this exposure is with counterparties with investment grade credit ratings. However, this concentration increases the risk that a default by any of these counterparties would have a material effect on our financial condition, results of operations and liquidity. The transactions with these counterparties contain certain provisions that would require the counterparties to post collateral in the event of a material downgrade in their credit rating.
We maintain credit risk policies with regard to our counterparties to minimize overall credit risk. These policies authorize specific risk mitigation tools including, but not limited to, use of standardized master agreements that allow for netting of positive and negative exposures associated with a single counterparty. Credit enhancements such as parent guarantees, letters of credit, surety bonds, liens on assets and margin deposits are also utilized. Prospective material changes in the payment history or financial condition of a counterparty or downgrade of its credit quality result in the reassessment of the credit limit with that counterparty. The process can result in the subsequent reduction of the credit limit or a request for additional financial assurances. An event of default by one or more counterparties could subsequently result in termination-related settlement payments that reduce available liquidity if amounts are owed to the counterparties related to the derivative contracts or delays in receipts of expected settlements if the counterparties owe amounts to us.

Pension_And_Other_Postretireme

Pension And Other Postretirement Employee Benefits (OPEB) Plans	9 Months Ended
	Sep. 30, 2013
Compensation and Retirement Disclosure [Abstract]	'
Pension And Other Postretirement Employee Benefits (OPEB) Plans	'
	PENSION AND OTHER POSTRETIREMENT EMPLOYEE BENEFITS (OPEB) PLANS
	Net pension and OPEB costs related to plans sponsored by EFH Corp. for the three and nine months ended September 30, 2013 and 2012 are comprised of the following:
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Components of net pension costs:
	Service cost	$	2		$	13		$	6		$	36
	Interest cost	3			38			9			118
	Expected return on assets	(2		)	(42		)	(5		)	(122		)
	Amortization of net loss	2			30			6			84
	Pension costs	5			39			16			116
	Components of net OPEB costs:
	Service cost	3			3			8			7
	Interest cost	10			11			31			33
	Expected return on assets	(3		)	(3		)	(9		)	(9		)
	Amortization of transition obligation	—			—			—			1
	Amortization of prior service cost	(8		)	(8		)	(23		)	(24		)
	Amortization of net loss	7			4			22			11
	OPEB costs	9			7			29			19
	Total benefit costs	14			46			45			135
	Less amounts expensed by Oncor	(6		)	(8		)	(19		)	(26		)
	Less amounts deferred principally as a regulatory asset or property by Oncor	(6		)	(21		)	(18		)	(64		)
	Net amounts recognized as expense by EFH Corp. and consolidated subsidiaries	$	2		$	17		$	8		$	45
	The decrease in pension costs in 2013 reflects the implementation of certain amendments to EFH Corp.'s pension plan completed in the fourth quarter 2012 that resulted in:
	•	splitting off assets and liabilities under the plan associated with employees of Oncor and all retirees and terminated vested participants of EFH Corp. and its subsidiaries (including discontinued businesses) to a new plan sponsored and administered by Oncor (the Oncor Plan) and
	•	the termination of, distributions of benefits under, and settlement of all of EFH Corp.'s liabilities associated with active employees of EFH Corp.'s competitive businesses other than collective bargaining unit employees.
	The discount rates reflected in net pension and OPEB costs for 2013 are 4.30% and 4.10%, respectively. The expected rates of return on pension and OPEB plan assets reflected in the 2013 cost amounts are 5.4% and 6.7%, respectively.
	Cash contributions in the first nine months of 2013 related to the pension plans totaled $7 million, essentially all of which was funded by Oncor, and $13 million related to the OPEB plan, of which $9 million was funded by Oncor. Additional contributions expected in 2013 total less than $1 million for the pension plans, including amounts related to nonqualified plans, and $5 million for the OPEB plan, of which approximately $3 million is expected to be funded by Oncor.

Related_Party_Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2013
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	RELATED PARTY TRANSACTIONS
	The following represent our significant related-party transactions.
	•	We pay an annual management fee under the terms of a management agreement with the Sponsor Group, reported in SG&A expense, totaling $10 million and $9 million for the three months ended September 30, 2013 and 2012, respectively, and $29 million and $28 million for the nine months ended September 30, 2013 and 2012, respectively.
	•	In 2007, TCEH entered into the TCEH Senior Secured Facilities with syndicates of financial institutions and other lenders. These syndicates included affiliates of GS Capital Partners, which is a member of the Sponsor Group. Affiliates of each member of the Sponsor Group have from time to time engaged in commercial banking transactions with us and/or provided financial advisory services to us, in each case in the normal course of business.
	•	In January 2013, fees paid to Goldman, Sachs & Co. (Goldman), an affiliate of GS Capital Partners, for services related to debt exchanges totaled $2 million, described as follows: (i) Goldman acted as a dealer manager for the offers by EFIH and EFIH Finance to exchange new EFIH 10% Notes for EFH Corp. 9.75% Notes, EFH Corp. 10% Notes and EFIH 9.75% Notes (collectively, the Old Notes) and as a solicitation agent in the solicitation of consents by EFH Corp. and EFIH and EFIH Finance to amendments to the Old Notes and indentures governing the Old Notes and (ii) Goldman acted as a dealer manager for the offers by EFIH and EFIH Finance to exchange EFIH Toggle Notes for EFH Corp. 10.875% Notes and EFH Corp. Toggle Notes. See Note 5 for further discussion of these exchange offers.
	In the nine months ended September 30, 2012, fees paid to Goldman related to debt issuances totaled $10 million, described as follows: (i) Goldman acted as a joint book-running manager and initial purchaser in the February 2012 issuance of $1.15 billion principal amount of EFIH 11.750% Notes; (ii) Goldman acted as joint book-running manager and initial purchaser in the August 2012 issuance of $600 million principal amount of 11.750% Notes and $250 million principal amount of EFIH 6.875% Notes. A broker-dealer affiliate of KKR served as a co-manager and initial purchaser and an affiliate of TPG served as an advisor in both of these transactions, for which they each received a total of $3 million.
	•	Affiliates of GS Capital Partners are parties to certain commodity and interest rate hedging transactions with us in the normal course of business.
	•	Affiliates of the Sponsor Group have sold or acquired, and in the future may sell or acquire, debt or debt securities issued by us in open market transactions or through loan syndications.
	•	TCEH made loans to EFH Corp. in the form of demand notes (TCEH Demand Notes) that were pledged as collateral under the TCEH Senior Secured Facilities for (i) debt principal and interest payments and (ii) other general corporate purposes (SG&A Note) for EFH Corp. The TCEH Demand Notes totaled $698 million at December 31, 2012, including $233 million in the SG&A Note, and are eliminated in consolidation in these condensed consolidated financial statements. EFH Corp. settled the balance of the TCEH Demand Notes in January 2013 using $680 million of the proceeds from debt issued by EFIH in 2012 that had been held as restricted cash (see Note 13).
	•	As part of EFH Corp.'s liability management program, EFH Corp. and EFIH have purchased, or received in exchanges, certain debt securities of EFH Corp. and TCEH, which they have held. Principal and interest payments received by EFH Corp. and EFIH on these investments have been used, in part, to service their outstanding debt. These investments are eliminated in consolidation in these consolidated financial statements. At September 30, 2013, EFIH held $1.282 billion principal amount of EFH Corp. debt and $79 million principal amount of TCEH debt. At September 30, 2013, EFH Corp. held $303 million principal amount of TCEH debt. In the first quarter 2013, EFIH distributed as a dividend to EFH Corp. $6.360 billion principal amount of EFH Corp. debt previously received by EFIH in debt exchanges; EFH Corp. cancelled the debt instruments (see Note 5).
	•	TCEH's retail operations pay Oncor for services it provides, principally the delivery of electricity. Expenses recorded for these services, reported in fuel, purchased power costs and delivery fees, totaled $273 million and $281 million for the three months ended September 30, 2013 and 2012, respectively, and $728 million and $746 million for the nine months ended September 30, 2013 and 2012, respectively. The fees are based on rates regulated by the PUCT that apply to all REPs. The balance sheets at September 30, 2013 and December 31, 2012 reflect amounts due currently to Oncor totaling $158 million and $53 million, respectively (included in net payables due to unconsolidated subsidiary), largely related to these electricity delivery fees. Also see discussion below regarding receivables from Oncor under a tax sharing agreement.
	•	In August 2012, TCEH and Oncor agreed to settle at a discount two agreements related to securitization (transition) bonds issued by Oncor's bankruptcy-remote financing subsidiary in 2003 and 2004 to recover generation-related regulatory assets. Under the agreements, TCEH had been reimbursing Oncor as described immediately below. Under the settlement, TCEH paid, and Oncor received, $159 million in cash.
	Oncor collects transition surcharges from its customers to recover the transition bond payment obligations. Oncor's incremental income taxes related to the transition surcharges it collects had been reimbursed by TCEH quarterly under a noninterest bearing note payable to Oncor that was to mature in 2016. TCEH's payments on the note prior to the August 2012 settlement totaled zero and $20 million for the three and nine months ended September 30, 2012, respectively.
	Under an interest reimbursement agreement, TCEH had reimbursed Oncor on a monthly basis for interest expense on the transition bonds. Only the monthly accrual of interest under this agreement was reported as a liability. This interest expense prior to the August 2012 settlement totaled $2 million and $16 million for the three and nine months ended September 30, 2012, respectively.
	•	Oncor pays EFH Corp. subsidiaries for financial and other administrative services and shared facilities at cost. Such amounts reduced reported SG&A expense by $8 million and $10 million for the three months ended September 30, 2013 and 2012, respectively, and $24 million and $27 million for the nine months ended September 30, 2013 and 2012, respectively.
	•	Under Texas regulatory provisions, the trust fund for decommissioning the Comanche Peak nuclear generation facility is funded by a delivery fee surcharge billed to REPs by Oncor, as collection agent, and remitted monthly to TCEH for contribution to the trust fund with the intent that the trust fund assets, reported in other investments in our balance sheet, will ultimately be sufficient to fund the actual future decommissioning liability, reported in noncurrent liabilities in our balance sheet. The delivery fee surcharges remitted to TCEH totaled $5 million for both the three months ended September 30, 2013 and 2012 and $12 million for both the nine months ended September 30, 2013 and 2012. Income and expenses associated with the trust fund and the decommissioning liability incurred by TCEH are offset by a net change in a receivable/payable that ultimately will be settled through changes in Oncor's delivery fee rates. At September 30, 2013 and December 31, 2012, the excess of the trust fund balance over the decommissioning liability resulted in a payable totaling $352 million and $284 million, respectively, reported in noncurrent liabilities.
	•	We file a consolidated federal income tax return that includes Oncor Holdings' results. Oncor is not a member of our consolidated tax group, but our consolidated federal income tax return includes our portion of Oncor's results due to our equity ownership in Oncor. We also file a consolidated Texas state margin tax return that includes all of Oncor Holdings' and Oncor's results. However, under a tax sharing agreement, Oncor Holdings' and Oncor's federal income tax and Texas margin tax expense and related balance sheet amounts, including our income taxes receivable from or payable to Oncor Holdings and Oncor, are recorded as if Oncor Holdings and Oncor file their own corporate income tax returns.
	At September 30, 2013, our current amount receivable from Oncor Holdings related to federal and state income taxes (included in net payables due to unconsolidated subsidiary) totaled $35 million, which includes $28 million from Oncor. At December 31, 2012, our current amount receivable totaled $34 million, which included $22 million from Oncor.
	For the nine months ended September 30, 2013, EFH Corp. received net federal and state income tax payments from Oncor Holdings and Oncor totaling $24 million and $60 million, respectively. The 2013 net payment included $33 million from Oncor related to the 1997 through 2002 IRS appeals settlement and a $10 million refund paid to Oncor related to the filing of amended Texas franchise tax returns for 1997 through 2001. For the nine months ended September 30, 2012, EFH Corp. received income tax payments from Oncor Holdings and Oncor totaling $24 million and $3 million, respectively, net of $21 million in federal income tax refunds paid to Oncor Holdings.
	•	Pursuant to the existing tax sharing agreement between EFH Corp. and TCEH, in September 2013, TCEH made a federal income tax payment of $84 million to EFH Corp related to the 1997 through 2002 IRS appeals settlement.
	•	Certain transmission and distribution utilities in Texas have requirements in place to assure adequate creditworthiness of any REP to support the REP's obligation to collect securitization bond-related (transition) charges on behalf of the utility. Under these requirements, as a result of TCEH's credit rating being below investment grade, TCEH is required to post collateral support in an amount equal to estimated transition charges over specified time periods. Accordingly, at September 30, 2013 and December 31, 2012, TCEH had posted letters of credit in the amount of $10 million and $11 million, respectively, for the benefit of Oncor.
	•	As a result of the pension plan actions discussed in Note 10, in December 2012, Oncor became the sponsor of a new pension plan (the Oncor Plan), the participants in which consist of all of Oncor's active employees and all retirees and terminated vested participants of EFH Corp. and its subsidiaries (including discontinued businesses). Oncor had previously contractually agreed to assume responsibility for pension and OPEB liabilities that are recoverable by Oncor under regulatory rate-setting provisions. As part of the pension plan actions, EFH Corp. fully funded the nonrecoverable pension liabilities under the Oncor Plan. After the pension plan actions, participants remaining in the EFH Corp. pension plan consist of active employees under collective bargaining agreements (union employees). Oncor continues to be responsible for the recoverable portion of pension obligations to these union employees. EFH Corp. is the sponsor of the OPEB plan and remains liable for the majority of the OPEB plan obligations. Accordingly, EFH Corp.'s balance sheet reflects unfunded pension and OPEB liabilities related to plans that it sponsors, including recoverable and nonrecoverable amounts, but also reflects a receivable from Oncor for that portion of the unfunded liabilities for which Oncor is contractually responsible, substantially all of which is expected to be recovered in Oncor's rates. At September 30, 2013 and December 31, 2012, the receivable amounts totaled $839 million and $825 million, respectively, classified as noncurrent. Under ERISA, EFH Corp. and Oncor remain jointly and severally liable for the funding of the EFH Corp. and Oncor pension plans. We view the risk of the retained liability under ERISA related to the Oncor Plan to be not significant.
	•	Oncor and Texas Holdings agreed to the terms of a stipulation with major interested parties to resolve all outstanding issues in the PUCT review related to the Merger. As part of this stipulation, TCEH would be required to post a letter of credit in an amount equal to $170 million to secure its payment obligations to Oncor in the event, which has not occurred, two or more rating agencies downgrade Oncor's credit rating below investment grade.

Segment_Information

Segment Information	9 Months Ended
	Sep. 30, 2013
Segment Reporting [Abstract]	'
Segment Information	'
	SEGMENT INFORMATION
	Our operations are aligned into two reportable business segments: Competitive Electric and Regulated Delivery. The segments are managed separately because they are strategic business units that offer different products or services and involve different risks.
	The Competitive Electric segment is engaged in competitive market activities consisting of electricity generation, wholesale energy sales and purchases, commodity risk management and trading activities, and retail electricity sales to residential and business customers, all largely in Texas. These activities are conducted by TCEH.
	The Regulated Delivery segment consists largely of our investment in Oncor. Oncor is engaged in regulated electricity transmission and distribution operations in Texas. These activities are conducted by Oncor, including its wholly owned bankruptcy-remote financing subsidiary. See Note 2 for discussion of the reporting of Oncor Holdings and, accordingly, the Regulated Delivery segment, as an equity method investment. See Note 11 for discussion of material transactions with Oncor, including payment to Oncor of electricity delivery fees, which are based on rates regulated by the PUCT.
	Corporate and Other represents the remaining nonsegment operations consisting primarily of discontinued businesses, general corporate expenses and interest and other expenses related to EFH Corp., EFIH and EFCH.
	The accounting policies of the business segments are the same as those described in the summary of significant accounting policies in Note 1 above and in Note 1 to Financial Statements in our 2012 Form 10-K. We evaluate performance based on net income (loss). We account for intersegment sales and transfers as if the sales or transfers were to third parties, that is, at current market prices or regulated rates.
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Operating revenues (all Competitive Electric)	$	1,893		$	1,752		$	4,572		$	4,358
	Equity in earnings of unconsolidated subsidiaries (net of tax) — Regulated Delivery (net of noncontrolling interest of $29, $27, $66 and $64)	$	114		$	109		$	255		$	249
	Net income (loss):
	Competitive Electric	$	18		$	(393	)	$	(768	)	$	(1,319	)
	Regulated Delivery	114			109			255			249
	Corporate and Other	(127		)	(123		)	(122		)	(338		)
	Consolidated	$	5		$	(407	)	$	(635	)	$	(1,408	)

Supplementary_Financial_Inform

Supplementary Financial Information	9 Months Ended
	Sep. 30, 2013
Supplementary Financial Information [Abstract]	'
Supplementary Financial Information	'
	SUPPLEMENTARY FINANCIAL INFORMATION
	Other Income and Deductions
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Other income:
	Office space rental income (a)	$	3		$	3		$	9		$	9
	Consent fee related to novation of hedge positions between counterparties (b)	—			—			—			6
	Insurance/litigation settlements (b)	—			—			2			2
	All other	2			3			8			8
	Total other income	$	5		$	6		$	19		$	25
	Other deductions:
	Impairment of remaining equipment from cancelled generation development program (b)	$	27		$	—		$	27		$	—
	Impairment of mineral interests (b)	—			24			—			24
	Impairment of computer software assets (a)	—			7			—			7
	Other asset impairments (b)	3			—			3			—
	Counterparty contract settlement (b)	—			4			—			4
	Ongoing employee retirement benefit expense related to discontinued businesses (a)	—			4			(1		)	10
	All other	6			3			11			9
	Total other deductions	$	36		$	42		$	40		$	54
	____________
	(a)	Reported in Corporate and Other.
	(b)	Reported in Competitive Electric segment.
	Interest Expense and Related Charges
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Interest paid/accrued (including net amounts settled/accrued under interest rate swaps)	$	851		$	812		$	2,532		$	2,405
	Interest payable with additional toggle notes (Note 5)	45			61			130			177
	Unrealized mark-to-market net (gain) loss on interest rate swaps (a)	(414		)	21			(903		)	12
	Amortization of interest rate swap losses at dedesignation of hedge accounting	2			2			6			7
	Amortization of fair value debt discounts resulting from purchase accounting	5			11			15			33
	Amortization of debt issuance, amendment and extension costs and discounts	49			48			154			143
	Capitalized interest	(5		)	(11		)	(19		)	(31		)
	Total interest expense and related charges	$	533		$	944		$	1,915		$	2,746
	____________
	(a)	Three months ended September 30, 2013 and 2012 amounts include net gains totaling $413 million and net losses totaling $20 million, respectively, related to TCEH swaps (see Note 5) and net gains totaling $1 million and net losses totaling $1 million, respectively, related to EFH Corp. swaps substantially closed through offsetting positions. Nine months ended September 30, 2013 and 2012 amounts include net gains totaling $899 million and net losses totaling $16 million, respectively, related to TCEH swaps and net gains totaling $4 million for both periods related to EFH Corp. swaps substantially closed through offsetting positions.
	Restricted Cash
		30-Sep-13						31-Dec-12
		Current Assets			Noncurrent Assets			Current Assets			Noncurrent Assets
	Amounts in escrow to settle TCEH Demand Notes (Note 11)	$	—		$	—		$	680		$	—
	Amounts related to TCEH's Letter of Credit Facility (Note 5)	—			947			—			947
	Other	4			—			—			—
	Total restricted cash	$	4		$	947		$	680		$	947
	Inventories by Major Category
		September 30,			December 31,
		2013			2012
	Materials and supplies	$	216		$	201
	Fuel stock	155			168
	Natural gas in storage	29			24
	Total inventories	$	400		$	393
	Other Investments
		September 30,			December 31,
		2013			2012
	Nuclear plant decommissioning trust	$	737		$	654
	Assets related to employee benefit plans, including employee savings programs, net of distributions	63			70
	Land	40			41
	Miscellaneous other	3			2
	Total other investments	$	843		$	767
	Nuclear Decommissioning Trust — Investments in a trust that will be used to fund the costs to decommission the Comanche Peak nuclear generation plant are carried at fair value. Decommissioning costs are being recovered from Oncor's customers as a delivery fee surcharge over the life of the plant and deposited by TCEH in the trust fund. Income and expense associated with the trust fund and the decommissioning liability are offset by a corresponding change in a receivable/payable (currently a payable reported in noncurrent liabilities) that will ultimately be settled through changes in Oncor's delivery fees rates (see Note 11). A summary of investments in the fund follows:
		30-Sep-13
		Cost (a)			Unrealized gain			Unrealized loss			Fair market
											value
	Debt securities (b)	$	261		$	9		$	(4	)	$	266
	Equity securities (c)	252			227			(8		)	471
Total	$	513		$	236		$	(12	)	$	737
	31-Dec-12
	Cost (a)			Unrealized gain			Unrealized loss			Fair market
										value
Debt securities (b)	$	246		$	16		$	(1	)	$	261
Equity securities (c)	245			161			(13		)	393
Total	$	491		$	177		$	(14	)	$	654
____________
(a)	Includes realized gains and losses on securities sold.
(b)	The investment objective for debt securities is to invest in a diversified tax efficient portfolio with an overall portfolio rating of AA or above as graded by S&P or Aa2 by Moody's Investors Services, Inc. The debt securities are heavily weighted with municipal bonds. The debt securities had an average coupon rate of 3.97% and 4.38% at September 30, 2013 and December 31, 2012, respectively, and an average maturity of 6 years at both September 30, 2013 and December 31, 2012.
(c)	The investment objective for equity securities is to invest tax efficiently and to match the performance of the S&P 500 Index.
Debt securities held at September 30, 2013 mature as follows: $103 million in one to five years, $58 million in five to ten years and $105 million after ten years.
The following table summarizes proceeds from sales of available-for-sale securities and the related realized gains and losses from such sales.
	Three Months Ended September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
Realized gains	$	1		$	—		$	2		$	1
Realized losses	$	(3	)	$	(1	)	$	(3	)	$	(2	)
Proceeds from sales of securities	$	23		$	25		$	128		$	56
Investments in securities	$	(28	)	$	(30	)	$	(140	)	$	(68	)
Property, Plant and Equipment
At September 30, 2013 and December 31, 2012, property, plant and equipment of $18.1 billion and $18.7 billion, respectively, is stated net of accumulated depreciation and amortization of $7.8 billion and $6.9 billion, respectively.
Asset Retirement and Mining Reclamation Obligations
These liabilities primarily relate to nuclear generation plant decommissioning, land reclamation related to lignite mining, removal of lignite/coal-fueled plant ash treatment facilities and generation plant asbestos removal and disposal costs. There is no earnings impact with respect to changes in the nuclear plant decommissioning liability, as all costs are recoverable through the regulatory process as part of Oncor's delivery fees.
The following table summarizes the changes to these obligations, reported in other current liabilities and other noncurrent liabilities and deferred credits in the balance sheet, for the nine months ended September 30, 2013:
	Nuclear Plant Decommissioning			Mining Land Reclamation			Other			Total
Liability at December 31, 2012	$	368		$	135		$	33		$	536
Additions:
Accretion	17			23			1			41
Reductions:
Payments	—			(72		)	(1		)	(73		)
Liability at September 30, 2013	385			86			33			504
Less amounts due currently	—			(60		)	—			(60		)
Noncurrent liability at September 30, 2013	$	385		$	26		$	33		$	444
Other Noncurrent Liabilities and Deferred Credits
The balance of other noncurrent liabilities and deferred credits consists of the following:
	September 30,			December 31,
	2013			2012
Uncertain tax positions (including accrued interest)	$	427		$	2,005
Retirement plan and other employee benefits (a)	1,050			1,035
Asset retirement and mining reclamation obligations	444			452
Unfavorable purchase and sales contracts	596			620
Nuclear decommissioning cost over-recovery (Note 11)	352			284
Other	34			30
Total other noncurrent liabilities and deferred credits	$	2,903		$	4,426
____________
(a)	Includes $839 million and $825 million at September 30, 2013 and December 31, 2012, respectively, representing pension and OPEB liabilities related to Oncor (see Note 11).
Liability for Uncertain Tax Positions — In May 2013, we received approval from the Joint Committee on Taxation of the IRS appeals settlement of all issues arising from the 1997 through 2002 IRS audit, which includes all tax issues related to EFH Corp.'s discontinued Europe operations. The settlement also affected federal and state returns for periods subsequent to 2002. In the second quarter 2013, we reduced the liability for uncertain tax positions to reflect the effects of the settlement, resulting in a $524 million reclassification to the accumulated deferred income tax liability and the recording of a $183 million income tax benefit. Other effects included the recording of a $19 million noncurrent federal income tax liability, an $8 million current federal income tax liability, a $15 million current state income tax liability and a $33 million federal income tax receivable from Oncor under the tax sharing agreement (see Note 11). In the third quarter 2013, we recorded an additional $38 million tax benefit, with an offset to accumulated deferred income tax liability, related to the settlement. The total income tax benefit of $221 million reflected a $204 million income tax benefit recorded in Corporate and Other activities and a $17 million income tax benefit reported in the Competitive Electric segment results.
In March 2013, EFH Corp. and the IRS agreed on terms to resolve disputed adjustments related to the IRS audit for the years 2003 through 2006, which was concluded in June 2011. The IRS proposed a significant number of adjustments to the originally filed returns for such years. The adjustments relate to one significant accounting method issue and other less significant issues. In the first quarter 2013, we reduced the liability for uncertain tax positions to reflect the terms of the agreement, resulting in a $701 million reclassification to the accumulated deferred income tax liability and a net adjustment of $143 million ($84 million after tax), largely representing a reversal of accrued interest and reported as an increase in income tax benefit. Any cash income tax liability related to this agreement is expected to be immaterial. The $84 million income tax benefit reflected a $62 million income tax benefit recorded in the Competitive Electric segment results and a $22 million income tax benefit recorded in Corporate and Other activities.
The March 2013 settlement and May 2013 IRS appeals settlement resulted in the expected elimination of all net operating loss carryforwards generated through 2013, as well as elimination of remaining alternative minimum tax credit carryforwards.
Unfavorable Purchase and Sales Contracts — The amortization of unfavorable purchase and sales contracts totaled $6 million for both the three months ended September 30, 2013 and 2012 and $19 million and $20 million for the nine months ended September 30, 2013 and 2012, respectively. See Note 3 for intangible assets related to favorable purchase and sales contracts.
The estimated amortization of unfavorable purchase and sales contracts for each of the next five fiscal years is as follows:
Year		Amount
2013		$	25
2014		$	24
2015		$	23
2016		$	23
2017		$	23
Supplemental Cash Flow Information
	Nine Months Ended September 30,
	2013			2012
Cash payments (receipts) related to:
Interest paid (a)	$	2,391		$	2,150
Capitalized interest	(19		)	(31		)
Interest paid (net of capitalized interest) (a)	$	2,372		$	2,119
Income taxes	$	65		$	67
Noncash investing and financing activities:
Principal amount of toggle notes issued in lieu of cash interest (Note 5)	$	83		$	114
Construction expenditures (b)	$	65		$	55
Debt exchange and extension transactions (Note 5)	$	(326	)	$	—
Debt assumed related to acquisition of combustion turbine trust interest	$	(45	)	$	—
____________
(a)	Net of amounts received under interest rate swap agreements.
(b)	Represents end-of-period accruals.

Business_And_Significant_Accou1

Business And Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2013
Accounting Policies [Abstract]	'
Basis of Presentation	'
	The condensed consolidated financial statements have been prepared in accordance with US GAAP and on the same basis as the audited financial statements included in our 2012 Form 10-K. Investments in unconsolidated subsidiaries, which are 50% or less owned and/or do not meet accounting standards criteria for consolidation, are accounted for under the equity method (see Note 2). Adjustments (consisting of normal recurring accruals) necessary for a fair presentation of the results of operations and financial position have been included therein. All intercompany items and transactions have been eliminated in consolidation. Any acquisitions of outstanding debt for cash, including notes that had been issued in lieu of cash interest, are presented in the financing activities section of the statement of cash flows. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with US GAAP have been omitted pursuant to the rules and regulations of the SEC. Because the condensed consolidated interim financial statements do not include all of the information and footnotes required by US GAAP, they should be read in conjunction with the audited financial statements and related notes included in our 2012 Form 10-K. The results of operations for an interim period may not give a true indication of results for a full year. All dollar amounts in the financial statements and tables in the notes are stated in millions of US dollars unless otherwise indicated.
Use of Estimates	'
	Preparation of financial statements requires estimates and assumptions about future events that affect the reporting of assets and liabilities at the balance sheet dates and the reported amounts of revenue and expense, including fair value measurements. In the event estimates and/or assumptions prove to be different from actual amounts, adjustments are made in subsequent periods to reflect more current information.

Variable_Interest_Entities_Tab

Variable Interest Entities (Tables)	9 Months Ended
	Sep. 30, 2013
Consolidation Of Variable Interest Entities [Abstract]	'
Schedule of carrying amounts and classifications of the assets and liabilities related to our consolidated VIEs	'
	The carrying amounts and classifications of the assets and liabilities related to our consolidated VIEs are as follows:
	Assets:	September 30,			31-Dec-12			Liabilities:	September 30,			31-Dec-12
		2013							2013
	Cash and cash equivalents	$	37		$	43		Short-term borrowings	$	172		$	82
	Accounts receivable	573			445			Trade accounts payable	1			1
	Property, plant and equipment	138			134			Other current liabilities	13			7
	Other assets, including $3 million and $12 million of current assets	12			16
	Total assets	$	760		$	638		Total liabilities	$	186		$	90
Schedule of condensed statements of consolidated income of Oncor Holdings and its subsidiaries	'
	Condensed statements of consolidated income of Oncor Holdings and its subsidiaries for the three and nine months ended September 30, 2013 and 2012 are presented below:
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Operating revenues	$	966		$	925		$	2,640		$	2,536
	Operation and maintenance expenses	(315		)	(292		)	(919		)	(873		)
	Depreciation and amortization	(207		)	(201		)	(608		)	(577		)
	Taxes other than income taxes	(112		)	(113		)	(315		)	(313		)
	Other income	4			6			14			20
	Other deductions	(2		)	(1		)	(11		)	(4		)
	Interest income	—			3			2			24
	Interest expense and related charges	(94		)	(96		)	(283		)	(279		)
	Income before income taxes	240			231			520			534
	Income tax expense	(97		)	(95		)	(199		)	(221		)
	Net income	143			136			321			313
	Net income attributable to noncontrolling interests	(29		)	(27		)	(66		)	(64		)
	Net income attributable to Oncor Holdings	$	114		$	109		$	255		$	249
Schedule of assets and liabilities of Oncor Holdings	'
	Assets and liabilities of Oncor Holdings at September 30, 2013 and December 31, 2012 are presented below:
		September 30,			December 31,
		2013			2012
	ASSETS
	Current assets:
	Cash and cash equivalents	$	17		$	45
	Restricted cash	61			55
	Trade accounts receivable — net	404			338
	Trade accounts and other receivables from affiliates	158			53
	Inventories	67			73
	Accumulated deferred income taxes	35			26
	Prepayments and other current assets	82			82
	Total current assets	824			672
	Restricted cash	16			16
	Other investments	85			83
	Property, plant and equipment — net	11,794			11,318
	Goodwill	4,064			4,064
	Regulatory assets — net	1,512			1,788
	Other noncurrent assets	70			78
	Total assets	$	18,365		$	18,019
	LIABILITIES
	Current liabilities:
	Short-term borrowings	$	860		$	735
	Long-term debt due currently	129			125
	Trade accounts payable — nonaffiliates	100			121
	Income taxes payable to EFH Corp.	35			34
	Accrued taxes other than income	134			153
	Accrued interest	65			95
	Other current liabilities	111			110
	Total current liabilities	1,434			1,373
	Accumulated deferred income taxes	1,881			1,736
	Investment tax credits	22			24
	Long-term debt, less amounts due currently	5,422			5,400
	Other noncurrent liabilities and deferred credits	1,931			1,999
	Total liabilities	$	10,690		$	10,532

Goodwill_And_Identifiable_Inta1

Goodwill And Identifiable Intangible Assets (Tables)	9 Months Ended
	Sep. 30, 2013
Goodwill and Intangible Assets Disclosure [Abstract]	'
Schedule of Goodwill	'
	The following table provides information regarding our goodwill balance, all of which relates to the Competitive Electric segment and arose in connection with accounting for the Merger. There were no changes to the goodwill balance for the three and nine months ended September 30, 2013. None of the goodwill is being deducted for tax purposes.
	Goodwill before impairment charges	$	18,342
	Accumulated impairment charges	(13,390		)
	Balance at September 30, 2013 and December 31, 2012	$	4,952
Schedule of identifiable intangible assets reported in the balance sheet	'
	Identifiable intangible assets, including amounts that arose in connection with accounting for the Merger, are comprised of the following:
			30-Sep-13							31-Dec-12
	Identifiable Intangible Asset		Gross			Accumulated		Net		Gross		Accumulated		Net
			Carrying			Amortization				Carrying		Amortization
			Amount							Amount
	Retail customer relationship		$	463		$	396	$	67	$	463	$	378	$	85
	Favorable purchase and sales contracts		551			333		218		552		314		238
	Capitalized in-service software		357			193		164		356		174		182
	Environmental allowances and credits		598			407		191		594		393		201
	Mining development costs		196			105		91		163		82		81
	Total identifiable intangible assets subject to amortization		$	2,165		$	1,434	731		$	2,128	$	1,341	787
	Retail trade name (not subject to amortization)							955						955
	Mineral interests (not currently subject to amortization)							11						13
	Total identifiable intangible assets							$	1,697					$	1,755
Schedule of amortization expense related to intangible assets (including income statement line item)	'
	Amortization expense related to identifiable intangible assets (including income statement line item) consisted of:
	Identifiable Intangible Asset		Income Statement Line		Segment	Three Months Ended September 30,				Nine Months Ended September 30,
						2013		2012		2013		2012
	Retail customer relationship		Depreciation and amortization		Competitive Electric	$	6	$	8	$	18	$	25
	Favorable purchase and sales contracts		Operating revenues/fuel, purchased power costs and delivery fees		Competitive Electric	6		5		19		20
	Capitalized in-service software		Depreciation and amortization		Competitive Electric and Corporate and Other	10		10		31		29
	Environmental allowances and credits		Fuel, purchased power costs and delivery fees		Competitive Electric	5		6		11		15
	Mining development costs		Depreciation and amortization		Competitive Electric	8		7		23		20
	Total amortization expense					$	35	$	36	$	102	$	109
Schedule of estimated aggregate amortization expense of intangible assets for each of the next five fiscal years	'
	Estimated Amortization of Identifiable Intangible Assets — The estimated aggregate amortization expense of identifiable intangible assets for each of the next five fiscal years is as follows:
	Year		Estimated Amortization Expense
	2013		$	138
	2014		$	125
	2015		$	115
	2016		$	95
	2017		$	75

Trade_Accounts_Receivable_And_1

Trade Accounts Receivable And Accounts Receivable Securitization Program (Tables)	9 Months Ended
	Sep. 30, 2013
Receivables [Abstract]	'
Schedule of program fees	'
	Program fee amounts were as follows:
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Program fees	$	3		$	2		$	6		$	6
	Program fees as a percentage of average funding (annualized)	5.1		%	4.9		%	5.8		%	6.2		%
Schedule of activities from receivables company related to cash flows used by (provided to) originator under the program	'
	Activities of TXU Energy Receivables Company and its predecessor, TXU Receivables Company, were as follows:
		Nine Months Ended September 30,
		2013			2012
	Cash collections on accounts receivable	$	3,200		$	3,501
	Face amount of new receivables purchased (a)	(3,328		)	(3,571		)
	Discount from face amount of purchased receivables	29			8
	Program fees paid to financial institution	(6		)	(6		)
	Servicing fees paid for recordkeeping and collection services	—			(2		)
	Decrease in subordinated notes payable	(4		)	(10		)
	Increase in cash held	17			—
	Other — net	2			—
	Cash flows provided to originator under the program	$	(90	)	$	(80	)
Schedule of trade accounts receivable and allowance for uncollectible accounts receivable	'
	Trade Accounts Receivable
		September 30,			December 31,
		2013			2012
	Wholesale and retail trade accounts receivable	$	825		$	727
	Allowance for uncollectible accounts	(17		)	(9		)
	Trade accounts receivable — reported in balance sheet, including $573 and $445 in pledged retail receivables	$	808		$	718
	Allowance for Uncollectible Accounts Receivable
		Nine Months Ended September 30,
		2013			2012
	Allowance for uncollectible accounts receivable at beginning of period	$	9		$	27
	Increase for bad debt expense	23			20
	Decrease for account write-offs	(15		)	(32		)
	Allowance for uncollectible accounts receivable at end of period	$	17		$	15

ShortTerm_Borrowings_And_LongT1

Short-Term Borrowings And Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2013
Debt and Capital Lease Obligations [Abstract]	'
Schedule of Line of Credit Facilities	'
	Credit facilities and related cash borrowings at September 30, 2013 are presented below. Available letter of credit capacity totaled $171 million at September 30, 2013 as discussed below. The facilities are all senior secured facilities of TCEH.
				30-Sep-13
	Facility	Maturity		Facility				Letters of				Cash				Availability
		Date		Limit				Credit				Borrowings
	TCEH Revolving Credit Facility (a)	Oct-16		$	2,054			$	—			$	2,054			$	—
	TCEH Letter of Credit Facility (b)	October 2017 (b)		1,062				—				1,062				—
	Total TCEH			$	3,116			$	—			$	3,116			$	—
	___________
	(a)	Facility used for borrowings for general corporate purposes. Borrowings are classified as short-term borrowings. At September 30, 2013, borrowings under the facility bear interest at LIBOR plus 4.50%, and a commitment fee is payable quarterly in arrears at a rate per annum equal to 1.00% of the average daily unused portion of the facility. In January 2013, commitments previously maturing in 2013 were extended to 2016 as discussed below.
	(b)	Facility, $42 million of which matures in October 2014, used for issuing letters of credit for general corporate purposes, including, but not limited to, providing collateral support under hedging arrangements and other commodity transactions that are not secured by a first-lien interest in the assets of TCEH. The borrowings under this facility have been recorded by TCEH as restricted cash that supports issuances of letters of credit and are classified as long-term debt. At September 30, 2013, the restricted cash totaled $947 million, after reduction for a $115 million letter of credit drawn in 2009 related to an office building financing. At September 30, 2013, the restricted cash supports $776 million in letters of credit outstanding, leaving $171 million in available letter of credit capacity.
Schedule of Long-term Debt Instruments	'
	Long-Term Debt
	At September 30, 2013 and December 31, 2012, long-term debt consisted of the following:
		September 30,				December 31,
		2013				2012
	EFH Corp. (parent entity)
	9.75% Fixed Senior Notes due October 15, 2019	$	2			$	115
	10% Fixed Senior Notes due January 15, 2020	3				1,061
	10.875% Fixed Senior Notes due November 1, 2017 (a)	33				64
	11.25 / 12.00% Senior Toggle Notes due November 1, 2017 (a)	27				60
	5.55% Fixed Series P Senior Notes due November 15, 2014 (a)	90				92
	6.50% Fixed Series Q Senior Notes due November 15, 2024 (a)	201				230
	6.55% Fixed Series R Senior Notes due November 15, 2034 (a)	291				291
	8.82% Building Financing due semiannually through February 11, 2022 (b)	46				53
	Unamortized fair value premium related to Building Financing (b)(c)	9				11
	Unamortized fair value discount (c)	(123		)		(137		)
	Total EFH Corp.	579				1,840
	EFIH
	6.875% Fixed Senior Secured First Lien Notes due August 15, 2017	503				503
	10% Fixed Senior Secured First Lien Notes due December 1, 2020	3,482				2,180
	11% Fixed Senior Secured Second Lien Notes due October 1, 2021	406				406
	11.75% Fixed Senior Secured Second Lien Notes due March 1, 2022	1,750				1,750
	11.25 / 12.25% Senior Toggle Notes due December 1, 2018	1,476				1,304
	9.75% Fixed Senior Notes due October 15, 2019	2				141
	Unamortized premium	303				351
	Unamortized discount	(149		)		(131		)
	Total EFIH	7,773				6,504
	EFCH
	9.58% Fixed Notes due in annual installments through December 4, 2019 (d)	35				35
	8.254% Fixed Notes due in quarterly installments through December 31, 2021 (d)	35				39
	1.065% Floating Rate Junior Subordinated Debentures, Series D due January 30, 2037 (e)	1				1
	8.175% Fixed Junior Subordinated Debentures, Series E due January 30, 2037	8				8
	Unamortized fair value discount (c)	(6		)		(7		)
	Total EFCH	73				76
	TCEH
	Senior Secured Facilities:
	3.710% TCEH Term Loan Facilities maturing October 10, 2014 (e)(f)	3,809				3,809
	3.679% TCEH Letter of Credit Facility maturing October 10, 2014 (e)	42				42
	4.709% TCEH Term Loan Facilities maturing October 10, 2017 (a)(e)(f)	15,691				15,351
	4.679% TCEH Letter of Credit Facility maturing October 10, 2017 (e)	1,020				1,020
	11.5% Fixed Senior Secured Notes due October 1, 2020	1,750				1,750
	15% Fixed Senior Secured Second Lien Notes due April 1, 2021	336				336
	15% Fixed Senior Secured Second Lien Notes due April 1, 2021, Series B	1,235				1,235
	10.25% Fixed Senior Notes due November 1, 2015 (a)	1,833				1,833
	10.25% Fixed Senior Notes due November 1, 2015, Series B (a)	1,292				1,292
	10.50 / 11.25% Senior Toggle Notes due November 1, 2016	1,749				1,749
		September 30,				December 31,
		2013				2012
	Pollution Control Revenue Bonds:
	Brazos River Authority:
	5.40% Fixed Series 1994A due May 1, 2029	$	39			$	39
	7.70% Fixed Series 1999A due April 1, 2033	111				111
	6.75% Fixed Series 1999B due September 1, 2034, remarketing date April 1, 2013 (g)	—				16
	7.70% Fixed Series 1999C due March 1, 2032	50				50
	8.25% Fixed Series 2001A due October 1, 2030	71				71
	8.25% Fixed Series 2001D-1 due May 1, 2033	171				171
	0.089% Floating Series 2001D-2 due May 1, 2033 (h)	97				97
	0.210% Floating Taxable Series 2001I due December 1, 2036 (i)	62				62
	0.089% Floating Series 2002A due May 1, 2037 (h)	45				45
	6.75% Fixed Series 2003A due April 1, 2038, remarketing date April 1, 2013 (g)	—				44
	6.30% Fixed Series 2003B due July 1, 2032	39				39
	6.75% Fixed Series 2003C due October 1, 2038	52				52
	5.40% Fixed Series 2003D due October 1, 2029, remarketing date October 1, 2014 (g)	31				31
	5.00% Fixed Series 2006 due March 1, 2041	100				100
Sabine River Authority of Texas:
6.45% Fixed Series 2000A due June 1, 2021	51				51
5.20% Fixed Series 2001C due May 1, 2028	70				70
5.80% Fixed Series 2003A due July 1, 2022	12				12
6.15% Fixed Series 2003B due August 1, 2022	45				45
Trinity River Authority of Texas:
6.25% Fixed Series 2000A due May 1, 2028	14				14
Unamortized fair value discount related to pollution control revenue bonds (c)	(107		)		(112		)
Other:
7.48% Fixed Secured Facility Bonds with amortizing payments through January 2017	36				—
7.46% Fixed Secured Facility Bonds with amortizing payments through January 2015	4				12
7% Fixed Senior Notes due March 15, 2013	—				5
Capital leases	56				64
Other	3				3
Unamortized discount	(110		)		(10		)
Unamortized fair value discount (c)	—				(1		)
Total TCEH	29,699				29,498
Total EFH Corp. consolidated	38,124				37,918
Less amount due currently	(38		)		(103		)
Total long-term debt	$	38,086			$	37,815
___________
(a)	Excludes the following debt held by EFIH or EFH Corp. (parent entity) and eliminated in consolidation:
	September 30,				December 31,
	2013				2012
EFH Corp. 10.875% Fixed Senior Notes due November 1, 2017	$	—			$	1,685
EFH Corp. 11.25 / 12.00% Senior Toggle Notes due November 1, 2017	—				3,441
EFH Corp. 5.55% Fixed Series P Senior Notes due November 15, 2014	281				279
EFH Corp. 6.50% Fixed Series Q Senior Notes due November 15, 2024	545				516
EFH Corp. 6.55% Fixed Series R Senior Notes due November 15, 2034	456				456
TCEH 4.709% Term Loan Facilities maturing October 10, 2017	19				19
TCEH 10.25% Fixed Senior Notes due November 1, 2015	213				213
TCEH 10.25% Fixed Senior Notes due November 1, 2015, Series B	150				150
Total	$	1,664			$	6,759
(b)	This financing is the obligation of a subsidiary of EFH Corp. and will be serviced with cash drawn by the beneficiary of a letter of credit that was previously issued to secure the obligation.
(c)	Amount represents unamortized fair value adjustments recorded under purchase accounting.
(d)	EFCH's obligations with respect to these financings are guaranteed by EFH Corp. and secured on a first-priority basis by, among other things, an undivided interest in the Comanche Peak nuclear generation facility.
(e)	Interest rates in effect at September 30, 2013.
(f)	Interest rate swapped to fixed on $18.140 billion principal amount of maturities through October 2014 and up to an aggregate $12.6 billion principal amount from October 2014 through October 2017.
(g)	These series are in the multiannual interest rate mode and are subject to mandatory tender prior to maturity on the mandatory remarketing date. On such date, the interest rate and interest rate period will be reset for the bonds.
(h)	Interest rates in effect at September 30, 2013. These series are in a daily interest rate mode and are classified as long-term as they are supported by long-term irrevocable letters of credit.
(i)	Interest rate in effect at September 30, 2013. This series is in a weekly interest rate mode and is classified as long-term as it is supported by long-term irrevocable letters of credit.
Schedule of Interest Rate Derivatives	'
	As reflected in the table below, at September 30, 2013, TCEH has entered into the following series of interest rate swap transactions that effectively fix the interest rates at between 5.5% and 9.3%.
	Fixed Rates					Expiration Dates		Notional Amount
	5.5	%	-	9.30%		October 2013 through October 2014			$	18.14		billion (a)
	6.8	%	-	9.00%		October 2015 through October 2017			$	12.6		billion (b)
	___________
	(a)	Swaps related to an aggregate $1.6 billion principal amount of debt expired in 2013. Per the terms of the transactions, the notional amount of swaps entered into in 2011 grew by $1.280 billion in 2013, substantially offsetting the expired swaps.
	(b)	These swaps are effective from October 2014 through October 2017. The $12.6 billion notional amount of swaps includes $3 billion that expires in October 2015 with the remainder expiring in October 2017.
	The interest rate swaps have resulted in net gains (losses) reported in interest expense and related charges as follows:
		Three Months Ended September 30,								Nine Months Ended September 30,
		2013				2012				2013				2012
	Realized net loss	$	(160	)		$	(168	)		$	(466	)		$	(505	)
	Unrealized net gain (loss)	413				(20		)		899				(16		)
	Total	$	253			$	(188	)		$	433			$	(521	)

Equity_Tables

Equity (Tables)	9 Months Ended
	Sep. 30, 2013
Stockholders' Equity Note [Abstract]	'
Schedule of Stockholders Equity	'
	The following table presents the changes to equity for the nine months ended September 30, 2013:
		EFH Corp. Shareholders’ Equity
		Common Stock (a)			Additional Paid-in Capital			Retained Earnings (Deficit)			Accumulated Other Comprehensive Income (Loss)			Noncontrolling Interests		Total Equity
	Balance at December 31, 2012	$	2		$	7,959		$	(18,939	)	$	(47	)	$	102	$	(10,923	)
	Net loss	—			—			(635		)	—			—		(635		)
	Effects of stock-based incentive compensation plans	—			5			—			—			—		5
	Repurchases of stock	—			(5		)	—			—			—		(5		)
	Change in unrecognized losses related to pension and OPEB plans (Note 10)	—			—			—			(4		)	—		(4		)
	Net effects of cash flow hedges	—			—			—			5			—		5
	Net effects related to Oncor	—			—			—			1			—		1
	Investment by noncontrolling interests	—			—			—			—			3		3
	Other	—			2			—			—			—		2
	Balance at September 30, 2013	$	2		$	7,961		$	(19,574	)	$	(45	)	$	105	$	(11,551	)
	____________
	(a)	Authorized shares totaled 2,000,000,000 at September 30, 2013. Outstanding shares totaled 1,669,861,383 and 1,680,539,245 at September 30, 2013 and December 31, 2012, respectively.
	The following table presents the changes to equity for the nine months ended September 30, 2012:
		EFH Corp. Shareholders’ Equity
		Common Stock (a)			Additional Paid-in Capital			Retained Earnings (Deficit)			Accumulated Other Comprehensive Income (Loss)			Noncontrolling Interests		Total Equity
	Balance at December 31, 2011	$	2		$	7,947		$	(15,579	)	$	(222	)	$	95	$	(7,757	)
	Net loss	—			—			(1,408		)	—			—		(1,408		)
	Effects of stock-based incentive compensation plans	—			11			—			—			—		11
	Change in unrecognized losses related to pension and OPEB plans	—			—			—			(25		)	—		(25		)
	Net effects of cash flow hedges	—			—			—			5			—		5
	Net effects related to Oncor	—			—			—			2			—		2
	Investment by noncontrolling interests	—			—			—			—			6		6
	Balance at September 30, 2012	$	2		$	7,958		$	(16,987	)	$	(240	)	$	101	$	(9,166	)
	____________
	(a)	Authorized shares totaled 2,000,000,000 at September 30, 2012. Outstanding shares totaled 1,680,539,245 and 1,679,539,245 at September 30, 2012 and December 31, 2011, respectively.
Schedule of Accumulated Other Comprehensive Income (Loss)	'
	Accumulated Other Comprehensive Income (Loss)
	The following table presents the changes to accumulated other comprehensive income (loss) for the nine months ended September 30, 2013. There was no other comprehensive income (loss) before reclassification for the period.
		Dedesignated Cash Flow Hedges – Interest Rate Swaps (Note 9)			Pension and Other Postretirement Employee Benefit Liabilities Adjustments (Note 10)			Accumulated Other Comprehensive Income (Loss)
	Balance at December 31, 2012	$	(64	)	$	17		$	(47	)
	Amounts reclassified from accumulated other comprehensive income (loss) and reported in:
	Operating costs	—			(4		)	(4		)
	Depreciation and amortization	2			—			2
	Selling, general and administrative expenses	—			(2		)	(2		)
	Interest expense and related charges	6			—			6
	Equity in earnings of unconsolidated subsidiaries	2			(1		)	1
	Income tax benefit (expense)	(3		)	2			(1		)
	Total amount reclassified from accumulated other comprehensive income (loss) during the period	7			(5		)	2
	Balance at September 30, 2013	$	(57	)	$	12		$	(45	)

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2013
Fair Value Disclosures [Abstract]	'
Schedule of assets and liabilities measured at fair value on a recurring basis	'
	Assets and liabilities measured at fair value consisted of the following:
	30-Sep-13
		Level 1			Level 2				Level 3 (a)				Reclassification (b)				Total
	Assets:
	Commodity contracts	$	140		$	941			$	48			$	2			$	1,131
	Interest rate swaps	—			84				—				—				84
	Nuclear decommissioning trust –	299			172				—				—				471
	equity securities (c)
	Nuclear decommissioning trust –	—			266				—				—				266
	debt securities (c)
	Total assets	$	439		$	1,463			$	48			$	2			$	1,952
	Liabilities:
	Commodity contracts	$	129		$	26			$	52			$	2			$	209
	Interest rate swaps	—			97				1,167				—				1,264
	Total liabilities	$	129		$	123			$	1,219			$	2			$	1,473
	31-Dec-12
		Level 1			Level 2				Level 3 (a)				Total
	Assets:
	Commodity contracts	$	180		$	1,784			$	83			$	2,047
	Interest rate swaps	—			134				—				134
	Nuclear decommissioning trust – equity securities (c)	249			144				—				393
	Nuclear decommissioning trust – debt securities (c)	—			261				—				261
	Total assets	$	429		$	2,323			$	83			$	2,835
	Liabilities:
	Commodity contracts	$	208		$	121			$	54			$	383
	Interest rate swaps	—			2,217				—				2,217
	Total liabilities	$	208		$	2,338			$	54			$	2,600
	____________
	(a)	See table below for description of Level 3 assets and liabilities.
	(b)	Fair values are determined on a contract basis, but certain contracts result in a current asset and a noncurrent liability, or vice versa, as presented in the balance sheet.
	(c)	The nuclear decommissioning trust investment is included in the other investments line in the balance sheet. See Note 13.
Schedule of fair value of the Level 3 assets and liabilities by major contract type (all related to commodity contracts) and the significant unobservable inputs used in the valuations	'
	The following tables present the fair value of the Level 3 assets and liabilities by major contract type and the significant unobservable inputs used in the valuations at September 30, 2013 and December 31, 2012:
	30-Sep-13
			Fair Value
	Contract Type (a)		Assets			Liabilities				Total				Valuation Technique		Significant Unobservable Input		Range (b)
	Electricity purchases and sales		$	5		$	(2	)		$	3			Valuation Model		Illiquid pricing locations (c)		$30 to $45/ MWh
																Hourly price curve shape (d)		$20 to $70/ MWh
	Electricity spread options		—			(19		)		(19		)		Option Pricing Model		Gas to power correlation (e)		45% to 100%
																Power volatility (f)		10% to 30%
	Electricity congestion revenue rights		37			(5		)		32				Market Approach (g)		Illiquid price differences between settlement points (h)		$0.00 to $30.00
	Coal purchases		1			(12		)		(11		)		Market Approach (g)		Illiquid price variances between mines (i)		$0.00 to $1.00
																Probability of default (j)		0% to 40%
																Recovery rate (k)		0% to 40%
	Interest rate swaps		—			(1,167		)		(1,167		)		Valuation Model		Nonperformance risk adjustment (l)		30% to 35%
	Other		5			(14		)		(9		)
	Total		$	48		$	(1,219	)		$	(1,171	)
	31-Dec-12
			Fair Value
	Contract Type (a)		Assets			Liabilities				Total				Valuation Technique		Significant Unobservable Input		Range (b)
	Electricity purchases and sales		$	5		$	(9	)		$	(4	)		Valuation Model		Illiquid pricing locations (c)		$20 to $40/ MWh
																Hourly price curve shape (d)		$20 to $50/ MWh
	Electricity spread options		34			(10		)		24				Option Pricing Model		Gas to power correlation (e)		20% to 90%
																Power volatility (f)		20% to 40%
	Electricity congestion revenue rights		41			(2		)		39				Market Approach (g)		Illiquid price differences between settlement points (h)		$0.00 to $0.50
	Coal purchases		—			(32		)		(32		)		Market Approach (g)		Illiquid price variances between mines (i)		$0.00 to $1.00
																Probability of default (j)		5% to 40%
																Recovery rate (k)		0% to 40%
	Other		3			(1		)		2
	Total		$	83		$	(54	)		$	29
	____________
	(a)	Electricity purchase and sales contracts include wind generation agreements and hedging positions in the ERCOT west region as well as power contracts, the valuations of which include unobservable inputs related to the hourly shaping of the price curve. Electricity spread option contracts consist of physical electricity call options. Electricity congestion revenue rights contracts consist of forward purchase contracts (swaps and options) used to hedge electricity price differences between settlement points within ERCOT. Coal purchase contracts relate to western (Powder River Basin) coal. Interest rate swaps are held by TCEH to hedge exposure to its variable rate debt.
	(b)	The range of the inputs may be influenced by factors such as time of day, delivery period, season and location.
	(c)	Based on the historical range of forward average monthly ERCOT West Hub prices.
	(d)	Based on the historical range of forward average hourly ERCOT North Hub prices.
	(e)	Estimate of the historical range based on forward natural gas and on-peak power prices for the ERCOT hubs most relevant to our spread options.
	(f)	Based on historical forward price changes.
	(g)	While we use the market approach, there is either insufficient market data to consider the valuation liquid or the significance of credit reserves or non-performance risk adjustments results in a Level 3 designation.
	(h)	Based on the historical price differences between settlement points in the ERCOT North Hub and the ERCOT West Hub.
	(i)	Based on the historical range of price variances between mine locations.
	(j)	Estimate of the range of probabilities of default based on past experience and the length of the contract as well as our and counterparties' credit ratings.
	(k)	Estimate of the default recovery rate based on historical corporate rates.
	(l)	Estimate of nonperformance risk adjustment based on TCEH senior secured bond trading values. See discussion immediately below regarding transfers into Level 3.
Schedule of changes in fair value of the Level 3 assets and liabilities (all related to commodity contracts)	'
	The following table presents the changes in fair value of the Level 3 assets and liabilities for the three and nine months ended September 30, 2013 and 2012. Transfers into Level 3 during 2013 as noted below reflect a nonperformance risk adjustment in the valuation of the TCEH interest rate swaps, which are secured by a first-lien interest in the same assets of TCEH (on a pari passu basis) with the TCEH Senior Secured Facilities and the TCEH Senior Secured Notes (see Note 5). At September 30, 2013, the estimated fair value of these interest rate swaps totaled $1.518 billion before consideration of nonperformance risk adjustment and $1.167 billion after consideration of such adjustment. The amount of the nonperformance risk adjustment was after consideration of derivative assets related to contracts with the same counterparties that are also secured by a first-lien interest in the assets of TCEH, and a master netting agreement is in place that provides for netting and setoff of amounts related to these contracts.
		Three Months Ended September 30,							Nine Months Ended September 30,
		2013			2012				2013				2012
	Net asset balance at beginning of period	$	88		$	12			$	29			$	53
	Total unrealized valuation gains (losses)	(24		)	12				(41		)		(5		)
	Purchases, issuances and settlements (a):
	Purchases	6			17				66				30
	Issuances	—			(4		)		(6		)		(15		)
	Settlements	(62		)	(56		)		(45		)		(34		)
	Transfers into Level 3 (b)	(1,179		)	3				(1,178		)		(42		)
	Transfers out of Level 3 (b)	—			—				4				(3		)
	Net change (c)	(1,259		)	(28		)		(1,200		)		(69		)
	Net liability balance at end of period	$	(1,171	)	$	(16	)		$	(1,171	)		$	(16	)
	Unrealized valuation gains (losses) relating to instruments held at end of period	$	254		$	15			$	280			$	(22	)
	____________
	(a)	Settlements reflect reversals of unrealized mark-to-market valuations previously recognized in net income. Purchases and issuances reflect option premiums paid or received.
	(b)	Includes transfers due to changes in the observability of significant inputs. Transfers in and out occur at the end of each quarter, which is when the assessments are performed. All Level 3 transfers during the periods presented are in and out of Level 2.
	(c)	Substantially all changes in values of commodity contracts are reported in the income statement in net gain (loss) from commodity hedging and trading activities. Changes in values of interest rate swaps are reported in the income statement in interest expense and related charges. Activity excludes changes in fair value in the month the position settled as well as amounts related to positions entered into and settled in the same month.

Commodity_And_Other_Derivative1

Commodity And Other Derivative Contractual Assets And Liabilities (Tables)	9 Months Ended
	Sep. 30, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Schedule of Commodity and Other Derivative Contractual Assets and Liabilities as Reported in the Balance Sheets	'
	The following tables provide detail of commodity and other derivative contractual assets and liabilities (with the column totals representing the net positions of the contracts) as reported in the balance sheets at September 30, 2013 and December 31, 2012:
	30-Sep-13
		Derivative assets								Derivative liabilities
		Commodity contracts				Interest rate swaps				Commodity contracts				Interest rate swaps				Total
	Current assets	$	972			$	84			$	—			$	—			$	1,056
	Noncurrent assets	159				—				—				—				159
	Current liabilities	(2		)		—				(204		)		(485		)		(691		)
	Noncurrent liabilities	—				—				(3		)		(779		)		(782		)
	Net assets (liabilities)	$	1,129			$	84			$	(207	)		$	(1,264	)		$	(258	)
	31-Dec-12
		Derivative assets								Derivative liabilities
		Commodity contracts				Interest rate swaps				Commodity contracts				Interest rate swaps				Total
	Current assets	$	1,461			$	134			$	—			$	—			$	1,595
	Noncurrent assets	586				—				—				—				586
	Current liabilities	—				—				(366		)		(678		)		(1,044		)
	Noncurrent liabilities	—				—				(17		)		(1,539		)		(1,556		)
	Net assets (liabilities)	$	2,047			$	134			$	(383	)		$	(2,217	)		$	(419	)
Schedule of Pre-tax Effect on Net Income of Derivatives Not Under Hedge Accounting, Including Realized and Unrealized Effects	'
	The following table presents the pretax effect of derivatives on net income (gains (losses)), including realized and unrealized effects:
			Three Months Ended September 30,								Nine Months Ended September 30,
	Derivative (income statement presentation)		2013				2012				2013				2012
	Commodity contracts (Net gain (loss) from commodity hedging and trading activities) (a)		$	98			$	(95	)		$	54			$	130
	Interest rate swaps (Interest expense and related charges) (b)		253				(188		)		433				(520		)
	Net gain (loss)		$	351			$	(283	)		$	487			$	(390	)
	____________
	(a)	Amount represents changes in fair value of positions in the derivative portfolio during the period, as realized amounts related to positions settled are assumed to equal reversals of previously recorded unrealized amounts.
	(b)	Includes unrealized mark-to-market net gain (loss) as well as the net realized effect on interest paid/accrued, both reported in "Interest Expense and Related Charges" (see Note 13).
Schedule of Pre-tax Effect on Net Income and Other Comprehensive Income (OCI) of Derivative Instruments Previously Accounted for as Cash Flow Hedges	'
	The following table presents the pretax effect (all losses) on net income and other comprehensive income (OCI) of derivative instruments previously accounted for as cash flow hedges. There were no amounts recognized in OCI for the three and nine months ended September 30, 2013 and 2012.
	Derivative type (income statement presentation of loss reclassified from accumulated OCI into income)		Three Months Ended September 30,								Nine Months Ended September 30,
			2013				2012				2013				2012
	Interest rate swaps (Interest expense and related charges)		$	(1	)		$	(1	)		$	(6	)		$	(6	)
	Interest rate swaps (Depreciation and amortization)		(1		)		(1		)		(2		)		(2		)
	Total		$	(2	)		$	(2	)		$	(8	)		$	(8	)
Offsetting Assets and Liabilities	'
	The following tables reconcile our derivative assets and liabilities as presented in the consolidated balance sheet to net amounts after taking into consideration netting arrangements with counterparties and financial collateral:
	30-Sep-13
			Amounts Presented in Balance Sheet				Offsetting Financial Instruments (a)				Financial Collateral (Received) Pledged (b)				Net Amounts (c)
	Derivative assets:
	Commodity contracts		$	1,131			$	(613	)		$	(351	)		$	167
	Interest rate swaps		84				(84		)		—				—
	Total derivative assets		1,215				(697		)		(351		)		167
	Derivative liabilities:
	Commodity contracts		(209		)		180				11				(18		)
	Interest rate swaps		(1,264		)		517				—				(747		)
	Total derivative liabilities		(1,473		)		697				11				(765		)
	Net amounts		$	(258	)		$	—			$	(340	)		$	(598	)
	31-Dec-12
			Amounts Presented in Balance Sheet				Offsetting Financial Instruments (a)				Financial Collateral (Received) Pledged (b)				Net Amounts
	Derivative assets:
	Commodity contracts		$	2,047			$	(1,263	)		$	(597	)		$	187
	Interest rate swaps		134				(134		)		—				—
	Total derivative assets		2,181				(1,397		)		(597		)		187
	Derivative liabilities:
	Commodity contracts		(383		)		319				29				(35		)
	Interest rate swaps		(2,217		)		1,078				—				(1,139		)
	Total derivative liabilities		(2,600		)		1,397				29				(1,174		)
	Net amounts		$	(419	)		$	—			$	(568	)		$	(987	)
	____________
	(a)	Offsetting financial instruments with respect to commodity contracts include amounts related to interest rate swaps and vice versa. Amounts exclude trade accounts receivable and payable related to settled financial instruments.
	(b)	Financial collateral consists entirely of cash margin deposits.
	(c)	Includes net liability positions totaling approximately $1.2 billion (before nonperformance risk adjustment) related to counterparties with positions that are secured by a first-lien interest in the same assets of TCEH (on a pari passu basis) with the TCEH Senior Secured Facilities and the TCEH Senior Secured Notes.
Schedule of Gross Notional Amounts of Derivative Volumes	'
	The following table presents the gross notional amounts of derivative volumes at September 30, 2013 and December 31, 2012:
			30-Sep-13				31-Dec-12
	Derivative type		Notional Volume								Unit of Measure
	Interest rate swaps:
	Floating/fixed (a)		$	32,440			$	32,760			Million US dollars
	Basis		$	11,967			$	11,967			Million US dollars
	Natural gas:
	Natural gas forward sales and purchases (b)		452				875				Million MMBtu
	Locational basis swaps		337				495				Million MMBtu
	All other		2,021				1,549				Million MMBtu
	Electricity		21,663				76,767				GWh
	Congestion Revenue Rights (c)		82,156				111,185				GWh
	Coal		11				13				Million US tons
	Fuel oil		28				47				Million gallons
	Uranium		575				441				Thousand pounds
	____________
	(a)	Includes notional amount of interest rate swaps with maturity dates through October 2014 as well as notional amount of swaps effective from October 2014 with maturity dates through October 2017 (see Note 5).
	(b)	Represents gross notional forward sales, purchases and options transactions in the natural gas hedging program. The net amount of these transactions was approximately 210 million MMBtu and 360 million MMBtu at September 30, 2013 and December 31, 2012, respectively.
	(c)	Represents gross forward purchases associated with instruments used to hedge electricity price differences between settlement points within ERCOT.

Pension_And_Other_Postretireme1

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Tables)	9 Months Ended
	Sep. 30, 2013
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'
Schedule of Net Benefit Costs	'
	Net pension and OPEB costs related to plans sponsored by EFH Corp. for the three and nine months ended September 30, 2013 and 2012 are comprised of the following:
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Components of net pension costs:
	Service cost	$	2		$	13		$	6		$	36
	Interest cost	3			38			9			118
	Expected return on assets	(2		)	(42		)	(5		)	(122		)
	Amortization of net loss	2			30			6			84
	Pension costs	5			39			16			116
	Components of net OPEB costs:
	Service cost	3			3			8			7
	Interest cost	10			11			31			33
	Expected return on assets	(3		)	(3		)	(9		)	(9		)
	Amortization of transition obligation	—			—			—			1
	Amortization of prior service cost	(8		)	(8		)	(23		)	(24		)
	Amortization of net loss	7			4			22			11
	OPEB costs	9			7			29			19
	Total benefit costs	14			46			45			135
	Less amounts expensed by Oncor	(6		)	(8		)	(19		)	(26		)
	Less amounts deferred principally as a regulatory asset or property by Oncor	(6		)	(21		)	(18		)	(64		)
	Net amounts recognized as expense by EFH Corp. and consolidated subsidiaries	$	2		$	17		$	8		$	45

Segment_Information_Tables

Segment Information (Tables)	9 Months Ended
	Sep. 30, 2013
Segment Reporting [Abstract]	'
Schedule of segment reporting information, by segment	'
	We account for intersegment sales and transfers as if the sales or transfers were to third parties, that is, at current market prices or regulated rates.
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Operating revenues (all Competitive Electric)	$	1,893		$	1,752		$	4,572		$	4,358
	Equity in earnings of unconsolidated subsidiaries (net of tax) — Regulated Delivery (net of noncontrolling interest of $29, $27, $66 and $64)	$	114		$	109		$	255		$	249
	Net income (loss):
	Competitive Electric	$	18		$	(393	)	$	(768	)	$	(1,319	)
	Regulated Delivery	114			109			255			249
	Corporate and Other	(127		)	(123		)	(122		)	(338		)
	Consolidated	$	5		$	(407	)	$	(635	)	$	(1,408	)

Supplementary_Financial_Inform1

Supplementary Financial Information (Tables)	9 Months Ended
	Sep. 30, 2013
Supplementary Financial Information [Abstract]	'
Schedule of other income and deductions	'
	Other Income and Deductions
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Other income:
	Office space rental income (a)	$	3		$	3		$	9		$	9
	Consent fee related to novation of hedge positions between counterparties (b)	—			—			—			6
	Insurance/litigation settlements (b)	—			—			2			2
	All other	2			3			8			8
	Total other income	$	5		$	6		$	19		$	25
	Other deductions:
	Impairment of remaining equipment from cancelled generation development program (b)	$	27		$	—		$	27		$	—
	Impairment of mineral interests (b)	—			24			—			24
	Impairment of computer software assets (a)	—			7			—			7
	Other asset impairments (b)	3			—			3			—
	Counterparty contract settlement (b)	—			4			—			4
	Ongoing employee retirement benefit expense related to discontinued businesses (a)	—			4			(1		)	10
	All other	6			3			11			9
	Total other deductions	$	36		$	42		$	40		$	54
	____________
	(a)	Reported in Corporate and Other.
	(b)	Reported in Competitive Electric segment.
Schedule of interest expense and related charges	'
	Interest Expense and Related Charges
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Interest paid/accrued (including net amounts settled/accrued under interest rate swaps)	$	851		$	812		$	2,532		$	2,405
	Interest payable with additional toggle notes (Note 5)	45			61			130			177
	Unrealized mark-to-market net (gain) loss on interest rate swaps (a)	(414		)	21			(903		)	12
	Amortization of interest rate swap losses at dedesignation of hedge accounting	2			2			6			7
	Amortization of fair value debt discounts resulting from purchase accounting	5			11			15			33
	Amortization of debt issuance, amendment and extension costs and discounts	49			48			154			143
	Capitalized interest	(5		)	(11		)	(19		)	(31		)
	Total interest expense and related charges	$	533		$	944		$	1,915		$	2,746
	____________
	(a)	Three months ended September 30, 2013 and 2012 amounts include net gains totaling $413 million and net losses totaling $20 million, respectively, related to TCEH swaps (see Note 5) and net gains totaling $1 million and net losses totaling $1 million, respectively, related to EFH Corp. swaps substantially closed through offsetting positions.
Schedule of restricted cash	'
	Restricted Cash
		30-Sep-13						31-Dec-12
		Current Assets			Noncurrent Assets			Current Assets			Noncurrent Assets
	Amounts in escrow to settle TCEH Demand Notes (Note 11)	$	—		$	—		$	680		$	—
	Amounts related to TCEH's Letter of Credit Facility (Note 5)	—			947			—			947
	Other	4			—			—			—
	Total restricted cash	$	4		$	947		$	680		$	947
Schedule of inventories by major category	'
	Inventories by Major Category
		September 30,			December 31,
		2013			2012
	Materials and supplies	$	216		$	201
	Fuel stock	155			168
	Natural gas in storage	29			24
	Total inventories	$	400		$	393
Summary of other investments	'
	Other Investments
		September 30,			December 31,
		2013			2012
	Nuclear plant decommissioning trust	$	737		$	654
	Assets related to employee benefit plans, including employee savings programs, net of distributions	63			70
	Land	40			41
	Miscellaneous other	3			2
	Total other investments	$	843		$	767
Summary of investments in the fund	'
	A summary of investments in the fund follows:
		30-Sep-13
		Cost (a)			Unrealized gain			Unrealized loss			Fair market
											value
	Debt securities (b)	$	261		$	9		$	(4	)	$	266
	Equity securities (c)	252			227			(8		)	471
	Total	$	513		$	236		$	(12	)	$	737
		31-Dec-12
		Cost (a)			Unrealized gain			Unrealized loss			Fair market
											value
	Debt securities (b)	$	246		$	16		$	(1	)	$	261
	Equity securities (c)	245			161			(13		)	393
	Total	$	491		$	177		$	(14	)	$	654
	____________
	(a)	Includes realized gains and losses on securities sold.
	(b)	The investment objective for debt securities is to invest in a diversified tax efficient portfolio with an overall portfolio rating of AA or above as graded by S&P or Aa2 by Moody's Investors Services, Inc. The debt securities are heavily weighted with municipal bonds. The debt securities had an average coupon rate of 3.97% and 4.38% at September 30, 2013 and December 31, 2012, respectively, and an average maturity of 6 years at both September 30, 2013 and December 31, 2012.
	(c)	The investment objective for equity securities is to invest tax efficiently and to match the performance of the S&P 500 Index.
Summary of proceeds from sales of available-for-sale securities and the related realized gains and losses from such sales	'
	The following table summarizes proceeds from sales of available-for-sale securities and the related realized gains and losses from such sales.
		Three Months Ended September 30,						Nine Months Ended September 30,
		2013			2012			2013			2012
	Realized gains	$	1		$	—		$	2		$	1
	Realized losses	$	(3	)	$	(1	)	$	(3	)	$	(2	)
	Proceeds from sales of securities	$	23		$	25		$	128		$	56
	Investments in securities	$	(28	)	$	(30	)	$	(140	)	$	(68	)
Schedule of asset retirement and mining reclamation obligations	'
	The following table summarizes the changes to these obligations, reported in other current liabilities and other noncurrent liabilities and deferred credits in the balance sheet, for the nine months ended September 30, 2013:
		Nuclear Plant Decommissioning			Mining Land Reclamation			Other			Total
	Liability at December 31, 2012	$	368		$	135		$	33		$	536
	Additions:
	Accretion	17			23			1			41
	Reductions:
	Payments	—			(72		)	(1		)	(73		)
	Liability at September 30, 2013	385			86			33			504
	Less amounts due currently	—			(60		)	—			(60		)
	Noncurrent liability at September 30, 2013	$	385		$	26		$	33		$	444
Schedule of other noncurrent liabilities and deferred credits	'
	Other Noncurrent Liabilities and Deferred Credits
	The balance of other noncurrent liabilities and deferred credits consists of the following:
		September 30,			December 31,
		2013			2012
	Uncertain tax positions (including accrued interest)	$	427		$	2,005
	Retirement plan and other employee benefits (a)	1,050			1,035
	Asset retirement and mining reclamation obligations	444			452
	Unfavorable purchase and sales contracts	596			620
	Nuclear decommissioning cost over-recovery (Note 11)	352			284
	Other	34			30
	Total other noncurrent liabilities and deferred credits	$	2,903		$	4,426
	____________
	(a)	Includes $839 million and $825 million at September 30, 2013 and December 31, 2012, respectively, representing pension and OPEB liabilities related to Oncor (see Note 11).
Schedule of estimated amortization of unfavorable purchase and sales contracts for each of the next five fiscal years	'
	The estimated amortization of unfavorable purchase and sales contracts for each of the next five fiscal years is as follows:
	Year		Amount
	2013		$	25
	2014		$	24
	2015		$	23
	2016		$	23
	2017		$	23
Schedule of supplemental cash flow information	'
	Supplemental Cash Flow Information
		Nine Months Ended September 30,
		2013			2012
	Cash payments (receipts) related to:
	Interest paid (a)	$	2,391		$	2,150
	Capitalized interest	(19		)	(31		)
	Interest paid (net of capitalized interest) (a)	$	2,372		$	2,119
	Income taxes	$	65		$	67
	Noncash investing and financing activities:
	Principal amount of toggle notes issued in lieu of cash interest (Note 5)	$	83		$	114
	Construction expenditures (b)	$	65		$	55
	Debt exchange and extension transactions (Note 5)	$	(326	)	$	—
	Debt assumed related to acquisition of combustion turbine trust interest	$	(45	)	$	—
	____________
	(a)	Net of amounts received under interest rate swap agreements.
	(b)	Represents end-of-period accruals.

Business_And_Significant_Accou2

Business And Significant Accounting Policies (Details) (USD $)

9 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2012

Dec. 31, 2011

Nov. 30, 2008

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Reportable_segment

Oncor [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Energy Future Competitive Holdings Company [Member]

EFH Corp. [Member]

Line of Credit [Member]

Letter of Credit Facility maturing October 2017 [Member]

TCEH Term Loan Facilities maturing October 10, 2014 [Member]

TCEH Term Loan Facilities maturing October 10, 2014 [Member]

Oncor [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Letter of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Business and Significant Accounting Policies

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity method investment, ownership (as a percent)

'

'

'

'

'

'

80.00%

'

'

'

'

'

'

'

Sale of equity ownership interest (as a percent)

'

'

'

'

19.75%

'

'

'

'

'

'

'

'

'

Number of reportable segments (in reportable segments)

2

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash and cash equivalents

$1,816

$1,913

$1,112

$826

'

'

'

$1,300

'

'

'

'

'

'

Resticted cash, additional letters of credit that can be supported

'

'

'

'

'

'

'

'

'

'

'

171

'

'

Long-term debt, gross

'

'

'

'

'

'

'

'

'

'

22,616

'

3,809

[1],[2]

3,809

[1],[2]

Equity method investment, Maximum ownership percentage for accounting treatment (as a percent)

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Long-term And Short-term Combined Amount, Gross

'

'

'

'

'

$7,600

'

'

$32,200

$650

'

'

'

'

[1]

Interest rate swapped to fixed on $18.140 billion principal amount of maturities through October 2014 and up to an aggregate $12.6 billion principal amount from October 2014 through October 2017.

[2]

Interest rates in effect at September 30, 2013.

Variable_Interest_Entities_Car

Variable Interest Entities (Carrying Amounts and Classifications of Assets and Liabilities Related to Consolidated VIEs) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013
In Millions, unless otherwise specified					Consolidated VIEs [Member]	Consolidated VIEs [Member]	Texas Competitive Electric Holdings Company LLC [Member]	Texas Competitive Electric Holdings Company LLC [Member]	MHI [Member]
					Nuclear_generation_units			Consolidated VIEs [Member]	Consolidated VIEs [Member]
Variable Interest Entity [Line Items]	'	'	'	'	'	'	'	'	'
Number of new nuclear generation units in development (in nuclear generation units)	'	'	'	'	2	'	'	'	'
Variable interest entity, ownership percentage (as a percent)	'	'	'	'	'	'	'	88.00%	12.00%
Assets	'	'	'	'	'	'	'	'	'
Cash and cash equivalents	$1,816	$1,913	$1,112	$826	$37	$43	$1,300	'	'
Accounts receivable	808	718	'	'	573	445	'	'	'
Property, plant and equipment	18,103	18,705	'	'	138	134	'	'	'
Other assets, including $3 million and $12 million of current assets	'	'	'	'	12	16	'	'	'
Total assets	38,690	40,970	'	'	760	638	'	'	'
Other current assets	64	143	'	'	3	12	'	'	'
Liabilities	'	'	'	'	'	'	'	'	'
Short-term borrowings	2,226	2,136	'	'	172	82	'	'	'
Trade accounts payable	368	394	'	'	1	1	'	'	'
Other current liabilities	387	353	'	'	13	7	'	'	'
Total liabilities	$50,241	$51,893	'	'	$186	$90	'	'	'

Variable_Interest_Entities_Onc

Variable Interest Entities (Oncor Holdings and Distributions from Oncor Holdings) (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Schedule of Equity Method Investments [Line Items]	'	'	'
Investment in unconsolidated subsidiary	$5,959	'	$5,850
Distributions of earnings from unconsolidated subsidiaries	148	100	'
Oncor Holdings [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Distributions of earnings from unconsolidated subsidiaries	148	100	'
Eligible distributions after accounting for regulatory restrictions	$187	'	'
PUCT required regulatory capitalization, ratio of debt to equity, debt (as a percent)	60.00%	'	'
PUCT required regulatory capitalization, ratio of debt to equity, equity (as a percent)	40.00%	'	'
Regulatory capitalization, ratio of debt to equity, debt (as a percent)	58.70%	'	'
Regulatory capitalization, ratio of debt to equity, equity (as a percent)	41.30%	'	'
Oncor Holdings [Member] | Oncor [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Percentage of equity method investment consolidated revenues related to services provided to entity (as a percent)	28.00%	29.00%	'
Energy Future Intermediate Holding CO LLC [Member] | Oncor [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Equity method investment, ownership (as a percent)	80.00%	'	'

Variable_Interest_Entities_Onc1

Variable Interest Entities (Oncor Holdings Financial Statements) (Details) (Oncor Holdings [Member], USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Oncor Holdings [Member]	'	'	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'	'	'
Operating revenues	$966	$925	$2,640	$2,536	'
Operation and maintenance expenses	-315	-292	-919	-873	'
Depreciation and amortization	-207	-201	-608	-577	'
Taxes other than income taxes	-112	-113	-315	-313	'
Other income	4	6	14	20	'
Other deductions	-2	-1	-11	-4	'
Interest income	0	3	2	24	'
Interest expense and related charges	-94	-96	-283	-279	'
Income before income taxes	240	231	520	534	'
Income tax expense	-97	-95	-199	-221	'
Net income	143	136	321	313	'
Net income attributable to noncontrolling interests	-29	-27	-66	-64	'
Net income attributable to Oncor Holdings	114	109	255	249	'
Current assets:	'	'	'	'	'
Cash and cash equivalents	17	'	17	'	45
Restricted cash	61	'	61	'	55
Trade accounts receivable — net	404	'	404	'	338
Trade accounts and other receivables from affiliates	158	'	158	'	53
Inventories	67	'	67	'	73
Accumulated deferred income taxes	35	'	35	'	26
Prepayments and other current assets	82	'	82	'	82
Total current assets	824	'	824	'	672
Restricted cash	16	'	16	'	16
Other investments	85	'	85	'	83
Property, plant and equipment — net	11,794	'	11,794	'	11,318
Goodwill	4,064	'	4,064	'	4,064
Regulatory assets — net	1,512	'	1,512	'	1,788
Other noncurrent assets	70	'	70	'	78
Total assets	18,365	'	18,365	'	18,019
Current liabilities:	'	'	'	'	'
Short-term borrowings	860	'	860	'	735
Long-term debt due currently	129	'	129	'	125
Trade accounts payable — nonaffiliates	100	'	100	'	121
Income taxes payable to EFH Corp.	35	'	35	'	34
Accrued taxes other than income	134	'	134	'	153
Accrued interest	65	'	65	'	95
Other current liabilities	111	'	111	'	110
Total current liabilities	1,434	'	1,434	'	1,373
Accumulated deferred income taxes	1,881	'	1,881	'	1,736
Investment tax credits	22	'	22	'	24
Long-term debt, less amounts due currently	5,422	'	5,422	'	5,400
Other noncurrent liabilities and deferred credits	1,931	'	1,931	'	1,999
Total liabilities	$10,690	'	$10,690	'	$10,532

Goodwill_And_Identifiable_Inta2

Goodwill And Identifiable Intangible Assets (Narrative) (Details) (Competitive Electric [Member], USD $)	3 Months Ended
In Billions, unless otherwise specified	Dec. 31, 2012
Competitive Electric [Member]	'
Goodwill and Indentifiable Intangible Assets [Line Items]	'
Impairment of goodwill	$1.20

Goodwill_And_Identifiable_Inta3

Goodwill And Identifiable Intangible Assets (Goodwill) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Goodwill [Line Items]	'	'
Balance, goodwill	$4,952	$4,952
Competitive Electric [Member]	'	'
Goodwill [Line Items]	'	'
Goodwill before impairment charges	18,342	18,342
Accumulated impairment charges	-13,390	-13,390
Balance, goodwill	$4,952	$4,952

Goodwill_And_Identifiable_Inta4

Goodwill And Identifiable Intangible Assets (Identifiable Intangible Assets Reported in the Balance Sheet) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Finite-Lived and Indefinite-Lived Intangible [Line Items]	'	'
Gross Carrying Amount	$2,165	$2,128
Accumulated Amortization	1,434	1,341
Total intangible assets subject to amortization, net	731	787
Total intangible assets	1,697	1,755
Retail trade name (not subject to amortization) [Member]	'	'
Finite-Lived and Indefinite-Lived Intangible [Line Items]	'	'
Gross Carrying Amount, Unamortized Intangibles	955	955
Mineral interests (not currently subject to amortization) [Member]	'	'
Finite-Lived and Indefinite-Lived Intangible [Line Items]	'	'
Gross Carrying Amount, Unamortized Intangibles	11	13
Retail customer relationship [Member]	'	'
Finite-Lived and Indefinite-Lived Intangible [Line Items]	'	'
Gross Carrying Amount	463	463
Accumulated Amortization	396	378
Total intangible assets subject to amortization, net	67	85
Favorable purchase and sales contracts [Member]	'	'
Finite-Lived and Indefinite-Lived Intangible [Line Items]	'	'
Gross Carrying Amount	551	552
Accumulated Amortization	333	314
Total intangible assets subject to amortization, net	218	238
Capitalized in-service software [Member]	'	'
Finite-Lived and Indefinite-Lived Intangible [Line Items]	'	'
Gross Carrying Amount	357	356
Accumulated Amortization	193	174
Total intangible assets subject to amortization, net	164	182
Environmental allowances and credits [Member]	'	'
Finite-Lived and Indefinite-Lived Intangible [Line Items]	'	'
Gross Carrying Amount	598	594
Accumulated Amortization	407	393
Total intangible assets subject to amortization, net	191	201
Mining development costs [Member]	'	'
Finite-Lived and Indefinite-Lived Intangible [Line Items]	'	'
Gross Carrying Amount	196	163
Accumulated Amortization	105	82
Total intangible assets subject to amortization, net	$91	$81

Goodwill_And_Identifiable_Inta5

Goodwill And Identifiable Intangible Assets (Amortization Expense Related to Intangible Assets (including income statement line item)) (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Finite-Lived Intangible Assets [Line Items]	'	'	'	'
Amortization expense	$35	$36	$102	$109
Retail customer relationship [Member] | Depreciation and amortization [Member] | Competitive Electric [Member]	'	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'	'
Amortization expense	6	8	18	25
Favorable purchase and sales contracts [Member] | Operating revenues/ Fuel, purchased power costs and delivery fees [Member] | Competitive Electric [Member]	'	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'	'
Amortization expense	6	5	19	20
Capitalized in-service software [Member] | Depreciation and amortization [Member]	'	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'	'
Amortization expense	10	10	31	29
Environmental allowances and credits [Member] | Fuel, purchased power costs and delivery fees [Member] | Competitive Electric [Member]	'	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'	'
Amortization expense	5	6	11	15
Mining development costs [Member] | Depreciation and amortization [Member] | Competitive Electric [Member]	'	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'	'
Amortization expense	$8	$7	$23	$20

Goodwill_And_Identifiable_Inta6

Goodwill And Identifiable Intangible Assets (Estimated Amortization of Intangible Assets) (Details) (USD $)	Sep. 30, 2013
In Millions, unless otherwise specified
Estimated Amortization Expense	'
2013	$138
2014	125
2015	115
2016	95
2017	$75

Trade_Accounts_Receivable_And_2

Trade Accounts Receivable And Accounts Receivable Securitization Program (Narrative) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2013	Dec. 31, 2012	Oct. 31, 2013	Oct. 31, 2013
In Millions, unless otherwise specified					Texas Competitive Electric Holdings Company LLC [Member]	Texas Competitive Electric Holdings Company LLC [Member]	Texas Competitive Electric Holdings Company LLC [Member]	Consolidation, Eliminations [Member]	Consolidation, Eliminations [Member]	Subsequent Event [Member]	Subsequent Event [Member]
							T X U Receivables Company [Member]	Texas Competitive Electric Holdings Company LLC [Member]	Texas Competitive Electric Holdings Company LLC [Member]	T X U Receivables Company [Member]	Consolidation, Eliminations [Member]
								T X U Receivables Company [Member]	T X U Receivables Company [Member]		Texas Competitive Electric Holdings Company LLC [Member]
											T X U Receivables Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Program Termination, Face Amount of Receivables Repurchased	'	'	'	'	'	'	'	'	'	'	$491
Program Termination, Purchase Price of Receivables Repurchased	'	'	'	'	'	'	'	'	'	'	474
Program Termination, Repayment of Subordinated Notes Payable	'	'	'	'	'	'	'	'	'	'	11
Program Termination, Repayment of Borrowings To Financial Institution	'	'	'	'	'	'	'	'	'	126	'
Maximum funding capacity	'	'	'	'	200	'	'	'	'	'	'
Program funding	'	'	'	'	172	82	'	'	'	'	'
Decrease in customer deposits held by the originator because TCEH's credit ratings were lower than Ba3/BB-	'	'	'	'	33	'	'	'	'	'	'
Limited percentage of uncollected accounts receivable purchased	'	'	'	'	'	'	25.00%	'	'	'	'
Cash and cash equivalents	1,816	1,913	1,112	826	1,300	'	'	37	'	'	'
Subordinated notes payable	'	'	'	'	'	'	'	$93	$97	'	'

Trade_Accounts_Receivable_And_3

Trade Accounts Receivable And Accounts Receivable Securitization Program (Program fee amounts/ Activities of TXU Receivables Company/ Trade Accounts Receivable/ Allowance for Uncollectible Accounts Receivable) (Details) (USD $)	9 Months Ended			3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013		Sep. 30, 2012
				Texas Competitive Electric Holdings Company LLC [Member]	Texas Competitive Electric Holdings Company LLC [Member]	Texas Competitive Electric Holdings Company LLC [Member]		Texas Competitive Electric Holdings Company LLC [Member]
				T X U Receivables Company [Member]	T X U Receivables Company [Member]	T X U Receivables Company [Member]		T X U Receivables Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]	'	'	'	'	'	'		'
Program fees	'	'	'	$3	$2	$6		$6
Program fees as a percentage of average funding (annualized)	'	'	'	5.10%	4.90%	5.80%		6.20%
Cash collections on accounts receivable	'	'	'	'	'	3,200		3,501
Face amount of new receivables purchased	'	'	'	'	'	-3,328	[1]	-3,571	[1]
Discount from face amount of purchased receivables	'	'	'	'	'	29		8
Program fees paid to financial institution	'	'	'	-3	-2	-6		-6
Servicing fees paid for recordkeeping and collection services	'	'	'	'	'	0		-2
Decrease in subordinated notes payable	'	'	'	'	'	-4		-10
Increase in cash held	'	'	'	'	'	17		0
Other — net	'	'	'	'	'	2		0
Cash flows provided to originator under the program	'	'	'	'	'	-90		-80
Wholesale and retail trade accounts receivable	825	'	727	'	'	'		'
Allowance for uncollectible accounts	-17	-15	'	'	'	'		'
Trade accounts receivable — reported in balance sheet, including $573 and $445 in pledged retail receivables	808	'	718	'	'	'		'
Pledged retail receivables	573	'	445	'	'	'		'
Unbilled Receivables, Current	272	'	260	'	'	'		'
Allowance for Doubtful Accounts Receivable [Roll Forward]	'	'	'	'	'	'		'
Allowance for uncollectible accounts receivable at beginning of period	9	27	'	'	'	'		'
Increase for bad debt expense	23	20	'	'	'	'		'
Decrease for account write-offs	-15	-32	'	'	'	'		'
Allowance for uncollectible accounts receivable at end of period	$17	$15	'	'	'	'		'
[1]	Net of allowance for uncollectible accounts.

ShortTerm_Borrowings_And_LongT2

Short-Term Borrowings And Long-Term Debt (Short-Term Borrowings) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Short-term Debt [Line Items]	'	'
Short-term borrowings	$2,226	$2,136
Texas Competitive Electric Holdings Company LLC [Member]	'	'
Short-term Debt [Line Items]	'	'
Program funding under the accounts receivable securitization program	172	82
Texas Competitive Electric Holdings Company LLC [Member] | Revolving Credit Facility [Member]	'	'
Short-term Debt [Line Items]	'	'
Short-term borrowings	$2,054	$2,054
Short-term borrowings, weighted average interest rate (as a percent)	4.68%	4.40%

ShortTerm_Borrowings_And_LongT3

Short-Term Borrowings And Long-Term Debt (Credit Facilities) (Details) (USD $)

1 Months Ended

9 Months Ended

In Millions, unless otherwise specified

Jan. 31, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Jan. 31, 2013

Jan. 31, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Letter of Credit [Member]

Letter of Credit [Member]

Letter of Credit [Member]

Line of Credit [Member]

Revolving Credit Facility maturing October 2013 Extended to October 2016 [Member]

Revolving Credit Facility maturing October 2016 [Member]

Letter of Credit Facility maturing October 2017 [Member]

Letter of Credit Facility maturing October 2014 [Member]

Letter of Credit Facility maturing October 2014 [Member]

Credit Facilities [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Facility Limit

'

'

'

$3,116

$2,054

[1]

$645

[1]

$2,054

[1]

$1,062

[2]

'

'

'

Letters of Credit

'

'

'

0

'

'

0

[1]

0

[2]

'

'

'

Cash Borrowings

'

'

'

3,116

'

'

2,054

[1]

1,062

[2]

'

'

'

Availability

'

'

'

0

'

'

0

[1]

0

[2]

'

'

'

Basis Spread on LIBOR Rate (as a percent)

'

'

'

'

'

'

4.50%

'

3.50%

'

'

Per annum rate, commitment fee of average daily unused portion of credit facility (as a percent)

'

'

'

'

'

'

1.00%

'

'

'

'

Long-term debt, gross

'

'

'

'

'

'

'

'

42

[3]

42

[3]

22,616

Restricted cash

'

947

947

'

'

'

'

947

'

'

'

Reduction in restricted cash related to letter of credit drawn related to office building financing

'

'

'

'

'

'

'

-115

'

'

'

Restricted Cash, Amount supported in letters of credit outstanding

'

'

'

'

'

'

'

776

'

'

'

Resticted cash, additional letters of credit that can be supported

'

'

'

'

'

'

'

171

'

'

'

Debt Issuance Fee Paid By Issuance Of Debt

$340

'

'

'

'

'

'

'

'

'

'

[1]

Facility used for borrowings for general corporate purposes. Borrowings are classified as short-term borrowings. At September 30, 2013, borrowings under the facility bear interest at LIBOR plus 4.50%, and a commitment fee is payable quarterly in arrears at a rate per annum equal to 1.00% of the average daily unused portion of the facility. In January 2013, commitments previously maturing in 2013 were extended to 2016 as discussed below.

[2]

Facility, $42 million of which matures in October 2014, used for issuing letters of credit for general corporate purposes, including, but not limited to, providing collateral support under hedging arrangements and other commodity transactions that are not secured by a first-lien interest in the assets of TCEH. The borrowings under this facility have been recorded by TCEH as restricted cash that supports issuances of letters of credit and are classified as long-term debt. At September 30, 2013, the restricted cash totaled $947 million, after reduction for a $115 million letter of credit drawn in 2009 related to an office building financing. At September 30, 2013, the restricted cash supports $776 million in letters of credit outstanding, leaving $171 million in available letter of credit capacity.

[3]

Interest rates in effect at September 30, 2013.

ShortTerm_Borrowings_And_LongT4

Short-Term Borrowings And Long-Term Debt (Long-Term Debt) (Details) (USD $)	Sep. 30, 2013		Jun. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Debt Instrument [Line Items]	'		'	'
Debt and capital lease obligations	$38,124		'	$37,918
Long-term debt due currently	-38		'	-103
Total long-term debt	38,086		'	37,815
Consolidation, Eliminations [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	1,664		'	6,759
EFH Corp. [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Unamortized fair value premium (discount)	-123	[1]	'	-137	[1]
Debt and capital lease obligations	579		'	1,840
EFH Corp. [Member] | Senior Secured Debt [Member] | 10% Fixed Senior Secured First Lien Notes due January 15, 2020 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	3		'	1,061
Debt Instrument, Interest Rate, Stated Percentage	10.00%		'	'
EFH Corp. [Member] | Senior Secured Debt [Member] | 9.75% Fixed Senior Secured First Lien Notes due October 15, 2019 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	2		'	115
Debt Instrument, Interest Rate, Stated Percentage	9.75%		'	'
EFH Corp. [Member] | Fixed Senior Notes [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	60		'	'
EFH Corp. [Member] | Fixed Senior Notes [Member] | 10.875% Fixed Senior Notes due November 1, 2017 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	33	[2]	'	64	[2]
Debt Instrument, Interest Rate, Stated Percentage	10.88%	[2]	'	'
EFH Corp. [Member] | Fixed Senior Notes [Member] | 10.875% Fixed Senior Notes due November 1, 2017 [Member] | Consolidation, Eliminations [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	0		'	1,685
EFH Corp. [Member] | Fixed Senior Notes [Member] | 11.25 / 12.00% Senior Toggle Notes due November 1, 2017 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	27	[2]	'	60	[2]
EFH Corp. [Member] | Fixed Senior Notes [Member] | 11.25 / 12.00% Senior Toggle Notes due November 1, 2017 [Member] | Consolidation, Eliminations [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	0		'	3,441
EFH Corp. [Member] | Fixed Senior Notes [Member] | 5.55% Fixed Series P Senior Notes due November 15, 2014 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	90	[2]	'	92	[2]
Debt Instrument, Interest Rate, Stated Percentage	5.55%		'	'
EFH Corp. [Member] | Fixed Senior Notes [Member] | 5.55% Fixed Series P Senior Notes due November 15, 2014 [Member] | Consolidation, Eliminations [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	281		'	279
EFH Corp. [Member] | Fixed Senior Notes [Member] | 6.50% Fixed Series Q Senior Notes due November 15, 2024 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	201	[2]	'	230	[2]
Debt Instrument, Interest Rate, Stated Percentage	6.50%		'	'
EFH Corp. [Member] | Fixed Senior Notes [Member] | 6.50% Fixed Series Q Senior Notes due November 15, 2024 [Member] | Consolidation, Eliminations [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	545		'	516
EFH Corp. [Member] | Fixed Senior Notes [Member] | 6.55% Fixed Series R Senior Notes due November 15, 2034 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	291	[2]	'	291	[2]
Debt Instrument, Interest Rate, Stated Percentage	6.55%		'	'
EFH Corp. [Member] | Fixed Senior Notes [Member] | 6.55% Fixed Series R Senior Notes due November 15, 2034 [Member] | Consolidation, Eliminations [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	456		'	456
EFH Corp. [Member] | Building Financing [Member] | 8.82% Building Financing due semiannually through February 11, 2022 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	46	[3]	'	53	[3]
Unamortized fair value premium (discount)	9	[1],[3]	'	11	[1],[3]
Debt Instrument, Interest Rate, Stated Percentage	8.82%		'	'
Energy Future Intermediate Holding CO LLC [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Unamortized premium	303		'	351
Unamortized discount	-149		'	-131
Debt and capital lease obligations	7,773		'	6,504
Energy Future Intermediate Holding CO LLC [Member] | Senior Secured Debt [Member] | 6.875% Senior Secured First Lien Notes due August 15, 2017 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	503		'	503
Debt Instrument, Interest Rate, Stated Percentage	6.88%		'	'
Energy Future Intermediate Holding CO LLC [Member] | Senior Secured Debt [Member] | 10% Fixed Senior Secured First Lien Notes due December 1, 2020 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	3,482		'	2,180
Debt Instrument, Interest Rate, Stated Percentage	10.00%		'	'
Energy Future Intermediate Holding CO LLC [Member] | Senior Secured Debt [Member] | 11% Fixed Senior Secured Second Lien Notes due October 1, 2021 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	406		'	406
Debt Instrument, Interest Rate, Stated Percentage	11.00%		'	'
Energy Future Intermediate Holding CO LLC [Member] | Senior Secured Debt [Member] | 11.75% Fixed Senior Secured Second Lien Notes due March 1, 2022 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	1,750		'	1,750
Debt Instrument, Interest Rate, Stated Percentage	11.75%		'	'
Energy Future Intermediate Holding CO LLC [Member] | Senior Secured Debt [Member] | 9.75% Fixed Senior Secured First Lien Notes due October 15, 2019 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	2		'	141
Debt Instrument, Interest Rate, Stated Percentage	9.75%		'	'
Energy Future Intermediate Holding CO LLC [Member] | Fixed Senior Notes [Member] | 11.25%/ 12.25% Senior Toggle Notes due December 1, 2018 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	1,476		'	1,304
Energy Future Competitive Holdings Company [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Unamortized fair value premium (discount)	-6	[1]	'	-7	[1]
Debt and capital lease obligations	73		'	76
Energy Future Competitive Holdings Company [Member] | Fixed Notes [Member] | 9.58% Fixed Notes due in annual installments through December 4, 2019 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	35	[4]	'	35	[4]
Debt Instrument, Interest Rate, Stated Percentage	9.58%	[4]	'	'
Energy Future Competitive Holdings Company [Member] | Fixed Notes [Member] | 8.254% Fixed Notes due in quarterly installments through December 31, 2021 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	35	[4]	'	39	[4]
Debt Instrument, Interest Rate, Stated Percentage	8.25%	[4]	'	'
Energy Future Competitive Holdings Company [Member] | Junior Subordinated Debentures [Member] | Floating Rate Junior Subordinated Debentures, Series D due January 30, 2037 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	1	[5]	'	1	[5]
Effective interest rate (as a percent)	1.07%	[5]	'	'
Energy Future Competitive Holdings Company [Member] | Junior Subordinated Debentures [Member] | 8.175% Fixed Junior Subordinated Debentures, Series E due January 30, 2037 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	8		'	8
Debt Instrument, Interest Rate, Stated Percentage	8.18%		'	'
Texas Competitive Electric Holdings Company LLC [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Capital lease obligations	56		'	64
Other	3		'	3
Unamortized discount	-110		'	-10
Unamortized fair value premium (discount)	0	[1]	'	-1	[1]
Debt and capital lease obligations	29,699		'	29,498
Texas Competitive Electric Holdings Company LLC [Member] | Pollution control revenue bonds [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Unamortized fair value premium (discount)	-107	[1]	'	-112	[1]
Texas Competitive Electric Holdings Company LLC [Member] | Senior Secured Debt [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	1,571		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Senior Secured Debt [Member] | 11.5% Fixed Senior Secured Notes due October 1, 2020 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	1,750		'	1,750
Debt Instrument, Interest Rate, Stated Percentage	11.50%		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Senior Secured Debt [Member] | 15% Fixed Senior Secured Second Lien Notes due April 1, 2021 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	336		'	336
Debt Instrument, Interest Rate, Stated Percentage	15.00%		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Senior Secured Debt [Member] | 15% Fixed Senior Secured Second Lien Notes due April 1, 2021, Series B [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	1,235		'	1,235
Debt Instrument, Interest Rate, Stated Percentage	15.00%		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed Senior Notes [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	4,874		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed Senior Notes [Member] | 10.25% Fixed Senior Notes due November 1, 2015 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	1,833	[2]	'	1,833	[2]
Debt Instrument, Interest Rate, Stated Percentage	10.25%	[2]	'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed Senior Notes [Member] | 10.25% Fixed Senior Notes due November 1, 2015 [Member] | Consolidation, Eliminations [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	213		'	213
Texas Competitive Electric Holdings Company LLC [Member] | Fixed Senior Notes [Member] | 10.25% Fixed Senior Notes due November 1, 2015, Series B [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	1,292	[2]	'	1,292	[2]
Debt Instrument, Interest Rate, Stated Percentage	10.25%	[2]	'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed Senior Notes [Member] | 10.25% Fixed Senior Notes due November 1, 2015, Series B [Member] | Consolidation, Eliminations [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	150		'	150
Texas Competitive Electric Holdings Company LLC [Member] | Fixed Senior Notes [Member] | 10.50 / 11.25% Senior Toggle Notes due November 1, 2016 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	1,749		'	1,749
Texas Competitive Electric Holdings Company LLC [Member] | Fixed Senior Notes [Member] | 7% Fixed Senior Notes due March 15, 2013 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	0		'	5
Debt Instrument, Interest Rate, Stated Percentage	7.00%		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Term loan Facilities [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	22,616		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Term loan Facilities [Member] | TCEH Term Loan Facilities maturing October 10, 2014 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	3,809	[5],[6]	'	3,809	[5],[6]
Interest rate at period end (as a percent)	3.71%	[5],[6]	'	'
Texas Competitive Electric Holdings Company LLC [Member] | Term loan Facilities [Member] | Term Loan Facilities maturing October 2014 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Derivative, Notional Amount	18,140	[7]	'	'
Texas Competitive Electric Holdings Company LLC [Member] | Term loan Facilities [Member] | Term Loan Facilities maturing from October 2014 through October 2017 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Derivative, Notional Amount	12,600	[8]	'	'
Texas Competitive Electric Holdings Company LLC [Member] | Term loan Facilities [Member] | Term Loan Facilities maturing October 10, 2017 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	15,691	[2],[5],[6]	'	15,351	[2],[5],[6]
Interest rate at period end (as a percent)	4.71%	[2],[5],[6]	'	'
Texas Competitive Electric Holdings Company LLC [Member] | Term loan Facilities [Member] | Term Loan Facilities maturing October 10, 2017 [Member] | Consolidation, Eliminations [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	19		'	19
Texas Competitive Electric Holdings Company LLC [Member] | Letter of Credit [Member] | Letter of Credit Facility maturing October 2014 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	42	[5]	'	42	[5]
Interest rate at period end (as a percent)	3.68%	[5]	'	'
Texas Competitive Electric Holdings Company LLC [Member] | Letter of Credit [Member] | TCEH Letter of Credit Facility maturing October 10, 2017 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	1,020	[5]	'	1,020	[5]
Interest rate at period end (as a percent)	4.68%	[5]	'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | 5.40% Fixed Series 1994A due May 1, 2029 [Member] | Brazos River Authority [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	39		'	39
Debt Instrument, Interest Rate, Stated Percentage	5.40%		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | 7.70% Fixed Series 1999A due April 1, 2033 [Member] | Brazos River Authority [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	111		'	111
Debt Instrument, Interest Rate, Stated Percentage	7.70%		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | 6.75% Fixed Series 1999B due September 1, 2034, remarketing date April 1, 2013 [Member] | Brazos River Authority [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	0	[9]	'	16	[9]
Debt Instrument, Interest Rate, Stated Percentage	6.75%	[9]	'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | 7.70% Fixed Series 1999C due March 1, 2032 [Member] | Brazos River Authority [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	50		'	50
Debt Instrument, Interest Rate, Stated Percentage	7.70%		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | 8.25% Fixed Series 2001A due October 1, 2030 [Member] | Brazos River Authority [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	71		'	71
Debt Instrument, Interest Rate, Stated Percentage	8.25%		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | 8.25% Fixed Series 2001D-1 due May 1, 2033 [Member] | Brazos River Authority [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	171		'	171
Debt Instrument, Interest Rate, Stated Percentage	8.25%		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | Floating Series 2001D-2 due May 1, 2033 [Member] | Brazos River Authority [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	97	[10]	'	97	[10]
Effective interest rate (as a percent)	0.09%	[10]	'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | Floating Taxable Series 2001I due December 1, 2036 [Member] | Brazos River Authority [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	62	[11]	'	62	[11]
Effective interest rate (as a percent)	0.21%	[11]	'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | Floating Series 2002A due May 1, 2037 [Member] | Brazos River Authority [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	45	[10]	'	45	[10]
Effective interest rate (as a percent)	0.09%	[10]	'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | 6.75% Fixed Series 2003A due April 1, 2038, remarketing date April 1, 2013 [Member] | Brazos River Authority [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	0	[9]	'	44	[9]
Debt Instrument, Interest Rate, Stated Percentage	6.75%	[9]	'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | 6.30% Fixed Series 2003B due July 1, 2032 [Member] | Brazos River Authority [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	39		'	39
Debt Instrument, Interest Rate, Stated Percentage	6.30%		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | 6.75% Fixed Series 2003C due October 1, 2038 [Member] | Brazos River Authority [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	52		'	52
Debt Instrument, Interest Rate, Stated Percentage	6.75%		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | 5.40% Fixed Series 2003D due October 1, 2029, remarketing date October 1, 2014 [Member] | Brazos River Authority [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	31	[9]	'	31	[9]
Debt Instrument, Interest Rate, Stated Percentage	5.40%	[9]	'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | 5.00% Fixed Series 2006 due March 1, 2041 [Member] | Brazos River Authority [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	100		'	100
Debt Instrument, Interest Rate, Stated Percentage	5.00%		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | 6.45% Fixed Series 2000A due June 1, 2021 [Member] | Sabine River Authority of Texas [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	51		'	51
Debt Instrument, Interest Rate, Stated Percentage	6.45%		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | 5.20% Fixed Series 2001C due May 1, 2028 [Member] | Sabine River Authority of Texas [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	70		'	70
Debt Instrument, Interest Rate, Stated Percentage	5.20%		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | 5.80% Fixed Series 2003A due July 1, 2022 [Member] | Sabine River Authority of Texas [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	12		'	12
Debt Instrument, Interest Rate, Stated Percentage	5.80%		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | 6.15% Fixed Series 2003B due August 1, 2022 [Member] | Sabine River Authority of Texas [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	45		'	45
Debt Instrument, Interest Rate, Stated Percentage	6.15%		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | 6.25% Fixed Series 200A due May 1, 2028 [Member] | Trinity River Authority of Texas [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	14		'	14
Debt Instrument, Interest Rate, Stated Percentage	6.25%		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed Secured Facility Bonds [Member] | Fixed 7.48% Secured Facility Bonds With Amortizing Payments Through January 2017 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	36		45	0
Debt Instrument, Interest Rate, Stated Percentage	7.48%		'	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed Secured Facility Bonds [Member] | 7.46% Fixed Secured Facility Bonds with amortizing payments through January 2015 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Long-term debt, gross	$4		'	$12
Debt Instrument, Interest Rate, Stated Percentage	7.46%		'	'
Minimum [Member] | EFH Corp. [Member] | Fixed Senior Notes [Member] | 11.25 / 12.00% Senior Toggle Notes due November 1, 2017 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Effective interest rate (as a percent)	11.25%	[2]	'	'
Minimum [Member] | Energy Future Intermediate Holding CO LLC [Member] | Fixed Senior Notes [Member] | 11.25%/ 12.25% Senior Toggle Notes due December 1, 2018 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Effective interest rate (as a percent)	11.25%	[2]	'	'
Minimum [Member] | Texas Competitive Electric Holdings Company LLC [Member] | Fixed Senior Notes [Member] | 10.50 / 11.25% Senior Toggle Notes due November 1, 2016 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Effective interest rate (as a percent)	10.50%		'	'
Maximum [Member] | EFH Corp. [Member] | Fixed Senior Notes [Member] | 11.25 / 12.00% Senior Toggle Notes due November 1, 2017 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Effective interest rate (as a percent)	12.00%	[2]	'	'
Maximum [Member] | Energy Future Intermediate Holding CO LLC [Member] | Fixed Senior Notes [Member] | 11.25%/ 12.25% Senior Toggle Notes due December 1, 2018 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Effective interest rate (as a percent)	12.25%	[2]	'	'
Maximum [Member] | Texas Competitive Electric Holdings Company LLC [Member] | Fixed Senior Notes [Member] | 10.50 / 11.25% Senior Toggle Notes due November 1, 2016 [Member]	'		'	'
Debt Instrument [Line Items]	'		'	'
Effective interest rate (as a percent)	11.25%		'	'
[1]	Amount represents unamortized fair value adjustments recorded under purchase accounting.
[2]	Excludes the following debt held by EFIH or EFH Corp. (parent entity) and eliminated in consolidation: September 30, 2013 December 31, 2012EFH Corp. 10.875% Fixed Senior Notes due November 1, 2017$— $1,685EFH Corp. 11.25 / 12.00% Senior Toggle Notes due November 1, 2017— 3,441EFH Corp. 5.55% Fixed Series P Senior Notes due November 15, 2014281 279EFH Corp. 6.50% Fixed Series Q Senior Notes due November 15, 2024545 516EFH Corp. 6.55% Fixed Series R Senior Notes due November 15, 2034456 456TCEH 4.709% Term Loan Facilities maturing October 10, 201719 19TCEH 10.25% Fixed Senior Notes due November 1, 2015213 213TCEH 10.25% Fixed Senior Notes due November 1, 2015, Series B150 150Total$1,664 $6,759
[3]	This financing is the obligation of a subsidiary of EFH Corp. and will be serviced with cash drawn by the beneficiary of a letter of credit that was previously issued to secure the obligation.
[4]	EFCH's obligations with respect to these financings are guaranteed by EFH Corp. and secured on a first-priority basis by, among other things, an undivided interest in the Comanche Peak nuclear generation facility.
[5]	Interest rates in effect at September 30, 2013.
[6]	Interest rate swapped to fixed on $18.140 billion principal amount of maturities through October 2014 and up to an aggregate $12.6 billion principal amount from October 2014 through October 2017.
[7]	Swaps related to an aggregate $1.6 billion principal amount of debt expired in 2013. Per the terms of the transactions, the notional amount of swaps entered into in 2011 grew by $1.280 billion in 2013, substantially offsetting the expired swaps.
[8]	These swaps are effective from October 2014 through October 2017. The $12.6 billion notional amount of swaps includes $3 billion that expires in October 2015 with the remainder expiring in October 2017.
[9]	These series are in the multiannual interest rate mode and are subject to mandatory tender prior to maturity on the mandatory remarketing date. On such date, the interest rate and interest rate period will be reset for the bonds.
[10]	Interest rates in effect at September 30, 2013. These series are in a daily interest rate mode and are classified as long-term as they are supported by long-term irrevocable letters of credit.
[11]	Interest rate in effect at September 30, 2013. This series is in a weekly interest rate mode and is classified as long-term as it is supported by long-term irrevocable letters of credit.

ShortTerm_Borrowings_And_LongT5

Short-Term Borrowings And Long-Term Debt (2013 Debt-Related Activity) (Details) (USD $)

1 Months Ended

9 Months Ended

3 Months Ended

1 Months Ended

1 Months Ended

9 Months Ended

1 Months Ended

1 Months Ended

1 Months Ended

3 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

3 Months Ended

1 Months Ended

3 Months Ended

In Millions, unless otherwise specified

Jan. 31, 2013

Sep. 30, 2013

Sep. 30, 2012

Mar. 31, 2013

Jan. 31, 2013

Sep. 30, 2013

Jan. 31, 2013

Apr. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Jan. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Dec. 31, 2012

Jan. 31, 2013

Jan. 31, 2013

Sep. 30, 2013

Dec. 31, 2012

Jan. 31, 2013

Sep. 30, 2013

Dec. 31, 2012

Jan. 31, 2013

Sep. 30, 2013

Dec. 31, 2012

Mar. 31, 2013

Sep. 30, 2013

Dec. 31, 2012

Mar. 31, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Mar. 31, 2013

Jan. 31, 2013

Mar. 31, 2013

Jan. 31, 2013

Jan. 31, 2013

Jan. 31, 2013

Sep. 30, 2013

Dec. 31, 2012

Mar. 31, 2013

Sep. 30, 2013

Senior Notes [Member]

EFH Corp. [Member]

EFH Corp. [Member]

EFH Corp. [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

11.5% Fixed Senior Secured Notes due October 1, 2020 [Member]

11.5% Fixed Senior Secured Notes due October 1, 2020 [Member]

6.875% Senior Secured First Lien Notes due August 15, 2017 [Member]

6.875% Senior Secured First Lien Notes due August 15, 2017 [Member]

11.25%/12.25% Senior Toggle notes due 2018 [Member]

Fixed 7.48% Secured Facility Bonds With Amortizing Payments Through January 2017 [Member]

Fixed 7.48% Secured Facility Bonds With Amortizing Payments Through January 2017 [Member]

Fixed 7.48% Secured Facility Bonds With Amortizing Payments Through January 2017 [Member]

10.875% Senior notes due 2017 [Member]

11.25 / 12.00% Senior Toggle Notes due November 1, 2017 [Member]

11.25 / 12.00% Senior Toggle Notes due November 1, 2017 [Member]

11.25 / 12.00% Senior Toggle Notes due November 1, 2017 [Member]

5.55% Fixed Series P Senior Notes due November 15, 2014 [Member]

5.55% Fixed Series P Senior Notes due November 15, 2014 [Member]

5.55% Fixed Series P Senior Notes due November 15, 2014 [Member]

6.50% Fixed Series Q Senior Notes due November 15, 2024 [Member]

6.50% Fixed Series Q Senior Notes due November 15, 2024 [Member]

6.50% Fixed Series Q Senior Notes due November 15, 2024 [Member]

10.875% Fixed Senior Notes due November 1, 2017 [Member]

10.875% Fixed Senior Notes due November 1, 2017 [Member]

10.875% Fixed Senior Notes due November 1, 2017 [Member]

Toggle Notes [Member]

11.75% Fixed Senior Secured Second Lien Notes due March 1, 2022 [Member]

11.75% Fixed Senior Secured Second Lien Notes due March 1, 2022 [Member]

Pollution control revenue bonds [Member]

10% Senior Secured notes due 2020 [Member]

10% Senior Secured notes due 2020 [Member]

9.75% Secured notes due 2019 [Member]

9.75% Secured notes due 2019 [Member]

9.75% Secured notes due 2019 [Member]

10% Fixed Senior Secured First Lien Notes due December 1, 2020 [Member]

10% Fixed Senior Secured First Lien Notes due December 1, 2020 [Member]

10% Fixed Senior Secured First Lien Notes due December 1, 2020 [Member]

Returned debt as dividend [Member]

Oncor Holdings [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Secured Debt [Member]

Senior Notes [Member]

Fixed Secured Facility Bonds [Member]

Line of Credit [Member]

Senior Secured Debt [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

EFH Corp. [Member]

EFH Corp. [Member]

EFH Corp. [Member]

EFH Corp. [Member]

EFH Corp. [Member]

EFH Corp. [Member]

EFH Corp. [Member]

EFH Corp. [Member]

EFH Corp. [Member]

EFH Corp. [Member]

EFH Corp. [Member]

EFH Corp. [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Senior Notes [Member]

Energy Future Intermediate Holding CO LLC [Member]

Senior Notes [Member]

Energy Future Intermediate Holding CO LLC [Member]

EFH Corp. [Member]

Senior Secured Debt [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

6.875% Senior Secured First Lien Notes due August 15, 2017 [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Notes [Member]

Fixed Secured Facility Bonds [Member]

Fixed Secured Facility Bonds [Member]

Fixed Secured Facility Bonds [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Notes [Member]

Energy Future Intermediate Holding CO LLC [Member]

Senior Secured Debt [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long Term Debt And Capital Leases Issued, Principal Amount

'

$1,731

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Issuance Fee Paid By Issuance Of Debt

340

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt, gross

'

'

'

'

'

60

'

'

4,874

'

22,616

1,571

1,750

1,750

503

503

89

36

45

0

'

'

27

[1]

60

[1]

'

90

[1]

92

[1]

'

201

[1]

230

[1]

'

33

[1]

64

[1]

'

1,750

1,750

'

'

1,302

'

'

'

'

3,482

2,180

'

'

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

'

'

'

'

'

'

'

'

'

11.50%

'

6.88%

'

'

7.48%

'

'

'

'

'

'

'

5.55%

'

'

6.50%

'

'

10.88%

[1]

'

'

11.75%

'

'

'

'

'

'

'

'

10.00%

'

'

'

Principal Amount Of Affiliate Debt Acquired In Exchange Transaction

'

'

'

'

95

'

1,310

'

'

'

'

'

'

'

'

'

'

'

'

'

31

33

'

'

2

'

'

29

'

'

'

'

'

'

'

'

'

'

'

'

139

113

1,058

'

'

'

'

Pledged ownership membership interest as a percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

Repurchases of long-term debt

'

94

31

'

'

'

'

'

'

17

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

60

'

'

'

'

'

'

'

'

'

'

Repayments of principal at scheduled maturity dates

'

86

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repayments of contractual payments under capitalized lease obligations

'

8

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of combustion turbine trust interest (Note 5)

'

-40

0

'

'

'

'

40

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Combustion Turbine Asset Acquired, Fair Value

'

'

'

'

'

'

'

83

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred Lease Liability and and Unamortized Lease Valuation Reserve

'

'

'

'

'

'

'

18

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Principal Amounts Cancelled, Payment as Dividend

'

'

'

1,235

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,715

'

'

3,474

'

'

'

1,058

'

113

'

'

'

'

'

6,360

'

Debt Instrument Principal Amount Of Subsidiaries Still Held By Affiliate

'

1,361

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred Tax Assets, Deferred Income Gain Relating to Membership Interests Transactions

'

21

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Taxable Cancellation of Debt Income

'

$11

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

Excludes the following debt held by EFIH or EFH Corp. (parent entity) and eliminated in consolidation: September 30, 2013 December 31, 2012EFH Corp. 10.875% Fixed Senior Notes due November 1, 2017$— $1,685EFH Corp. 11.25 / 12.00% Senior Toggle Notes due November 1, 2017— 3,441EFH Corp. 5.55% Fixed Series P Senior Notes due November 15, 2014281 279EFH Corp. 6.50% Fixed Series Q Senior Notes due November 15, 2024545 516EFH Corp. 6.55% Fixed Series R Senior Notes due November 15, 2034456 456TCEH 4.709% Term Loan Facilities maturing October 10, 201719 19TCEH 10.25% Fixed Senior Notes due November 1, 2015213 213TCEH 10.25% Fixed Senior Notes due November 1, 2015, Series B150 150Total$1,664 $6,759

ShortTerm_Borrowings_And_LongT6

Short-Term Borrowings And Long-Term Debt (Information Regarding Other Significant Outstanding Debt) (Details) (USD $)

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Jan. 31, 2013

Jan. 31, 2013

Sep. 30, 2013

In Millions, unless otherwise specified

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Energy Future Competitive Holdings Company [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Letter of Credit [Member]

Letter of Credit [Member]

Letter of Credit [Member]

Letter of Credit [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Until June 1, 2016 [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

EFH Corp. [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Senior Notes [Member]

6.875% Senior Secured First Lien Notes due August 15, 2017 [Member]

6.875% Senior Secured First Lien Notes due August 15, 2017 [Member]

10% Fixed Senior Secured First Lien Notes due December 1, 2020 [Member]

10% Fixed Senior Secured First Lien Notes due December 1, 2020 [Member]

11% Fixed Senior Secured Second Lien Notes due October 1, 2021 [Member]

11% Fixed Senior Secured Second Lien Notes due October 1, 2021 [Member]

11.75% Fixed Senior Secured Second Lien Notes due March 1, 2022 [Member]

11.75% Fixed Senior Secured Second Lien Notes due March 1, 2022 [Member]

11.5% Fixed Senior Secured Notes due October 1, 2020 [Member]

11.5% Fixed Senior Secured Notes due October 1, 2020 [Member]

11.25%/ 12.25% Senior Toggle Notes due December 1, 2018 [Member]

11.25%/ 12.25% Senior Toggle Notes due December 1, 2018 [Member]

Consolidation, Eliminations [Member]

10.25% Fixed Senior Notes due November 1, 2015 [Member]

10.25% Fixed Senior Notes due November 1, 2015 [Member]

10.25% Fixed Senior Notes due November 1, 2015 [Member]

10.25% Fixed Senior Notes due November 1, 2015 [Member]

10.50 / 11.25% Senior Toggle Notes due November 1, 2016 [Member]

10.50 / 11.25% Senior Toggle Notes due November 1, 2016 [Member]

TCEH Term Loan Facilities maturing October 10, 2014 [Member]

TCEH Term Loan Facilities maturing October 10, 2014 [Member]

Term Loan Facilities maturing October 10, 2017 [Member]

Term Loan Facilities maturing October 10, 2017 [Member]

Term Loan Facilities maturing October 10, 2017 [Member]

Term Loan Facilities maturing October 10, 2017 [Member]

Letter of Credit Facility maturing October 10, 2014 [Member]

Letter of Credit Facility maturing October 10, 2014 [Member]

TCEH Letter of Credit Facility maturing October 10, 2017 [Member]

TCEH Letter of Credit Facility maturing October 10, 2017 [Member]

Revolving Credit Facility maturing October 2013 Extended to October 2016 [Member]

Energy Future Intermediate Holding CO LLC [Member]

Financial guarantee [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

Consolidation, Eliminations [Member]

11.25%/ 12.25% Senior Toggle Notes due December 1, 2018 [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Registration Default, if not filed and declared effective after original issue date, variable interest rate increase for first ninety days

'

'

'

'

0.25%

'

'

'

'

'

0.25%

'

'

'

'

0.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument registration default if not filed and declared effective after original issue date, incremental variable interest rate increase after first ninety day period

'

'

'

'

0.25%

'

'

'

'

'

0.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument Registration Default If Not Fled And Declared Effective After Original Issue Date, Total Interest Rate Percentage For First Ninety Days

'

'

'

'

7.13%

'

'

'

'

'

12.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument Registration Default If Not Registered Within One Year Of Original Issue Date, Total Interest Rate Percentage After First Ninety Days

'

'

'

'

7.38%

'

'

'

'

'

12.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Registration Default, if not filed and declared effective after original issue date, total variable interest rate increase after first ninety day period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Springing maturity provision, remaining outstanding days prior to maturity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'91 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity

'

'

$3,116

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$2,054

[1]

$645

[1]

'

Debt Instrument, Springing maturity provision pursuant if in the event that aggregate principal amount to the extent held at the determination date, Exceeds Minimum

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

500

'

'

'

150

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt, gross

$1,664

$6,759

'

'

$503

$503

$3,482

$2,180

$406

$406

$1,750

$1,750

$1,571

$1,750

$1,750

$1,476

$1,304

$60

$4,874

$363

$1,833

[2]

$1,833

[2]

$213

$213

$1,749

$1,749

$22,616

$3,809

[3],[4]

$3,809

[3],[4]

$15,691

[2],[3],[4]

$15,351

[2],[3],[4]

$19

$19

$42

[3]

$42

[3]

$1,020

[3]

$1,020

[3]

'

'

'

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

'

6.88%

'

10.00%

'

11.00%

'

11.75%

'

'

11.50%

'

'

'

'

'

'

10.25%

[2]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Basis Spread on LIBOR Rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3.50%

'

4.50%

'

'

'

3.50%

'

4.50%

'

'

'

'

Ownership interest (as a percent)

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total debt to Adjusted EBITDA ratio at Determination Date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Springing maturity provision, remaining outstanding days prior to maturity automatic extention if Adjusted EBITDA ratio at determination date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'90 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Registration Default, if not filed and declared effective after original issue date, days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'365 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Registration Default, if not filed and declared effective after original issue date, first quarter annual interest rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'90 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Options to Pay Interest, Percentage Allowed in Cash

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

Debt Instrument, Options to Pay Interest, Percentage Allowed in PIK Interest

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

[1]

Facility used for borrowings for general corporate purposes. Borrowings are classified as short-term borrowings. At September 30, 2013, borrowings under the facility bear interest at LIBOR plus 4.50%, and a commitment fee is payable quarterly in arrears at a rate per annum equal to 1.00% of the average daily unused portion of the facility. In January 2013, commitments previously maturing in 2013 were extended to 2016 as discussed below.

[2]

Excludes the following debt held by EFIH or EFH Corp. (parent entity) and eliminated in consolidation: September 30, 2013 December 31, 2012EFH Corp. 10.875% Fixed Senior Notes due November 1, 2017$— $1,685EFH Corp. 11.25 / 12.00% Senior Toggle Notes due November 1, 2017— 3,441EFH Corp. 5.55% Fixed Series P Senior Notes due November 15, 2014281 279EFH Corp. 6.50% Fixed Series Q Senior Notes due November 15, 2024545 516EFH Corp. 6.55% Fixed Series R Senior Notes due November 15, 2034456 456TCEH 4.709% Term Loan Facilities maturing October 10, 201719 19TCEH 10.25% Fixed Senior Notes due November 1, 2015213 213TCEH 10.25% Fixed Senior Notes due November 1, 2015, Series B150 150Total$1,664 $6,759

[3]

Interest rates in effect at September 30, 2013.

[4]

Interest rate swapped to fixed on $18.140 billion principal amount of maturities through October 2014 and up to an aggregate $12.6 billion principal amount from October 2014 through October 2017.

ShortTerm_Borrowings_And_LongT7

Short-Term Borrowings And Long-Term Debt (Fair Value of Long-Term Debt) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Short-term borrowings (includes $172 and $82 related to a VIE (Notes 2 and 5))	$2,226	$2,136
Carrying Amount [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Long-term debt (including current maturities)	38,068	37,854
Level 2 [Member] | Fair Value [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Long-term debt (including current maturities)	23,625	25,890
Texas Competitive Electric Holdings Company LLC [Member] | Level 2 [Member] | Fair Value [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Lines of Credit, Fair Value Disclosure	1,371	1,500
Revolving Credit Facility [Member] | Texas Competitive Electric Holdings Company LLC [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Short-term borrowings (includes $172 and $82 related to a VIE (Notes 2 and 5))	$2,054	$2,054

ShortTerm_Borrowings_And_LongT8

Short-Term Borrowings And Long-Term Debt (TCEH Interest Rate Swap Transactions) (Details) (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012		Dec. 31, 2012
Derivative [Line Items]	'		'		'		'		'
Unrealized net gain (loss)	$414	[1]	($21)	[1]	$903	[1]	($12)	[1]	'
Interest Rate Swap [Member]	'		'		'		'		'
Derivative [Line Items]	'		'		'		'		'
Derivative, Notional Amount	32,440	[2]	'		32,440	[2]	'		32,760	[2]
Interest Rate Swap [Member] | Texas Competitive Electric Holdings Company LLC [Member]	'		'		'		'		'
Derivative [Line Items]	'		'		'		'		'
Accumulated Unrealized Gain (Loss) On Interest Rate Derivative Instruments Not Designated As Hedging Instruments Net Of Nonperformance Risk Adjustments	1,167		'		1,167		'		'
Realized net loss	-160		-168		-466		-505		'
Unrealized net gain (loss)	413		-20		899		-16		'
Total	253		-188		433		-521		'
Accumulated Unrealized Gain (Loss) On Interest Rate Derivative Instruments Not Designated As Hedging Instruments	1,518		'		1,518		'		2,065
Accumulated unrealized gain (loss) on interest rate derivative instruments not designated as hedging instruments other comprehensive income, pre-tax	57		'		57		'		65
Interest Rate Swap [Member] | Texas Competitive Electric Holdings Company LLC [Member] | October 2015 through October 2017 [Member]	'		'		'		'		'
Derivative [Line Items]	'		'		'		'		'
Derivative, Notional Amount	12,600	[3]	'		12,600	[3]	'		'
Interest Rate Swap [Member] | Texas Competitive Electric Holdings Company LLC [Member] | Expires in October 2015 and the remainder in October 2017 [Member]	'		'		'		'		'
Derivative [Line Items]	'		'		'		'		'
Derivative, Notional Amount	3,000		'		3,000		'		'
Interest Rate Swap [Member] | Texas Competitive Electric Holdings Company LLC [Member] | Minimum [Member] | October 2012 through October 2014 [Member]	'		'		'		'		'
Derivative [Line Items]	'		'		'		'		'
Swap interest rate (as a percent)	5.50%	[4]	'		5.50%	[4]	'		'
Interest Rate Swap [Member] | Texas Competitive Electric Holdings Company LLC [Member] | Minimum [Member] | October 2015 through October 2017 [Member]	'		'		'		'		'
Derivative [Line Items]	'		'		'		'		'
Swap interest rate (as a percent)	6.80%	[3]	'		6.80%	[3]	'		'
Interest Rate Swap [Member] | Texas Competitive Electric Holdings Company LLC [Member] | Maximum [Member] | October 2012 through October 2014 [Member]	'		'		'		'		'
Derivative [Line Items]	'		'		'		'		'
Swap interest rate (as a percent)	9.30%	[4]	'		9.30%	[4]	'		'
Interest Rate Swap [Member] | Texas Competitive Electric Holdings Company LLC [Member] | Maximum [Member] | October 2015 through October 2017 [Member]	'		'		'		'		'
Derivative [Line Items]	'		'		'		'		'
Swap interest rate (as a percent)	9.00%	[3]	'		9.00%	[3]	'		'
Basis swap [Member]	'		'		'		'		'
Derivative [Line Items]	'		'		'		'		'
Derivative, Notional Amount	11,967		'		11,967		'		11,967
Basis swap [Member] | Texas Competitive Electric Holdings Company LLC [Member] | October 2012 through October 2014 [Member]	'		'		'		'		'
Derivative [Line Items]	'		'		'		'		'
Derivative, Notional Amount	11,967	[4]	'		11,967	[4]	'		'
Debt obligation expiring in 2012 [Member] | Interest Rate Swap [Member] | Texas Competitive Electric Holdings Company LLC [Member]	'		'		'		'		'
Derivative [Line Items]	'		'		'		'		'
Long-term debt, gross	1,600		'		1,600		'		'
Increase in notional amount of swaps during period [Member] | Interest Rate Swap [Member] | Texas Competitive Electric Holdings Company LLC [Member]	'		'		'		'		'
Derivative [Line Items]	'		'		'		'		'
Notional Amount of Interest Rate Derivatives, Gross	'		'		1,280		'		'
Line of Credit [Member] | Texas Competitive Electric Holdings Company LLC [Member]	'		'		'		'		'
Derivative [Line Items]	'		'		'		'		'
Long-term debt, gross	22,616		'		22,616		'		'
Line of Credit [Member] | Term Loan Facilities maturing October 2014 [Member] | Texas Competitive Electric Holdings Company LLC [Member]	'		'		'		'		'
Derivative [Line Items]	'		'		'		'		'
Derivative, Notional Amount	$18,140	[4]	'		$18,140	[4]	'		'
[1]	Three months ended September 30, 2013 and 2012 amounts include net gains totaling $413 million and net losses totaling $20 million, respectively, related to TCEH swaps (see Note 5) and net gains totaling $1 million and net losses totaling $1 million, respectively, related to EFH Corp. swaps substantially closed through offsetting positions. Nine months ended September 30, 2013 and 2012 amounts include net gains totaling $899 million and net losses totaling $16 million, respectively, related to TCEH swaps and net gains totaling $4 million for both periods related to EFH Corp. swaps substantially closed through offsetting positions.
[2]	Includes notional amount of interest rate swaps with maturity dates through October 2014 as well as notional amount of swaps effective from October 2014 with maturity dates through October 2017 (see Note 5).
[3]	These swaps are effective from October 2014 through October 2017. The $12.6 billion notional amount of swaps includes $3 billion that expires in October 2015 with the remainder expiring in October 2017.
[4]	Swaps related to an aggregate $1.6 billion principal amount of debt expired in 2013. Per the terms of the transactions, the notional amount of swaps entered into in 2011 grew by $1.280 billion in 2013, substantially offsetting the expired swaps.

Commitments_And_Contingencies_

Commitments And Contingencies (Narrative) (Details) (USD $)	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013	Feb. 29, 2012
In Millions, unless otherwise specified	Texas Competitive Electric Holdings Company LLC [Member]	Texas Competitive Electric Holdings Company LLC [Member]	Financial Standby Letter of Credit [Member]	Financial Standby Letter of Credit [Member]	Financial Standby Letter of Credit [Member]	Financial Standby Letter of Credit [Member]	Financial Standby Letter of Credit [Member]	TXU Gas Company [Member]	Liability related to assets retained by TXU Gas Company, including certain inactive gas plant sites not acquired by Atmos [Member]	Contingent liabilities associated with preclosing tax and employee related matters [Member]	CSAPR [Member]
		Debt obligation expiring in 2014 [Member]	Texas Competitive Electric Holdings Company LLC [Member]	Texas Competitive Electric Holdings Company LLC [Member]	Texas Competitive Electric Holdings Company LLC [Member]	Texas Competitive Electric Holdings Company LLC [Member]	Texas Competitive Electric Holdings Company LLC [Member]	Indemnification Agreement [Member]	TXU Gas Company [Member]	TXU Gas Company [Member]
				Support risk management and trading margin requirements, including over-the-counter hedging transactions and collateral postings with ERCOT [Member]	Support floating rate pollution control revenue bond debt [Member]	Support Retail Electric Provider's financial requirements with the PUCT [Member]	Miscellaneous credit support requirements [Member]		Indemnification Agreement [Member]	Indemnification Agreement [Member]
Commitments and Contingencies [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Maximum exposure, undiscounted	'	'	'	'	'	'	'	$1,900	$500	$1,400	'
Letters of Credit	0	'	776	353	208	65	150	'	'	'	'
Long-term debt, gross	'	$204	'	'	'	'	'	'	'	'	'
Emissions budget generation assets lower sulfur dioxide requirements (as a percent)	'	'	'	'	'	'	'	'	'	'	6.00%
Emissions budget generation assets higher annual nitrogen oxides requirements (as a percent)	'	'	'	'	'	'	'	'	'	'	3.00%
Emissions budget generation assets higher seasonal nitrogen oxides requirements (as a percent)	'	'	'	'	'	'	'	'	'	'	2.00%

Equity_Narrative_Details

Equity (Narrative) (Details)	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2012	Dec. 31, 2011
Equity	'	'	'	'
Consolidated leverage ratio related to dividend restrictions covenant threshold (as a ratio)	7	'	'	'
Consolidated leverage ratio related to dividend restrictions covenant, actual (as a ratio)	12.3	'	'	'
Common Stock, Shares Authorized	2,000,000,000	'	2,000,000,000	'
Common stock, shares outstanding	1,669,861,383	1,680,539,245	1,680,539,245	1,679,539,245
Energy Future Intermediate Holding CO LLC [Member]	'	'	'	'
Equity	'	'	'	'
Consolidated leverage ratio related to dividend restrictions covenant threshold (as a ratio)	6	'	'	'
Consolidated leverage ratio related to dividend restrictions covenant, actual (as a ratio)	7.7	'	'	'
Texas Competitive Electric Holdings Company LLC [Member]	'	'	'	'
Equity	'	'	'	'
Consolidated total debt to Adjusted EBITDA ratio related to dividend restrictions, threshold (as a ratio)	6.5	'	'	'
Consolidated total debt to Adjusted EBITDA ratio related to dividend restrictions, actual (as a ratio)	10.6	'	'	'

Equity_Changes_to_Equity_Detai

Equity (Changes to Equity) (Details) (USD $)

3 Months Ended

9 Months Ended

9 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2012

Dec. 31, 2011

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Common Stock [Member]

Common Stock [Member]

Common Stock [Member]

Common Stock [Member]

Additional Paid-in Capital [Member]

Additional Paid-in Capital [Member]

Retained Earnings [Member]

Retained Earnings [Member]

Accumulated Other Comprehensive Income (Loss) [Member]

Accumulated Other Comprehensive Income (Loss) [Member]

Noncontrolling Interest [Member]

Noncontrolling Interest [Member]

Increase (Decrease) in Stockholders' Equity [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Beginning balance

'

'

($10,923)

($7,757)

$2

[1]

$2

[1]

$2

[2]

$2

[2]

$7,959

$7,947

($18,939)

($15,579)

($47)

($222)

$102

$95

Net loss

5

-407

-635

-1,408

'

'

'

'

'

'

-635

-1,408

'

'

'

'

Effects of stock-based incentive compensation plans

'

'

5

11

'

'

'

'

5

11

'

'

'

'

'

'

Repurchases of stock

'

'

-5

'

'

'

'

'

-5

'

'

'

'

'

'

'

Change in unrecognized losses related to pension and OPEB plans (Note 10)

-1

-33

-4

-25

'

'

'

'

'

'

'

'

-4

-25

'

'

Net effects of cash flow hedges

1

1

5

5

'

'

'

'

'

'

'

'

5

5

'

'

Net effects related to Oncor

1

1

1

2

'

'

'

'

'

'

'

'

1

2

'

'

Noncontrolling Interest, Increase from Subsidiary Equity Issuance

'

'

3

6

'

'

'

'

'

'

'

'

'

'

3

6

Other

'

'

2

'

'

'

'

'

2

'

'

'

'

'

'

'

Ending balance

($11,551)

($9,166)

($11,551)

($9,166)

$2

[1]

$2

[1]

$2

[2]

$2

[2]

$7,961

$7,958

($19,574)

($16,987)

($45)

($240)

$105

$101

[1]

Authorized shares totaled 2,000,000,000 at September 30, 2013. Outstanding shares totaled 1,669,861,383 and 1,680,539,245 at September 30, 2013 and December 31, 2012, respectively.

[2]

Authorized shares totaled 2,000,000,000 at September 30, 2012. Outstanding shares totaled 1,680,539,245 and 1,679,539,245 at September 30, 2012 and December 31, 2011, respectively.

Equity_Accumulated_Other_Compr

Equity (Accumulated Other Comprehensive Income (Loss)) (Details) (USD $)	3 Months Ended		9 Months Ended						9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Dec. 31, 2012	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2013
					Dedesignated Cash Flow Hedges – Interest Rate Swaps [Member]	Dedesignated Cash Flow Hedges – Interest Rate Swaps [Member]	Pension and Other Postretirement Employee Benefit Liabilities Adjustments [Member]	Pension and Other Postretirement Employee Benefit Liabilities Adjustments [Member]	Reclassification out of Accumulated Other Comprehensive Income [Member]	Reclassification out of Accumulated Other Comprehensive Income [Member]	Reclassification out of Accumulated Other Comprehensive Income [Member]
										Dedesignated Cash Flow Hedges – Interest Rate Swaps [Member]	Pension and Other Postretirement Employee Benefit Liabilities Adjustments [Member]
Accumulated Other Comprehensive Income (Loss) [Roll Forward]	'	'	'	'	'	'	'	'	'	'	'
Beginning balance	'	'	($47)	'	($57)	($64)	$12	$17	'	'	'
Amounts reclassified from accumulated other comprehensive income (loss) and reported in:	'	'	'	'	'	'	'	'	'	'	'
Operating costs	'	'	'	'	'	'	'	'	-4	0	-4
Depreciation and amortization	-335	-335	-1,030	-1,015	'	'	'	'	2	2	0
Selling, general and administrative expenses	-202	-177	-540	-491	'	'	'	'	-2	0	-2
Interest expense and related charges (Note 13)	-533	-944	-1,915	-2,746	'	'	'	'	6	6	0
Equity in earnings of unconsolidated subsidiaries (net of tax) (Note 2)	114	109	255	249	'	'	'	'	1	2	-1
Income tax benefit (expense)	100	296	925	879	'	'	'	'	-1	-3	2
Total other comprehensive income (loss)	1	-31	2	-18	'	'	'	'	2	7	-5
Ending balance	($45)	'	($45)	'	($57)	($64)	$12	$17	'	'	'

Fair_Value_Measurements_Schedu

Fair Value Measurements (Schedule of Assets and Liabilities Measured at Fair Value on a Recurring Basis) (Details) (USD $)	Sep. 30, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Assets:	'		'
Nuclear decommissioning trust	$737		$654
Equity securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	471	[1]	393	[1]
Debt securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	266	[2]	261	[2]
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]	'		'
Assets:	'		'
Total assets	439		429
Liabilities:	'		'
Total liabilities	129		208
Fair Value, Measurements, Recurring [Member] | Level 1 [Member] | Equity securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	299	[3]	249	[3]
Fair Value, Measurements, Recurring [Member] | Level 1 [Member] | Debt securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	'	[3]	'	[3]
Fair Value, Measurements, Recurring [Member] | Level 1 [Member] | Commodity contracts [Member]	'		'
Assets:	'		'
Derivative Assets	140		180
Liabilities:	'		'
Derivative Liabilities	129		208
Fair Value, Measurements, Recurring [Member] | Level 1 [Member] | Interest Rate Swap [Member]	'		'
Assets:	'		'
Derivative Assets	'		'
Liabilities:	'		'
Derivative Liabilities	'		'
Fair Value, Measurements, Recurring [Member] | Level 2 [Member]	'		'
Assets:	'		'
Total assets	1,463		2,323
Liabilities:	'		'
Total liabilities	123		2,338
Fair Value, Measurements, Recurring [Member] | Level 2 [Member] | Equity securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	172	[3]	144	[3]
Fair Value, Measurements, Recurring [Member] | Level 2 [Member] | Debt securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	266	[3]	261	[3]
Fair Value, Measurements, Recurring [Member] | Level 2 [Member] | Commodity contracts [Member]	'		'
Assets:	'		'
Derivative Assets	941		1,784
Liabilities:	'		'
Derivative Liabilities	26		121
Fair Value, Measurements, Recurring [Member] | Level 2 [Member] | Interest Rate Swap [Member]	'		'
Assets:	'		'
Derivative Assets	84		134
Liabilities:	'		'
Derivative Liabilities	97		2,217
Fair Value, Measurements, Recurring [Member] | Level 3 [Member]	'		'
Assets:	'		'
Total assets	48	[4]	83	[4]
Liabilities:	'		'
Total liabilities	1,219	[4]	54	[4]
Fair Value, Measurements, Recurring [Member] | Level 3 [Member] | Equity securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	'	[3],[4]	'	[3],[4]
Fair Value, Measurements, Recurring [Member] | Level 3 [Member] | Debt securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	'	[3],[4]	'	[3],[4]
Fair Value, Measurements, Recurring [Member] | Level 3 [Member] | Commodity contracts [Member]	'		'
Assets:	'		'
Derivative Assets	48	[4]	83	[4]
Liabilities:	'		'
Derivative Liabilities	52	[4]	54	[4]
Fair Value, Measurements, Recurring [Member] | Level 3 [Member] | Interest Rate Swap [Member]	'		'
Assets:	'		'
Derivative Assets	'	[4]	'	[4]
Liabilities:	'		'
Derivative Liabilities	1,167	[4]	'	[4]
Fair Value, Measurements, Recurring [Member] | Fair value, inputs, Reclassification [Member]	'		'
Assets:	'		'
Total assets	2	[5]	'
Liabilities:	'		'
Total liabilities	2	[5]	'
Fair Value, Measurements, Recurring [Member] | Fair value, inputs, Reclassification [Member] | Equity securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	'	[3],[5]	'
Fair Value, Measurements, Recurring [Member] | Fair value, inputs, Reclassification [Member] | Debt securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	'	[3],[5]	'
Fair Value, Measurements, Recurring [Member] | Fair value, inputs, Reclassification [Member] | Commodity contracts [Member]	'		'
Assets:	'		'
Derivative Assets	2	[5]	'
Liabilities:	'		'
Derivative Liabilities	2	[5]	'
Fair Value, Measurements, Recurring [Member] | Fair value, inputs, Reclassification [Member] | Interest Rate Swap [Member]	'		'
Assets:	'		'
Derivative Assets	'	[5]	'
Liabilities:	'		'
Derivative Liabilities	'	[5]	'
Fair Value, Measurements, Recurring [Member] | Total [Member]	'		'
Assets:	'		'
Total assets	1,952		2,835
Liabilities:	'		'
Total liabilities	1,473		2,600
Fair Value, Measurements, Recurring [Member] | Total [Member] | Equity securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	471	[3]	393	[3]
Fair Value, Measurements, Recurring [Member] | Total [Member] | Debt securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	266	[3]	261	[3]
Fair Value, Measurements, Recurring [Member] | Total [Member] | Commodity contracts [Member]	'		'
Assets:	'		'
Derivative Assets	1,131		2,047
Liabilities:	'		'
Derivative Liabilities	209		383
Fair Value, Measurements, Recurring [Member] | Total [Member] | Interest Rate Swap [Member]	'		'
Assets:	'		'
Derivative Assets	84		134
Liabilities:	'		'
Derivative Liabilities	$1,264		$2,217
[1]	The investment objective for equity securities is to invest tax efficiently and to match the performance of the S&P 500 Index.
[2]	The investment objective for debt securities is to invest in a diversified tax efficient portfolio with an overall portfolio rating of AA or above as graded by S&P or Aa2 by Moody's Investors Services, Inc. The debt securities are heavily weighted with municipal bonds. The debt securities had an average coupon rate of 3.97% and 4.38% at September 30, 2013 and December 31, 2012, respectively, and an average maturity of 6 years at both September 30, 2013 and December 31, 2012.
[3]	The nuclear decommissioning trust investment is included in the other investments line in the balance sheet. See Note 13.
[4]	See table below for description of Level 3 assets and liabilities.
[5]	Fair values are determined on a contract basis, but certain contracts result in a current asset and a noncurrent liability, or vice versa, as presented in the balance sheet.

Fair_Value_Measurements_Schedu1

Fair Value Measurements (Schedule of Fair Value of the Level 3 Assets and Liabilities by Major Contract Type (All Related to Commodity Contracts) and the Significant Unobservable Inputs Used in the Valuations) (Details) (Derivative financial instruments, assets and liabilities [Member], Level 3 [Member], USD $)	9 Months Ended		12 Months Ended
	Sep. 30, 2013		Dec. 31, 2012
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Assets	$48,000,000	[1]	$83,000,000	[1]
Liabilities	-1,219,000,000	[1]	-54,000,000	[1]
Derivative Assets (Liabilities), at Fair Value, Net	-1,171,000,000	[1]	29,000,000	[1]
Electricity purchases and sales [Member] | Valuation Model [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Assets	5,000,000	[1]	5,000,000	[1]
Liabilities	-2,000,000	[1]	-9,000,000	[1]
Derivative Assets (Liabilities), at Fair Value, Net	3,000,000	[1]	-4,000,000	[1]
Electricity spread options [Member] | Option Pricing Model [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Assets	0	[1]	34,000,000	[1]
Liabilities	-19,000,000	[1]	-10,000,000	[1]
Derivative Assets (Liabilities), at Fair Value, Net	-19,000,000	[1]	24,000,000	[1]
Electricity congestion revenue rights [Member] | Market Approach [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Assets	37,000,000	[1],[2]	41,000,000	[1],[2]
Liabilities	-5,000,000	[1],[2]	-2,000,000	[1],[2]
Derivative Assets (Liabilities), at Fair Value, Net	32,000,000	[1],[2]	39,000,000	[1],[2]
Coal purchases [Member] | Market Approach [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Assets	1,000,000	[1],[2]	0	[1],[2]
Liabilities	-12,000,000	[1],[2]	-32,000,000	[1],[2]
Derivative Assets (Liabilities), at Fair Value, Net	-11,000,000	[1],[2]	-32,000,000	[1],[2]
Interest Rate Swap [Member] | Market Approach [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Assets	0	[1]	'
Liabilities	-1,167,000,000	[1]	'
Derivative Assets (Liabilities), at Fair Value, Net	-1,167,000,000	[1]	'
Other [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Assets	5,000,000	[1]	3,000,000	[1]
Liabilities	-14,000,000	[1]	-1,000,000	[1]
Derivative Assets (Liabilities), at Fair Value, Net	-9,000,000	[1]	2,000,000	[1]
Minimum [Member] | Electricity purchases and sales [Member] | Valuation Model [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Illiquid pricing locations (in usd per MWh)	30	[1],[3],[4]	20	[1],[3],[4]
Hourly price curve shape (in usd per MWh)	20	[1],[4],[5]	20	[1],[4],[5]
Minimum [Member] | Electricity spread options [Member] | Option Pricing Model [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Gas to power correlation (as a percent)	45.00%	[1],[4],[6]	20.00%	[1],[4],[6]
Power volatility (as a percent)	10.00%	[1],[4],[7]	20.00%	[1],[4],[7]
Minimum [Member] | Electricity congestion revenue rights [Member] | Market Approach [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Illiquid price differences between settlement points	0	[1],[2],[4],[8]	0	[1],[2],[4],[8]
Minimum [Member] | Coal purchases [Member] | Market Approach [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Probability of default (as a percent)	0.00%	[1],[2],[4],[9]	5.00%	[1],[2],[4],[9]
Recovery rate (as a percent)	0.00%	[1],[10],[2],[4]	0.00%	[1],[10],[2],[4]
Illiquid price variances between mines	0	[1],[11],[2],[4]	0	[1],[11],[2],[4]
Minimum [Member] | Interest Rate Swap [Member] | Valuation Model [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Fair Value Inputs, Nonperformance Risk Adjustment	30.00%	[1],[12],[4]	'
Maximum [Member] | Electricity purchases and sales [Member] | Valuation Model [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Illiquid pricing locations (in usd per MWh)	45	[1],[3],[4]	40	[1],[3],[4]
Hourly price curve shape (in usd per MWh)	70	[1],[4],[5]	50	[1],[4],[5]
Maximum [Member] | Electricity spread options [Member] | Option Pricing Model [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Gas to power correlation (as a percent)	100.00%	[1],[4],[6]	90.00%	[1],[4],[6]
Power volatility (as a percent)	30.00%	[1],[4],[7]	40.00%	[1],[4],[7]
Maximum [Member] | Electricity congestion revenue rights [Member] | Market Approach [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Illiquid price differences between settlement points	30	[1],[2],[4],[8]	0.5	[1],[2],[4],[8]
Maximum [Member] | Coal purchases [Member] | Market Approach [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Probability of default (as a percent)	40.00%	[1],[2],[4],[9]	40.00%	[1],[2],[4],[9]
Recovery rate (as a percent)	40.00%	[1],[10],[2],[4]	40.00%	[1],[10],[2],[4]
Illiquid price variances between mines	$1	[1],[11],[2],[4]	$1	[1],[11],[2],[4]
Maximum [Member] | Interest Rate Swap [Member] | Valuation Model [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Fair Value Inputs, Nonperformance Risk Adjustment	35.00%	[1],[12],[4]	'
[1]	Electricity purchase and sales contracts include wind generation agreements and hedging positions in the ERCOT west region as well as power contracts, the valuations of which include unobservable inputs related to the hourly shaping of the price curve. Electricity spread option contracts consist of physical electricity call options. Electricity congestion revenue rights contracts consist of forward purchase contracts (swaps and options) used to hedge electricity price differences between settlement points within ERCOT. Coal purchase contracts relate to western (Powder River Basin) coal. Interest rate swaps are held by TCEH to hedge exposure to its variable rate debt.
[2]	While we use the market approach, there is either insufficient market data to consider the valuation liquid or the significance of credit reserves or non-performance risk adjustments results in a Level 3 designation.
[3]	Based on the historical range of forward average monthly ERCOT West Hub prices.
[4]	The range of the inputs may be influenced by factors such as time of day, delivery period, season and location.
[5]	Based on the historical range of forward average hourly ERCOT North Hub prices.
[6]	Estimate of the historical range based on forward natural gas and on-peak power prices for the ERCOT hubs most relevant to our spread options.
[7]	Based on historical forward price changes.
[8]	Based on the historical price differences between settlement points in the ERCOT North Hub and the ERCOT West Hub.
[9]	Estimate of the range of probabilities of default based on past experience and the length of the contract as well as our and counterparties' credit ratings.
[10]	Estimate of the default recovery rate based on historical corporate rates.
[11]	Based on the historical range of price variances between mine locations.
[12]	Estimate of nonperformance risk adjustment based on TCEH senior secured bond trading values. See discussion immediately below regarding transfers into Level 3.

Fair_Value_Measurements_Schedu2

Fair Value Measurements (Schedule of Changes in Fair Value of the Level 3 Assets and Liabilities (All Related to Commodity Contracts)) (Details) (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013	Dec. 31, 2012
	Level 3 [Member]		Level 3 [Member]		Level 3 [Member]		Level 3 [Member]		Texas Competitive Electric Holdings Company LLC [Member]	Texas Competitive Electric Holdings Company LLC [Member]
	Commodity contracts [Member]		Commodity contracts [Member]		Commodity contracts [Member]		Commodity contracts [Member]		Interest Rate Swap [Member]	Interest Rate Swap [Member]
	Derivative financial instruments, assets and liabilities [Member]		Derivative financial instruments, assets and liabilities [Member]		Derivative financial instruments, assets and liabilities [Member]		Derivative financial instruments, assets and liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring Basis [Line Items]	'		'		'		'		'	'
Accumulated Unrealized Gain (Loss) On Interest Rate Derivative Instruments Not Designated As Hedging Instruments	'		'		'		'		$1,518	$2,065
Accumulated Unrealized Gain (Loss) On Interest Rate Derivative Instruments Not Designated As Hedging Instruments Net Of Nonperformance Risk Adjustments	'		'		'		'		1,167	'
Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'		'		'		'		'	'
Net asset (liability) balance at beginning of period	88		12		29		53		'	'
Total unrealized valuation gains (losses)	-24		12		-41		-5		'	'
Purchases, issuances and settlements:	'		'		'		'		'	'
Purchases	6	[1]	17	[1]	66	[1]	30	[1]	'	'
Issuances	0	[1]	-4	[1]	-6	[1]	-15	[1]	'	'
Settlements	-62	[1]	-56	[1]	-45	[1]	-34	[1]	'	'
Transfers into Level 3	-1,179	[2]	3	[2]	-1,178	[2]	-42	[2]	'	'
Transfers out of Level 3	0	[2]	0	[2]	4	[2]	-3	[2]	'	'
Net change	-1,259	[3]	-28	[3]	-1,200	[3]	-69	[3]	'	'
Net asset balance at end of period	-1,171		-16		-1,171		-16		'	'
Unrealized valuation gains (losses) relating to instruments held at end of period	$254		$15		$280		($22)		'	'
[1]	Settlements reflect reversals of unrealized mark-to-market valuations previously recognized in net income. Purchases and issuances reflect option premiums paid or received.
[2]	Includes transfers due to changes in the observability of significant inputs. Transfers in and out occur at the end of each quarter, which is when the assessments are performed. All Level 3 transfers during the periods presented are in and out of Level 2.
[3]	Substantially all changes in values of commodity contracts are reported in the income statement in net gain (loss) from commodity hedging and trading activities. Changes in values of interest rate swaps are reported in the income statement in interest expense and related charges. Activity excludes changes in fair value in the month the position settled as well as amounts related to positions entered into and settled in the same month.

Commodity_And_Other_Derivative2

Commodity And Other Derivative Contractual Assets And Liabilities (Financial Statement Effects of Derivatives) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Derivatives, Fair Value [Line Items]	'	'
Derivative asset, Fair Value, Gross Asset	$1,215	$2,181
Derivative liabilities, Fair Value, Gross Liability	-1,473	-2,600
Derivative, Fair Value, Net	-258	-419
Current assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Assets And Liability, Fair Value, Gross Assets	1,056	1,595
Noncurrent assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Assets And Liability, Fair Value, Gross Assets	159	586
Current liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Assets And Liability, Fair Value, Gross Liability	-691	-1,044
Noncurrent liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative Assets And Liability, Fair Value, Gross Liability	-782	-1,556
Commodity contracts [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative asset, Fair Value, Gross Asset	1,131	2,047
Derivative liabilities, Fair Value, Gross Liability	-209	-383
Derivative asset, Fair Value, Net	1,129	2,047
Derivative liabilities, Fair Value, Net	-207	-383
Commodity contracts [Member] | Current assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative asset, Fair Value, Gross Asset	972	1,461
Derivative liabilities, Fair Value, Gross Asset	0	0
Commodity contracts [Member] | Noncurrent assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative asset, Fair Value, Gross Asset	159	586
Derivative liabilities, Fair Value, Gross Asset	0	0
Commodity contracts [Member] | Current liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative asset, Fair Value, Gross Liability	-2	0
Derivative liabilities, Fair Value, Gross Liability	-204	-366
Commodity contracts [Member] | Noncurrent liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative asset, Fair Value, Gross Liability	0	0
Derivative liabilities, Fair Value, Gross Liability	-3	-17
Interest Rate Swap [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative asset, Fair Value, Gross Asset	84	134
Derivative liabilities, Fair Value, Gross Liability	-1,264	-2,217
Derivative asset, Fair Value, Net	84	134
Derivative liabilities, Fair Value, Net	-1,264	-2,217
Interest Rate Swap [Member] | Current assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative asset, Fair Value, Gross Asset	84	134
Derivative liabilities, Fair Value, Gross Asset	0	0
Interest Rate Swap [Member] | Noncurrent assets [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative asset, Fair Value, Gross Asset	0	0
Derivative liabilities, Fair Value, Gross Asset	0	0
Interest Rate Swap [Member] | Current liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative asset, Fair Value, Gross Liability	0	0
Derivative liabilities, Fair Value, Gross Liability	-485	-678
Interest Rate Swap [Member] | Noncurrent liabilities [Member]	'	'
Derivatives, Fair Value [Line Items]	'	'
Derivative asset, Fair Value, Gross Liability	0	0
Derivative liabilities, Fair Value, Gross Liability	($779)	($1,539)

Commodity_And_Other_Derivative3

Commodity And Other Derivative Contractual Assets And Liabilities (Derivative (Income Statement Presentation) and Derivative type (Income Statement Presentation of Loss Reclassified from Accumulated OCI into Income)) (Details) (USD $)

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Net gain from commodity hedging and trading activities [Member]

Net gain from commodity hedging and trading activities [Member]

Net gain from commodity hedging and trading activities [Member]

Net gain from commodity hedging and trading activities [Member]

Interest expense and related charges [Member]

Interest expense and related charges [Member]

Interest expense and related charges [Member]

Interest expense and related charges [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Cash Flow Hedging [Member]

Commodity contracts [Member]

Commodity contracts [Member]

Commodity contracts [Member]

Commodity contracts [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Interest expense and related charges [Member]

Interest expense and related charges [Member]

Interest expense and related charges [Member]

Interest expense and related charges [Member]

Depreciation and amortization [Member]

Depreciation and amortization [Member]

Depreciation and amortization [Member]

Depreciation and amortization [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Derivative Instruments, Gain (Loss) [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net gain (loss)

$351

($283)

$487

($390)

'

'

$98

[1]

($95)

[1]

$54

[1]

$130

[1]

$253

[2]

($188)

[2]

$433

[2]

($520)

[2]

'

'

'

'

'

'

'

'

'

'

'

'

Income statement presentation of loss reclassified from accumulated OCI into income

-2

-2

-6

-7

'

'

'

'

'

'

'

'

'

'

-2

-2

-8

-8

-1

-1

-6

-6

-1

-1

-2

-2

Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax

'

'

'

'

-38

-43

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest Rate Cash Flow Hedge Gain (Loss) to be Reclassified During Next 12 Months, Net

'

'

'

'

($2)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

Amount represents changes in fair value of positions in the derivative portfolio during the period, as realized amounts related to positions settled are assumed to equal reversals of previously recorded unrealized amounts.

[2]

Includes unrealized mark-to-market net gain (loss) as well as the net realized effect on interest paid/accrued, both reported in "Interest Expense and Related Charges" (see Note 13).

Commodity_And_Other_Derivative4

Commodity And Other Derivative Contractual Assets And Liabilities (Derivative Assets and Liabilities From Balance Sheet to Net Amounts After Consideration Netting Arrangements with Counterparties and Financial Collateral) (Details) (USD $)	Sep. 30, 2013		Dec. 31, 2012
Derivatives, Fair Value [Line Items]	'		'
Derivative Assets (Liability), Fair Value, Amount Offset Against Collateral, Secured By First Lien Interest in Subsidiary	$1,200,000,000		'
Derivative assets: Amounts Presented in Balance Sheet	1,215,000,000		2,181,000,000
Derivative assets: Offsetting Financial Instruments	-697,000,000	[1]	-1,397,000,000	[1]
Derivative assets: Financial Collateral (Received) Pledged	-351,000,000	[2]	-597,000,000	[2]
Derivative assets: Net Amounts	167,000,000	[3]	187,000,000
Derivative liabilities: Amounts Presented in Balance Sheet	-1,473,000,000		-2,600,000,000
Derivative liabilities: Offsetting Financial Instruments	697,000,000	[1]	1,397,000,000	[1]
Derivative liabilities: Financial Collateral (Received) Pledged	11,000,000	[2]	29,000,000	[2]
Derivative liabilities: Net Amounts	-765,000,000	[3]	-1,174,000,000
Derivative, Fair Value, Net	-258,000,000		-419,000,000
Derivative (Assets) Liability, Fair Value of Collateral, Net	-340,000,000	[2]	-568,000,000	[2]
Derivative Assets (Liability), Fair Value, Amount Offset Against Collateral	-598,000,000	[3]	-987,000,000
Commodity contracts [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative assets: Amounts Presented in Balance Sheet	1,131,000,000		2,047,000,000
Derivative assets: Offsetting Financial Instruments	-613,000,000	[1]	-1,263,000,000	[1]
Derivative assets: Financial Collateral (Received) Pledged	-351,000,000	[2]	-597,000,000	[2]
Derivative assets: Net Amounts	167,000,000	[3]	187,000,000
Derivative liabilities: Amounts Presented in Balance Sheet	-209,000,000		-383,000,000
Derivative liabilities: Offsetting Financial Instruments	180,000,000	[1]	319,000,000	[1]
Derivative liabilities: Financial Collateral (Received) Pledged	11,000,000	[2]	29,000,000	[2]
Derivative liabilities: Net Amounts	-18,000,000	[3]	-35,000,000
Interest Rate Swap [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative assets: Amounts Presented in Balance Sheet	84,000,000		134,000,000
Derivative assets: Offsetting Financial Instruments	-84,000,000	[1]	-134,000,000	[1]
Derivative assets: Financial Collateral (Received) Pledged	0	[2]	0	[2]
Derivative assets: Net Amounts	0	[3]	0
Derivative liabilities: Amounts Presented in Balance Sheet	-1,264,000,000		-2,217,000,000
Derivative liabilities: Offsetting Financial Instruments	517,000,000	[1]	1,078,000,000	[1]
Derivative liabilities: Financial Collateral (Received) Pledged	0	[2]	0	[2]
Derivative liabilities: Net Amounts	($747,000,000)	[3]	($1,139,000,000)
[1]	Offsetting financial instruments with respect to commodity contracts include amounts related to interest rate swaps and vice versa. Amounts exclude trade accounts receivable and payable related to settled financial instruments.
[2]	Financial collateral consists entirely of cash margin deposits.
[3]	Includes net liability positions totaling approximately $1.2 billion (before nonperformance risk adjustment) related to counterparties with positions that are secured by a first-lien interest in the same assets of TCEH (on a pari passu basis) with the TCEH Senior Secured Facilities and the TCEH Senior Secured Notes.

Commodity_And_Other_Derivative5

Commodity And Other Derivative Contractual Assets And Liabilities (Derivative Volumes) (Details) (USD $)	Sep. 30, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Interest rate swaps - Floating/fixed [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative, Notional Amount	$32,440	[1]	$32,760	[1]
Interest rate swaps - Basis [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative, Notional Amount	$11,967		$11,967
Natural gas price hedge forward sales and purchases (in MMBtu) [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Nonmonetary Notional Volume	452,000,000	[2]	875,000,000	[2]
Nonmonetary notional amount of price risk derivatives, net transaction amounts (in MMBtu)	210,000,000		360,000,000
Natural gas Locational basis swaps (in MMBtu) [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Nonmonetary Notional Volume	337,000,000		495,000,000
All other (in MMBtu) [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Nonmonetary Notional Volume	2,021,000,000		1,549,000,000
Electricity (in GWh) [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Nonmonetary Notional Volume	21,663		76,767
Congestion Revenue RIghts (in GWh) [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Nonmonetary Notional Volume	82,156	[3]	111,185	[3]
Coal (in tons) [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Nonmonetary Notional Volume	11,000,000		13,000,000
Fuel oil (in gallons) [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Nonmonetary Notional Volume	28,000,000		47,000,000
Uranium (in pounds) [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Nonmonetary Notional Volume	575,000		441,000
[1]	Includes notional amount of interest rate swaps with maturity dates through October 2014 as well as notional amount of swaps effective from October 2014 with maturity dates through October 2017 (see Note 5).
[2]	Represents gross notional forward sales, purchases and options transactions in the natural gas hedging program. The net amount of these transactions was approximately 210 million MMBtu and 360 million MMBtu at September 30, 2013 and December 31, 2012, respectively.
[3]	Represents gross forward purchases associated with instruments used to hedge electricity price differences between settlement points within ERCOT.

Commodity_And_Other_Derivative6

Commodity And Other Derivative Contractual Assets And Liabilities (Credit Risk-Related Contingent Features of Derivatives) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Credit Derivatives [Line Items]	'	'
Derivative, Net Liability Position, Aggregate Fair Value	$1,329	$2,357
Credit risk derivative with contingent feature [Member]	'	'
Credit Derivatives [Line Items]	'	'
Derivative, Net Liability Position, Aggregate Fair Value	40	58
Liquidity exposure associated with liabilities reduced by cash and letter of credit postings with the counterparties	9	12
Assets Needed for Immediate Settlement, Aggregate Fair Value	8	0
Cross-default credit derivative [Member]	'	'
Credit Derivatives [Line Items]	'	'
Derivative, Net Liability Position, Aggregate Fair Value	1,289	2,299
Assets Needed for Immediate Settlement, Aggregate Fair Value	$1,102	$1,141

Commodity_And_Other_Derivative7

Commodity And Other Derivative Contractual Assets And Liabilities (Concentrations of Credit Risk Related to Derivatives) (Details) (Texas Competitive Electric Holdings Company LLC [Member], Credit Risk Contract [Member], USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013
Texas Competitive Electric Holdings Company LLC [Member] | Credit Risk Contract [Member]	'
Derivative [Line Items]	'
Total credit risk exposure to all counterparties related to derivative contracts	$1,352
Net exposure to those counterparties after taking into effect master netting arrangements, setoff provisions and collateral	276
Credit risk exposure to Banking and financial sector percentage	88.00%
Net exposure to banking and financial sector percentage	59.00%
Largest net exposure to single counterparty	$50

Pension_And_Other_Postretireme2

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Narrative) (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013
Pension and OPEB [Member] | Majority-Owned Subsidiary, Unconsolidated [Member] | Oncor [Member]	'
Defined Benefit Plan, Estimated Future Employer Contributions	'
Estimated future employer contributions in next fiscal year	$3
Pension benefits [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.30%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	5.40%
Defined Benefit Plan, Estimated Future Employer Contributions	'
Defined Benefit Plan Contributions By Employer Excluding Affiliated Supplemental Plan	7
Estimated future employer contributions in next fiscal year	0
Pension benefits [Member] | Majority-Owned Subsidiary, Unconsolidated [Member] | Oncor [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Defined Benefit Plan, Contributions by Employer	7
OPEB [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	4.10%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	6.70%
Defined Benefit Plan, Contributions by Employer	13
Defined Benefit Plan, Estimated Future Employer Contributions	'
Estimated future employer contributions in next fiscal year	5
OPEB [Member] | Majority-Owned Subsidiary, Unconsolidated [Member] | Oncor [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Defined Benefit Plan, Contributions by Employer	$9

Pension_And_Other_Postretireme3

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Pension and OPEB Costs Recognized as Expense) (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Components of net pension/OPEB costs:	'	'	'	'
Total benefit costs	$14	$46	$45	$135
Net amounts recognized as expense by EFH Corp. and consolidated subsidiaries	2	17	8	45
Oncor [Member] | Majority-Owned Subsidiary, Unconsolidated [Member]	'	'	'	'
Components of net pension/OPEB costs:	'	'	'	'
Less amounts expensed by Oncor	-6	-8	-19	-26
Less amounts deferred principally as a regulatory asset or property by Oncor	-6	-21	-18	-64
Pension benefits [Member]	'	'	'	'
Components of net pension/OPEB costs:	'	'	'	'
Service cost	2	13	6	36
Interest cost	3	38	9	118
Expected return on assets	-2	-42	-5	-122
Amortization of net loss	2	30	6	84
Total benefit costs	5	39	16	116
OPEB [Member]	'	'	'	'
Components of net pension/OPEB costs:	'	'	'	'
Service cost	3	3	8	7
Interest cost	10	11	31	33
Expected return on assets	-3	-3	-9	-9
Amortization of transition obligation	0	0	0	1
Amortization of prior service cost	-8	-8	-23	-24
Amortization of net loss	7	4	22	11
Total benefit costs	$9	$7	$29	$19

Related_Party_Transactions_Nar

Related Party Transactions (Narrrative) (Details) (USD $)

9 Months Ended

3 Months Ended

9 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

1 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

1 Months Ended

3 Months Ended

9 Months Ended

9 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Mar. 31, 2013

Mar. 31, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Jan. 31, 2013

Sep. 30, 2012

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Aug. 31, 2012

Feb. 29, 2012

Sep. 30, 2013

Dec. 31, 2012

Aug. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Mar. 31, 2013

Aug. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2012

Sep. 30, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2013

Sep. 30, 2013

Oncor [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Oncor Holdings [Member]

Oncor Holdings [Member]

Sponsor Group [Member]

Sponsor Group [Member]

Sponsor Group [Member]

Sponsor Group [Member]

Senior Notes [Member]

10.875% Fixed Senior Notes due November 1, 2017 [Member]

EFH Corp. [Member]

EFH Corp. [Member]

EFH Corp. [Member]

EFH Corp. [Member]

EFH Corp. [Member]

EFH Corp. [Member]

EFH Corp. [Member]

EFH Corp. [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Indirect Guarantee of Indebtedness [Member]

Debt held by related party [Member]

Debt held by related party [Member]

Debt held by related party [Member]

Returned debt as dividend [Member]

Related Party Transactions, Agreement Between Parties To Settle Future Reimbursements [Member]

Decommisioning liablity [Member]

Decommisioning liablity [Member]

Receivable attributable to income taxes [Member]

Receivable attributable to income taxes [Member]

Receivable attributable to income taxes [Member]

Receivable attributable to income taxes [Member]

Agreement between parties to settle obligations under the note [Member]

Agreement between parties to settle obligations under the note [Member]

Collateral posted [Member]

Collateral posted [Member]

Internal Revenue Service (IRS) [Member]

Internal Revenue Service (IRS) [Member]

Texas Comptroller Of Public Accounts [Member]

Oncor Holdings [Member]

Senior Notes [Member]

9.75% Fixed Senior Secured First Lien Notes due October 15, 2019 [Member]

9.75% Fixed Senior Secured First Lien Notes due October 15, 2019 [Member]

10.875% Fixed Senior Notes due November 1, 2017 [Member]

10.875% Fixed Senior Notes due November 1, 2017 [Member]

10% Fixed Senior Secured First Lien Notes due January 15, 2020 [Member]

10% Fixed Senior Secured First Lien Notes due January 15, 2020 [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Line of Credit [Member]

10% Fixed Senior Secured First Lien Notes due December 1, 2020 [Member]

10% Fixed Senior Secured First Lien Notes due December 1, 2020 [Member]

9.75% Fixed Senior Secured First Lien Notes due October 15, 2019 [Member]

9.75% Fixed Senior Secured First Lien Notes due October 15, 2019 [Member]

11.75% Fixed Senior Secured Second Lien Notes due March 1, 2022 [Member]

11.75% Fixed Senior Secured Second Lien Notes due March 1, 2022 [Member]

11.75% Fixed Senior Secured Second Lien Notes due March 1, 2022 [Member]

11.75% Fixed Senior Secured Second Lien Notes due March 1, 2022 [Member]

6.875% Senior Secured First Lien Notes due August 15, 2017 [Member]

6.875% Senior Secured First Lien Notes due August 15, 2017 [Member]

6.875% Senior Secured First Lien Notes due August 15, 2017 [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Senior Secured Debt [Member]

Line of Credit [Member]

Senior Notes [Member]

Energy Future Intermediate Holding CO LLC [Member]

Senior Notes [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Oncor [Member]

Oncor [Member]

Oncor Holdings [Member]

Oncor Holdings [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Audit Years 1997 Through 2002 [Member]

Audit Years 1997 Through 2002 [Member]

Audit Years 1997 Through 2001 [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Goldman, Sachs & Co. [Member]

Goldman, Sachs & Co. [Member]

Affiliates of KKR and TPG Management, L.P. [Member]

TCEH to EFH [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Rating-Agencies-Downgrades

Rating-Agencies-Downgrades

Line of Credit [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Noninterest bearing note payable maturing in 2016 [Member]

Noninterest bearing note payable maturing in 2016 [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Texas Competitive Electric Holdings Company LLC [Member]

EFH Corp. [Member]

Goldman, Sachs & Co. [Member]

Goldman, Sachs & Co. [Member]

Goldman, Sachs & Co. [Member]

TCEH to EFH [Member]

EFH Corp. [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Related Party Transaction [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Selling, general and administrative expenses from transactions with related party

'

'

($8)

($10)

($24)

($27)

'

'

'

$10

$9

$29

$28

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt issuance cost

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9.75%

'

10.88%

[1]

'

10.00%

'

'

'

'

'

10.00%

'

9.75%

'

11.75%

'

'

'

6.88%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Face Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

600

1,150

'

'

250

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Related party transaction, amounts of transaction

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

'

273

281

728

746

'

'

'

'

'

'

'

'

'

159

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt, gross

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

60

2

115

33

[1]

64

[1]

3

1,061

'

'

'

'

3,482

2,180

2

141

1,750

1,750

'

'

503

503

'

'

'

'

'

'

1,571

22,616

4,874

698

303

1,282

79

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Principal Amounts Cancelled, Payment as Dividend

'

'

'

'

'

'

'

'

'

'

'

'

'

1,235

1,715

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,360

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repayments of Related Party Debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

20

'

'

'

'

'

Due from Affiliates

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

233

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Increase (Decrease) In Restricted Cash Related to Settlement of Intercompany Note

-680

680

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Due to Affiliate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

158

'

158

'

53

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest expense, related party

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

16

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Delivery fee surcharge remitted to related party

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5

5

12

12

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Due to affiliate, noncurrent

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

352

284

'

'

'

'

'

'

'

'

'

'

'

Due from affiliate, current

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

28

22

35

34

'

'

'

'

'

'

'

Related party tax expense, due from affiliates, current

'

'

'

'

60

3

'

24

24

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

33

84

'

Related Party Tax Expense, Due to Affiliates, Current

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

21

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10

Letter of credit posted as collateral

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10

11

'

'

'

Accounts receivable, related parties, noncurrent

'

'

839

'

839

'

825

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Event of credit rating downgrade, letter of credit required to be posted to secure payment obligations

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$170

'

$170

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Event of credit rating downgrade, minimum number of rating agencies downgrade below investment grade (in credit agencies downgrades)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

Excludes the following debt held by EFIH or EFH Corp. (parent entity) and eliminated in consolidation: September 30, 2013 December 31, 2012EFH Corp. 10.875% Fixed Senior Notes due November 1, 2017$— $1,685EFH Corp. 11.25 / 12.00% Senior Toggle Notes due November 1, 2017— 3,441EFH Corp. 5.55% Fixed Series P Senior Notes due November 15, 2014281 279EFH Corp. 6.50% Fixed Series Q Senior Notes due November 15, 2024545 516EFH Corp. 6.55% Fixed Series R Senior Notes due November 15, 2034456 456TCEH 4.709% Term Loan Facilities maturing October 10, 201719 19TCEH 10.25% Fixed Senior Notes due November 1, 2015213 213TCEH 10.25% Fixed Senior Notes due November 1, 2015, Series B150 150Total$1,664 $6,759

Segment_Information_Details

Segment Information (Details) (USD $)	3 Months Ended		9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
			Reportable_segment
Segment Reporting Information [Line Items]	'	'	'	'
Number of reportable segments (in reportable segments)	'	'	2	'
Operating revenues (all Competitive Electric)	$1,893	$1,752	$4,572	$4,358
Equity in earnings of unconsolidated subsidiaries (net of tax) — Regulated Delivery (net of noncontrolling interest of $29, $27, $66 and $64)	114	109	255	249
Net income (loss):	5	-407	-635	-1,408
Competitive Electric [Member]	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'
Operating revenues (all Competitive Electric)	1,893	1,752	4,572	4,358
Net income (loss):	18	-393	-768	-1,319
Regulated Delivery [Member]	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'
Equity in earnings of unconsolidated subsidiaries (net of tax) — Regulated Delivery (net of noncontrolling interest of $29, $27, $66 and $64)	114	109	255	249
Net income (loss):	114	109	255	249
Corp. and Other [Member]	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'
Net income (loss):	-127	-123	-122	-338
Noncontrolling Interest [Member]	'	'	'	'
Segment Reporting Information [Line Items]	'	'	'	'
Equity in earnings of unconsolidated subsidiaries (net of tax) — Regulated Delivery (net of noncontrolling interest of $29, $27, $66 and $64)	$29	$27	$66	$64

Supplementary_Financial_Inform2

Supplementary Financial Information (Other Income and Deductions) (Details) (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Other income:	'		'		'		'
Office space rental income	$3	[1]	$3	[1]	$9	[1]	$9	[1]
Consent fee related to novation of hedge positions between counterparties	0	[2]	0	[2]	0	[2]	6	[2]
Insurance/litigation settlements	0	[2]	0	[2]	2	[2]	2	[2]
All other	2		3		8		8
Total other income	5		6		19		25
Other deductions:	'		'		'		'
Impairment of remaining equipment from cancelled generation development program	27	[2]	0	[2]	27	[2]	0	[2]
Impairment of mineral interests	0	[2]	24	[2]	0	[2]	24	[2]
Impairment of computer software assets	0	[1]	7	[1]	0	[1]	7	[1]
Other asset impairments	3	[2]	0	[2]	3	[2]	0	[2]
Counterparty contract settlement	0	[2]	4	[2]	0	[2]	4	[2]
Ongoing employee retirement benefit expense related to discontinued businesses	0	[1]	4	[1]	-1	[1]	10	[1]
All other	6		3		11		9
Total other deductions	$36		$42		$40		$54
[1]	Reported in Corporate and Other.
[2]	Reported in Competitive Electric segment.

Supplementary_Financial_Inform3

Supplementary Financial Information (Interest Expense and Related Charges) (Details) (USD $)	3 Months Ended				9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012		Sep. 30, 2013		Sep. 30, 2012
Interest Expense and Related Charges [Line Items]	'		'		'		'
Interest paid/accrued (including net amounts settled/accrued under interest rate swaps)	$851		$812		$2,532		$2,405
Interest payable with additional toggle notes (Note 5)	45		61		130		177
Unrealized mark-to-market net (gain) loss on interest rate swaps	-414	[1]	21	[1]	-903	[1]	12	[1]
Amortization of interest rate swap losses at dedesignation of hedge accounting	2		2		6		7
Amortization of fair value debt discounts resulting from purchase accounting	5		11		15		33
Amortization of debt issuance, amendment and extension costs and discounts	49		48		154		143
Capitalized interest	-5		-11		-19		-31
Total interest expense and related charges	533		944		1,915		2,746
Interest Rate Swap [Member] | Texas Competitive Electric Holdings Company LLC [Member]	'		'		'		'
Interest Expense and Related Charges [Line Items]	'		'		'		'
Unrealized mark-to-market net (gain) loss on interest rate swaps	-413		20		-899		16
Interest Rate Swap [Member] | EFH Corp. [Member]	'		'		'		'
Interest Expense and Related Charges [Line Items]	'		'		'		'
Unrealized mark-to-market net (gain) loss on interest rate swaps	($1)		$1		($4)		($4)
[1]	Three months ended September 30, 2013 and 2012 amounts include net gains totaling $413 million and net losses totaling $20 million, respectively, related to TCEH swaps (see Note 5) and net gains totaling $1 million and net losses totaling $1 million, respectively, related to EFH Corp. swaps substantially closed through offsetting positions. Nine months ended September 30, 2013 and 2012 amounts include net gains totaling $899 million and net losses totaling $16 million, respectively, related to TCEH swaps and net gains totaling $4 million for both periods related to EFH Corp. swaps substantially closed through offsetting positions.

Supplementary_Financial_Inform4

Supplementary Financial Information (Restricted Cash) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Restricted Cash and Investments, Current	$4	$680
Restricted Cash and Investments, Noncurrent	947	947
Other Restricted Cash [Member]	'	'
Restricted Cash and Investments, Current	4	0
Restricted Cash and Investments, Noncurrent	0	0
Energy Future Intermediate Holding CO LLC [Member] | Amounts in escrow to settle TCEH Demand Notes [Member]	'	'
Restricted Cash and Investments, Current	0	680
Restricted Cash and Investments, Noncurrent	0	0
Texas Competitive Electric Holdings Company LLC [Member] | Amounts Related to TCEH's Letter of Credit Facility [Member]	'	'
Restricted Cash and Investments, Current	0	0
Restricted Cash and Investments, Noncurrent	$947	$947

Supplementary_Financial_Inform5

Supplementary Financial Information (Inventories by Major Category and Other Investments) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Inventories by Major Category	'	'
Materials and supplies	$216	$201
Fuel stock	155	168
Natural gas in storage	29	24
Total inventories	400	393
Other Investments	'	'
Nuclear plant decommissioning trust	737	654
Assets related to employee benefit plans, including employee savings programs, net of distributions	63	70
Land	40	41
Miscellaneous other	3	2
Total other investments	$843	$767

Supplementary_Financial_Inform6

Supplementary Financial Information (Nuclear Decommissioning Trust) (Details) (USD $)

3 Months Ended

9 Months Ended

9 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Debt securities [Member]

Debt securities [Member]

Equity securities [Member]

Equity securities [Member]

Schedule of Schedule of Decommissioning Fund Investments [Line Items]

'

'

'

'

'

'

'

'

'

Debt, Weighted Average Interest Rate

'

'

'

'

'

3.97%

4.38%

'

'

Decommissioning Fund Investments, Debt securities, average maturity

'

'

'

'

'

'6

'6

'

'

Cost

$513

[1]

'

$513

[1]

'

$491

[1]

$261

[1],[2]

$246

[1],[2]

$252

[1],[3]

$245

[1],[3]

Unrealized gain

236

'

236

'

177

9

[2]

16

[2]

227

[3]

161

[3]

Unrealized loss

-12

'

-12

'

-14

-4

[2]

-1

[2]

-8

[3]

-13

[3]

Fair market value

737

'

737

'

654

266

[2]

261

[2]

471

[3]

393

[3]

Decommissioning Fund Investments, debt maturities, one through five years, fair value

'

'

'

'

'

103

'

'

'

Decommissioning Fund Investments, debt maturities, five through ten years, fair value

'

'

'

'

'

58

'

'

'

Decommissioning Fund Investments, debt maturities, after ten years, fair value

'

'

'

'

'

105

'

'

'

Realized gains

1

0

2

1

'

'

'

'

'

Realized losses

-3

-1

-3

-2

'

'

'

'

'

Proceeds from sales of securities

23

25

128

56

'

'

'

'

'

Investments in securities

($28)

($30)

($140)

($68)

'

'

'

'

'

[1]

Includes realized gains and losses on securities sold.

[2]

The investment objective for debt securities is to invest in a diversified tax efficient portfolio with an overall portfolio rating of AA or above as graded by S&P or Aa2 by Moody's Investors Services, Inc. The debt securities are heavily weighted with municipal bonds. The debt securities had an average coupon rate of 3.97% and 4.38% at September 30, 2013 and December 31, 2012, respectively, and an average maturity of 6 years at both September 30, 2013 and December 31, 2012.

[3]

The investment objective for equity securities is to invest tax efficiently and to match the performance of the S&P 500 Index.

Supplementary_Financial_Inform7

Supplementary Financial Information (Property, Plant and Equipment) (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
Supplementary Financial Information [Abstract]	'	'
Property, plant and equipment — net (Note 13)	$18,103,000,000	$18,705,000,000
Less accumulated amortization/depreciation	$7,800,000,000	$6,900,000,000

Supplementary_Financial_Inform8

Supplementary Financial Information (Asset Retirement and Mining Reclamation Obligations) (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Asset Retirement Obligations [Line Items]	'	'
Less amounts due currently	($60)	'
Noncurrent liability	444	452
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'	'
Beginning balance, Liability	536	'
Additions:	'	'
Accretion	41	'
Reductions:	'	'
Payments	-73	'
Ending balance, Liability	504	'
Nuclear Plant Decommissioning [Member]	'	'
Asset Retirement Obligations [Line Items]	'	'
Less amounts due currently	0	'
Noncurrent liability	385	'
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'	'
Beginning balance, Liability	368	'
Additions:	'	'
Accretion	17	'
Reductions:	'	'
Payments	0	'
Ending balance, Liability	385	'
Mining Land Reclamation [Member]	'	'
Asset Retirement Obligations [Line Items]	'	'
Less amounts due currently	-60	'
Noncurrent liability	26	'
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'	'
Beginning balance, Liability	135	'
Additions:	'	'
Accretion	23	'
Reductions:	'	'
Payments	-72	'
Ending balance, Liability	86	'
Other Asset Retirement Obligations [Member]	'	'
Asset Retirement Obligations [Line Items]	'	'
Less amounts due currently	'	'
Noncurrent liability	33	'
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'	'
Beginning balance, Liability	33	'
Additions:	'	'
Accretion	1	'
Reductions:	'	'
Payments	-1	'
Ending balance, Liability	$33	'

Supplementary_Financial_Inform9

Supplementary Financial Information (Other Noncurrent Liabilities and Deferred Credits) (Details) (USD $)

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Mar. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Sep. 30, 2013

Mar. 31, 2013

Sep. 30, 2013

Mar. 31, 2013

Sep. 30, 2013

Mar. 31, 2013

Jun. 30, 2013

Jun. 30, 2013

Oncor [Member]

Oncor [Member]

Internal Revenue Service (IRS) [Member]

Audit Years 1997 Through 2002 [Member]

Audit Years 1997 Through 2002 [Member]

Audit Years 1997 Through 2002 [Member]

Audit Years 2003 Through 2006 [Member]

Corporate and Other [Member]

Corporate and Other [Member]

Competitive Electric [Member]

Competitive Electric [Member]

Oncor [Member]

Oncor [Member]

Internal Revenue Service (IRS) [Member]

Internal Revenue Service (IRS) [Member]

Internal Revenue Service (IRS) [Member]

Internal Revenue Service (IRS) [Member]

Audit Years 1997 Through 2002 [Member]

Audit Years 2003 Through 2006 [Member]

Audit Years 1997 Through 2002 [Member]

Audit Years 2003 Through 2006 [Member]

Audit Years 1997 Through 2002 [Member]

Audit Years 1997 Through 2002 [Member]

Internal Revenue Service (IRS) [Member]

Internal Revenue Service (IRS) [Member]

Internal Revenue Service (IRS) [Member]

Internal Revenue Service (IRS) [Member]

Internal Revenue Service (IRS) [Member]

State and Local Jurisdiction [Member]

Other Noncurrent Liabilities Noncurrent and Deferred Credits [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Uncertain tax positions (including accrued interest)

$427

'

$427

'

$2,005

'

'

'

'

'

'

'

'

'

'

'

'

'

Retirement plan and other employee benefits

1,050

[1]

'

1,050

[1]

'

1,035

[1]

839

825

'

'

'

'

'

'

'

'

'

'

'

Asset retirement and mining reclamation obligations

444

'

444

'

452

'

'

'

'

'

'

'

'

'

'

'

'

'

Unfavorable purchase and sales contracts

596

'

596

'

620

'

'

'

'

'

'

'

'

'

'

'

'

'

Nuclear decomissioning cost over-recovery

352

'

352

'

284

'

'

'

'

'

'

'

'

'

'

'

'

'

Other

34

'

34

'

30

'

'

'

'

'

'

'

'

'

'

'

'

'

Total other noncurrent liabilities and deferred credits

2,903

'

2,903

'

4,426

'

'

'

'

'

'

'

'

'

'

'

'

'

Income Tax Examination, Reclassification to Accumulated Deferred Income Tax Liability

'

'

'

'

'

'

'

'

'

524

'

701

'

'

'

'

'

'

Income Tax Examination, Estimated Reversal of Accrued Interest from Examination, Before Tax

'

'

'

'

'

'

'

143

'

'

'

'

'

'

'

'

'

'

Income Tax Examination, Estimated Reversal of Accrued Interest from Examination, Net of Tax

'

'

'

'

'

'

'

84

'

'

'

'

'

'

'

'

'

'

Accumulated deferred income taxes

3,489

'

3,489

'

2,828

'

'

'

'

19

'

'

'

'

'

'

'

'

Accumulated deferred income taxes

34

'

34

'

48

'

'

'

'

8

'

'

'

'

'

'

'

'

Accrued Income Taxes, Current

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

15

Income Taxes Receivable, Current

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

33

'

Income Tax Expense (Benefit)

-100

-296

-925

-879

'

'

'

'

38

183

221

'

204

22

17

62

'

'

Amortization of Deferred Charges

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amortization of Unfavorable Purchase and Sales Contracts

6

6

19

20

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Estimated Future Amortization Expense

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2013

'

'

25

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2014

'

'

24

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2015

'

'

23

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2016

'

'

23

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2017

'

'

$23

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

Includes $839 million and $825 million at September 30, 2013 and December 31, 2012, respectively, representing pension and OPEB liabilities related to Oncor (see Note 11).

Recovered_Sheet1

Supplementary Financial Information (Supplemental Cash Flow Information) (Details) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Sep. 30, 2012
Cash payments (receipts) related to:	'		'
Interest paid	$2,391	[1]	$2,150	[1]
Capitalized interest	-19		-31
Interest paid (net of capitalized interest)	2,372		2,119
Income taxes	65		67
Noncash investing and financing activities:	'		'
Principal amount of toggle notes issued in lieu of cash interest (Note 5)	83		114
Construction expenditures	65	[2]	55	[2]
Debt exchange and extension transactions (Note 5)	-326		0
Debt assumed related to acquisition of combustion turbine trust interest	($45)		$0
[1]	Net of amounts received under interest rate swap agreements.
[2]	Represents end-of-period accruals.