Energy Future (TXU) 10-Q 7 May 14 2014 Q1 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information	3 Months Ended
	Mar. 31, 2014	7-May-14
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	31-Mar-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q1	'
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
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Operating revenues	$1,517	$1,260
Fuel, purchased power costs and delivery fees	-732	-636
Net loss from commodity hedging and trading activities	-219	-197
Operating costs	-214	-229
Depreciation and amortization	-330	-351
Selling, general and administrative expenses	-200	-162
Franchise and revenue-based taxes	-18	-17
Other income (Note 12)	9	8
Other deductions (Note 12)	0	-3
Interest income	1	0
Interest expense and related charges (Note 12)	-863	-784
Loss before income taxes and equity in earnings of unconsolidated subsidiaries	-1,049	-1,111
Income tax benefit	360	475
Equity in earnings of unconsolidated subsidiaries (net of tax) (Note 3)	80	67
Net loss	($609)	($569)

Condensed_Statements_Of_Consol1

Condensed Statements Of Consolidated Comprehensive Income (Loss) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Net loss	($609)	($569)
Other comprehensive income (loss), net of tax effects:	'	'
Effects related to pension and other retirement benefit obligations (net of tax benefit of $1 and $1)	-1	-2
Cash flow hedges derivative value net loss related to hedged transactions recognized during the period (net of tax benefit of $— and $1)	0	2
Net effects related to Oncor — reported in equity in earnings of unconsolidated subsidiaries (net of tax benefit of $— in both periods)	0	1
Total other comprehensive income (loss)	-1	1
Comprehensive loss	($610)	($568)

Condensed_Statements_Of_Consol2

Condensed Statements Of Consolidated Comprehensive Income (Loss) (Parenthetical) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Effects related to pension and other retirement benefit costs, tax benefit	$1	$1
Cash flow hedges derivative value net loss related to hedged transactions recognized during the period and reported in net income (loss), tax benefit	0	1
Net effects related to Oncor — reported in equity in earnings of unconsolidated subsidiaries, tax benefit	$0	$0

Condensed_Statements_Of_Consol3

Condensed Statements Of Consolidated Cash Flows (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Cash flows — operating activities:	'	'
Net loss	($609)	($569)
Adjustments to reconcile net loss to cash used in operating activities:	'	'
Depreciation and amortization	371	394
Deferred income tax benefit, net	-310	-322
Unrealized net loss from mark-to-market valuations of commodity positions	250	487
Unrealized net gain from mark-to-market valuations of interest rate swaps (Note 12)	-65	-150
Interest expense on toggle notes payable in additional principal (Notes 5 and 12)	49	41
Amortization of debt related costs, discounts, fair value discounts and losses on dedesignated cash flow hedges (Note 12)	55	61
Equity in earnings of unconsolidated subsidiaries	-80	-67
Distributions of earnings from unconsolidated subsidiaries	37	31
Bad debt expense (Note 12)	10	6
Accretion expense related primarily to mining reclamation obligations (Note 12)	6	8
Stock-based incentive compensation expense	2	2
Other, net	-2	0
Changes in operating assets and liabilities:	'	'
Margin deposits, net	-127	-199
Other operating assets and liabilities	-18	179
Cash used in operating activities	-431	-98
Cash flows — financing activities:	'	'
Repayments/repurchases of debt (Note 5)	-191	-16
Net borrowings under accounts receivable securitization program	0	7
Contributions from noncontrolling interests	1	1
Debt amendment, exchange and issuance costs and discounts, including third-party fees expensed	0	-6
Other, net	0	-1
Cash used in financing activities	-190	-15
Cash flows — investing activities:	'	'
Capital expenditures	-119	-139
Nuclear fuel purchases	-26	-20
Proceeds from sales of assets	0	1
Restricted cash used to settle TCEH Demand Notes (Note 10)	0	680
Reduction of Restricted Cash Related To TCEH Letter of Credit Facility	285	0
Other changes in restricted cash	0	-4
Proceeds from sales of environmental allowances and credits	1	0
Purchases of environmental allowances and credits	-5	-5
Proceeds from sales of nuclear decommissioning trust fund securities	33	41
Investments in nuclear decommissioning trust fund securities	-37	-45
Other, net	5	2
Cash provided by investing activities	137	511
Net change in cash and cash equivalents	-484	398
Cash and cash equivalents — beginning balance	1,217	1,913
Cash and cash equivalents — ending balance	$733	$2,311

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$733	$1,217
Restricted cash (Note 12)	664	949
Trade accounts receivable — net	635	718
Inventories (Note 12)	373	399
Commodity and other derivative contractual assets (Note 9)	686	851
Accumulated deferred income taxes	110	105
Margin deposits related to commodity positions	122	93
Other current assets	157	135
Total current assets	3,480	4,467
Restricted cash (Note 12)	0	0
Receivable from unconsolidated subsidiary (Note 10)	845	838
Investment in unconsolidated subsidiary (Note 3)	6,002	5,959
Other investments (Note 12)	910	891
Property, plant and equipment — net (Note 12)	17,558	17,791
Goodwill (Note 4)	3,952	3,952
Identifiable intangible assets — net (Note 4)	1,652	1,679
Commodity and other derivative contractual assets (Note 9)	10	4
Other noncurrent assets, primarily unamortized debt amendment and issuance costs	803	865
Total assets	35,212	36,446
Current liabilities:	'	'
Borrowings under credit facilities (Note 5)	2,054	2,054
Notes, loans and other debt (Note 5)	38,000	38,198
Trade accounts payable	330	401
Net payables due to unconsolidated subsidiary (Note 10)	57	128
Commodity and other derivative contractual liabilities (Note 9)	1,367	1,355
Margin deposits related to commodity positions	204	302
Accrued interest	822	564
Other current liabilities	366	504
Total current liabilities	43,200	43,506
Accumulated deferred income taxes	3,126	3,433
Other noncurrent liabilities and deferred credits (Note 12)	2,750	2,762
Total liabilities	49,076	49,701
Commitments and Contingencies (Note 6)	'	'
Equity (Note 7):	'	'
EFH Corp. shareholders' equity	-13,864	-13,256
Noncontrolling interests in subsidiaries	0	1
Total equity	-13,864	-13,255
Total liabilities and equity	$35,212	$36,446

Business_And_Significant_Accou

Business And Significant Accounting Policies	3 Months Ended
	Mar. 31, 2014
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 3).
	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 11 for further information concerning reportable business segments.
	Bankruptcy Filing
	As discussed further in Note 2, on April 29, 2014 (the Petition Date), EFH Corp. and the substantial majority of its direct and indirect subsidiaries, including EFIH, EFCH and TCEH but excluding the Oncor Ring-Fenced Entities, (the Debtors) filed voluntary petitions for relief (the Bankruptcy Filing) under Chapter 11 of the United States Bankruptcy Code (the Bankruptcy Code) in the United States Bankruptcy Court for the District of Delaware (the Bankruptcy Court). See Note 5 for discussion of debtor-in-possession financing and classification of debt as current liabilities.
	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 2013 Form 10-K. The condensed consolidated financial statements have been prepared as if EFH Corp. is a going concern but do not reflect the application of ASC 852, Reorganizations. 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 3). 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. 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 2013 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.

Subsequent_Event_Bankruptcy_Fi

Subsequent Event - Bankruptcy Filing Subsequent Event - Bankruptcy Filing	3 Months Ended
	Mar. 31, 2014
Reorganizations [Abstract]	'
Subsequent Event - Bankruptcy Filing	'
	2	SUBSEQUENT EVENT – BANKRUPTCY FILING
	On April 29, 2014, EFH Corp. and the substantial majority of its direct and indirect subsidiaries, including EFIH, EFCH and TCEH but excluding the Oncor Ring-Fenced Entities, filed voluntary petitions for relief under Chapter 11 of the United States Bankruptcy Code in the United States Bankruptcy Court for the District of Delaware. During the pendency of the Bankruptcy Filing, the Debtors will operate their businesses as "debtors-in-possession" under the jurisdiction of the Bankruptcy Court and in accordance with the applicable provisions of the Bankruptcy Code.
	In 2013, we began to engage in discussions with certain creditors with respect to proposed changes to our capital structure. In anticipation of the Bankruptcy Filing, on April 29, 2014, the Debtors entered into a Restructuring Support and Lock-Up Agreement (the Restructuring Support and Lock-Up Agreement) with various stakeholders in order to effect an agreed upon restructuring of the Debtors through a pre-arranged Chapter 11 plan of reorganization (the Restructuring Plan).
	Restructuring Support and Lock-Up Agreement
	General
	In anticipation of the Bankruptcy Filing, on April 29, 2014, the Debtors, Texas Holdings and its general partner Texas Energy Future Capital Holdings LLC (TEF and, together with Texas Holdings, the Consenting Interest Holders) and the Consenting Creditors entered into the Restructuring Support and Lock-Up Agreement in order to effect an agreed upon restructuring of the Debtors through the Restructuring Plan.
	Pursuant to the Restructuring Support and Lock-Up Agreement, the Consenting Interest Holders and Consenting Creditors agreed, subject to the terms and conditions contained in the Restructuring Support and Lock-Up Agreement, to support the Debtors' proposed financial restructuring (the Restructuring Transactions), and further agreed to limit certain transfers of any ownership (including any beneficial ownership) in the equity interests of or claims held against the Debtors, including any such interests or claims acquired after executing the Restructuring Support and Lock-Up Agreement.
	Material Restructuring Terms
	The Restructuring Support and Lock-Up Agreement along with the accompanying term sheet sets forth the material terms of the Restructuring Transactions pursuant to which, in general:
	TCEH First Lien Secured Claims
	As a result of the Restructuring Transactions, holders of TCEH first lien secured claims will receive, among other things, their pro rata share of (i) 100% of the equity of newly reorganized TCEH (Reorganized TCEH) consummated through a tax-free spin (in accordance with the Private Letter Ruling described below) in connection with TCEH's emergence from bankruptcy and (ii) all of the net cash from the proceeds of the issuance of new long-term secured debt of Reorganized TCEH.
	TCEH Unsecured Claims
	As a result of the Restructuring Transactions, holders of general unsecured claims against EFCH, TCEH and its subsidiaries (including TCEH first lien deficiency claims, TCEH second lien claims and TCEH unsecured note claims) will receive their pro rata share of the unencumbered assets of TCEH.
	EFIH First Lien and EFIH Second Lien Settlements
	Pursuant to the Restructuring Support Agreement, certain holders of each of the EFIH 6.875% Notes and EFIH 10% Notes (such holders, the RSA EFIH First Lien Note Parties) have agreed to voluntary settlements with respect to EFIH's and EFIH Finance's obligations under the EFIH First Lien Notes held by such RSA EFIH First Lien Note Parties. Under the terms of the settlement, each such RSA EFIH First Lien Note Party has agreed to accept as payment in full of any claims arising out of its EFIH First Lien Notes an amount of loans under the EFIH First Lien DIP Facility (as discussed in Note 5) equal to the greater of (a) 105% of the principal amount on the EFIH First Lien Notes plus 101% of the accrued and unpaid interest at the non-default rate on such principal (which amount will be deemed to include the original issue discount on the loans under the EFIH First Lien DIP Facility) or (b) 104% of the principal amount of, plus accrued and unpaid interest at the non-default rate on, the EFIH First Lien Notes, as adjusted by the original issue price discount paid on the loans under the EFIH First Lien DIP Facility in connection with the initial lender syndication of the EFIH First Lien DIP Facility (such settlement, the EFIH First Lien Settlement). The Debtors plan to file a motion seeking the Bankruptcy Court's approval of the EFIH First Lien Settlement.
	Pursuant to the Restructuring Support Agreement, certain holders of each of the EFIH 11% Notes and EFIH 11.75% Notes (such holders, the EFIH Second Lien Note Parties) have agreed to voluntary settlements with respect to EFIH's and EFIH Finance's obligations under the EFIH Second Lien Notes held by the EFIH Second Lien Note Parties. Under the terms of the settlement, each EFIH Second Lien Note Party has agreed to accept as payment in full of any claims arising out of its EFIH Second Lien Notes, its pro rata share of an amount in cash equal to (i) 100% of the principal, plus accrued and unpaid interest at the non-default rate on such principal, of EFIH Second Lien Notes held by such EFIH Second Lien Party plus (ii) 50% of the aggregate amount of any claim derived from or based upon make-whole or other similar provisions under the EFIH 11% Notes or EFIH 11.75% Notes (such settlement, the EFIH Second Lien Settlement). The Debtors plan to file a motion seeking the Bankruptcy Court's approval of the EFIH Second Lien Settlement.
	On May 6, 2014, EFIH commenced an offer to certain remaining holders of the EFIH First Lien Notes to participate in the EFIH First Lien Settlement; provided however, such EFIH First Lien Note holders agree to accept as payment in full of any claims arising out of such holders' EFIH First Lien Notes an amount of loans under the EFIH First Lien DIP Facility (as discussed in Note 5) equal to 105% of the principal amount of the EFIH First Lien Notes held by such holders plus 101% of the accrued and unpaid interest at the non-default rate on such principal (which amount will be deemed to include original issue discount on the loans under the EFIH First Lien DIP Facility). During the early portion of the Chapter 11 Cases, EFIH expects to (i) commence an offer to the remaining holders of EFIH Second Lien Notes to participate in the EFIH Second Lien Settlement, and (ii) initiate litigation to obtain entry of an order from the Bankruptcy Court disallowing the claims of any non-settling holders of the EFIH First Lien Notes and EFIH Second Lien Notes from or based on make-whole or other similar provisions under the respective notes. Following the completion of these offers, and pending Bankruptcy Court approval, non-settling EFIH First Lien Holders and non-settling EFIH Second Lien Note Holders will receive their respective pro rata shares of cash equal to 100% of the principal of applicable notes plus accrued and unpaid interest at the non-default rate of the notes held by such holder (not taking into account alleged premiums, settlements, fees or claims relating to the repayment of such claims) from the proceeds of the EFIH First Lien DIP Facility and EFIH Second Lien DIP Facility (as described in Note 5).
	The EFIH First Lien Settlement and the EFIH Second Lien Settlement will not be consummated unless, among other things, the Bankruptcy Court approves the EFIH First Lien DIP Facility, the EFIH First Lien Settlement, the EFIH Second Lien DIP Facility and the EFIH Second Lien Settlement.
	EFIH Second Lien DIP Notes Offering
	During the early portion of the Chapter 11 Cases, EFIH and EFIH Finance expect to offer (the EFIH Second Lien DIP Notes Offering) to certain holders of EFIH unsecured claims and a significant EFIH Second Lien Note Party the right to purchase $1.9 billion aggregate principal amount of 8% Mandatorily Convertible Second Lien Subordinated Secured DIP Financing Notes due 2016 (EFIH Second Lien DIP Facility or EFIH Second Lien DIP Notes).
	Backstop Commitment
	In connection with the execution of the Restructuring Support and Lock-Up Agreement, certain holders of the EFIH Unsecured Notes (the Backstop Parties) entered into a commitment letter with EFH Corp. and EFIH, dated April 29, 2014 (the Commitment Letter), pursuant to which such holders committed, severally and not jointly, up to $1.9 billion in available funds (the Backstop Commitment) to purchase EFIH Second Lien DIP Notes not sold in the EFIH Second Lien DIP Notes offering. Any EFIH Second Lien DIP Notes not sold in the EFIH Second Lien DIP Notes Offering will be purchased by the Backstop Parties, pro rata in proportion to their respective share of the Backstop Commitment. If any Backstop Party fails to satisfy its obligation to purchase its pro rata share of the unpurchased notes, the other Backstop Parties would have the right, but not the obligation, to purchase such unpurchased notes. The obligations under the Commitment Letter are not subject to the approval of the Oncor TSA Amendment (as described below) by the Bankruptcy Court.
	Under the Commitment Letter and in consideration of the Backstop Commitment, EFIH agreed to pay the Backstop Parties fees consisting of approximately (i) $40 million in execution and approval fees payable at various milestones within the bankruptcy process and (ii) a fee equal to $95 million payable in the form of Non-Interest Bearing Mandatorily Convertible Second Lien Subordinated Secured DIP Financing Tranche B Notes due 2016 (EFIH Second Lien DIP Tranche B Notes) to be paid concurrently with the consummation of the EFIH Second Lien DIP Notes Offering.
	In the event the EFIH Second Lien DIP Notes are repaid in cash prior to the effective date of the plan of reorganization (Effective Date) without the consent of certain creditors, EFIH agreed to pay the Backstop Parties a termination fee of $380 million. In addition, if EFIH seeks to consummate an alternative transaction that delivers equal or greater value to EFIH than the transactions contemplated by the Restructuring Support and Lock-Up Agreement, EFIH agreed to pay the holders of EFIH Second Lien DIP Notes a break-up fee of approximately $57 million.
	EFIH Unsecured Claims and EFH Corp. Unsecured Claims
	On the Effective Date, all of the EFIH Unsecured Notes and EFH Corp. Unsecured Notes will be canceled. In full satisfaction of all general unsecured claims against EFIH and all general unsecured claims against EFH Corp., (i) each holder of a general unsecured claim against EFIH will receive its pro rata share of 98.0% of the equity interests of newly reorganized EFH Corp. (Reorganized EFH Corp.) (subject to dilution by the Equity Conversion as described below) and (ii) each holder of a general unsecured claim against EFH Corp. will receive its pro rata share of 1.0% of the equity interests of Reorganized EFH Corp. (subject to dilution by the Equity Conversion) and the right to purchase up to 9% of the equity interests in Reorganized EFH Corp. from certain holders of EFIH Second Lien DIP Notes.
	Holders of general unsecured claims against EFH Corp. will also receive on the Effective Date their pro rata share of either (A) if the Oncor TSA Amendment (described below) has then been approved, (1) $55 million in cash from EFIH, provided, however, that if the Oncor tax payments received by EFIH under the Oncor TSA Amendment through the Effective Date are less than 80% of projected amounts, the $55 million payment will be reduced on a dollar for dollar basis by the amount of such shortfall, and (2) cash on hand at EFH Corp. (not including the settlement payment in clause (1) hereof); or (B) if the Oncor TSA Amendment has not then been approved, all assets of EFH Corp., including cash on hand but excluding the equity interests in EFIH.
	EFH Corp. Equity Interests
	On the Effective Date, all of the equity interests in EFH Corp. (EFH Corp. Interests) will be canceled. In full satisfaction of the claims under the EFH Corp. Interests, each holder of EFH Corp. Interests will receive its pro rata share of 1.0% of the equity interests of Reorganized EFH Corp. (subject to dilution by the Equity Conversion).
	Equity Conversion
	On the Effective Date, the EFIH Second Lien DIP Notes will, subject to certain conditions, automatically convert (Equity Conversion) on a pro rata basis into approximately 64% of the equity interests of Reorganized EFH Corp., subject to adjustment based on the principal amount of the EFIH Second Lien DIP Notes.
	Oncor TSA Amendment
	The Restructuring Support and Lock-Up Agreement provides that the Debtors will request authority from the Bankruptcy Court to amend, or otherwise assign the right to payments under, the Oncor Tax Sharing Agreement (the Oncor TSA Amendment) to provide that any payment required to be made to EFH Corp. under the Oncor Tax Sharing Agreement after March 31, 2014, will instead be made to EFIH. Any tax payments received by EFH Corp. before the Bankruptcy Court enters or denies an order authorizing the Oncor TSA Amendment will be deposited by EFH Corp. into a segregated account until the earlier of (i) the date the Bankruptcy Court enters the order authorizing the Oncor TSA Amendment, in which case such amounts will be remitted to EFIH, or (ii) the date the Bankruptcy Court denies authorization of the Oncor TSA Amendment, in which case such amounts will be remitted to EFH Corp.
	The Oncor TSA Amendment will automatically terminate and be of no further force and effect in the event that the Commitment Letter is terminated by the Backstop Parties; provided, however, that any amounts that were paid to EFIH in accordance with the Oncor TSA Amendment before its termination will be retained by EFIH if the Commitment Letter terminates or the EFIH Second Lien DIP Facility is not fully funded in accordance with its terms (i.e., except as a result of a breach by the Backstop Parties). Neither EFH Corp. nor EFIH will have the right to terminate or modify the Oncor TSA Amendment during the Chapter 11 Cases if the EFIH Second Lien DIP Facility is consummated.
	If the Bankruptcy Court has not approved the Oncor TSA Amendment within 90 days after the Petition Date, the interest rate on the interest bearing EFIH Second Lien DIP Tranche A Notes (but not the EFIH Second Lien DIP Tranche B Notes) will increase by 4.0% with such additional interest to be paid-in-kind (compounded quarterly) until such approval is received from the Bankruptcy Court. If the Bankruptcy Court has not approved the Oncor TSA Amendment by April 29, 2015, each holder of EFIH Second Lien DIP Notes (including the non-interest bearing EFIH Second Lien DIP Tranche B Notes) will receive additional EFIH Second Lien DIP Notes equal to 10.0% of the amount of EFIH Second Lien DIP Notes held by such holder.
	Private Letter Ruling
	The Restructuring Support and Lock-Up Agreement provides that EFH Corp. will file a request with the IRS for a private letter ruling (Private Letter Ruling) that, among other things, will provide (a) that (i) the transfer by TCEH of all of its assets and its ordinary course operating liabilities to Reorganized TCEH, (ii) the transfer by the Debtors to Reorganized TCEH of certain operating assets and liabilities that are reasonably necessary to the operation of Reorganized TCEH and (iii) the distribution by TCEH of (A) the equity it holds in Reorganized TCEH and (B) the cash proceeds TCEH receives from Reorganized TCEH to the holders of TCEH First Lien Claims, will qualify as a "reorganization" within the meaning of Sections 368(a)(1)(G) , 355 and 356 of the Code and (b) for certain other rulings under Sections 368(a)(1)(G) and 355 of the Code.
	There are various conditions precedent to the restructuring transactions under the Restructuring Support and Lock-Up Agreement including, but not limited to, the receipt of the Private Letter Ruling, requisite regulatory approvals and approvals by the Bankruptcy Court.
	Operation and Implications of the Chapter 11 Cases
	The accompanying consolidated financial statements contemplate the realization of assets and the satisfaction of liabilities in the normal course of business. Our ability to continue as a going concern is contingent upon our ability to comply with the financial and other covenants contained in the debtor-in-possession financing (DIP Facilities, described below), the Bankruptcy Court's approval of the Restructuring Plan or another Chapter 11 plan and our ability to successfully implement the Restructuring Plan or another Chapter 11 plan and obtain new financing, among other factors. As a result of the Chapter 11 Cases, the realization of assets and the satisfaction of liabilities are subject to uncertainty. While operating as debtors-in-possession under Chapter 11, the Debtors may sell or otherwise dispose of or liquidate assets or settle liabilities, subject to the approval of the Bankruptcy Court or as otherwise permitted in the ordinary course of business (and subject to restrictions contained in the DIP Facilities), for amounts other than those reflected in the accompanying consolidated financial statements. Further, the Restructuring Plan or another Chapter 11 plan could materially change and may impact the amounts and classifications of assets and liabilities reported in our consolidated financial statements.
	Financing During the Chapter 11 Cases
	See Note 5 for discussion of the TCEH DIP Facility, which provides up to $4.5 billion in senior secured, super-priority financing, the EFIH First Lien DIP Facility, which is expected to provide $5.4 billion in senior secured, super-priority financing, and the EFIH Second Lien DIP Facility, which is expected to provide $1.9 billion in secured, super-priority financing.
	Significant Bankruptcy Court Actions
	On May 1 and 2, 2014 at the first-day hearings of the Chapter 11 Cases, the Bankruptcy Court issued certain interim orders relating to the Debtors’ businesses. These orders authorized the Debtors to, among other things, enter into the TCEH DIP Facilities (described in Note 5), pay certain prepetition employee and retiree expenses and benefits, use their existing cash management system, maintain and administer customer programs primarily at TXU Energy, pay certain critical vendors, perform under certain prepetition hedging and trading arrangements and pay certain prepetition taxes and related fees. In addition, during the first-day hearings, the Bankruptcy Court set June 5 and 6, 2014 as the date for the second-day hearings in the Chapter 11 Cases. We expect that at the second-day hearings the Bankruptcy Court will consider issuing final orders related to the matters approved in the interim orders as well as certain other related matters.
	These orders are significant because they allow us to operate our businesses in the normal course.

Variable_Interest_Entities

Variable Interest Entities	3 Months Ended
	Mar. 31, 2014
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.
	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.
	Assets and liabilities of other consolidated VIEs are immaterial. 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 $6.002 billion and $5.959 billion at March 31, 2014 and December 31, 2013, 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 26% and 28% of Oncor Holdings' consolidated operating revenues for the three months ended March 31, 2014 and 2013, respectively.
	See Note 10 for discussion of Oncor Holdings' and Oncor's transactions with EFH Corp. and its other subsidiaries.
	Distributions from Oncor Holdings and Related Risks — Oncor Holdings' distributions of earnings to us totaled $37 million and $31 million for the three months ended March 31, 2014 and 2013, respectively. Distributions may not be paid except to the extent Oncor maintains a required regulatory capital structure as discussed below. At March 31, 2014, $239 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 March 31, 2014, Oncor's regulatory capitalization ratio was 58.4% debt and 41.6% 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).
	As a result of the Bankruptcy Filing, Oncor has credit risk exposure to trade accounts receivable from TCEH, which relate to delivery services provided by Oncor to TCEH's retail operations. At the Petition Date, these accounts receivable totaled $109 million, including $37 million in unbilled amounts. The accounts receivable are secured by $5 million in letters of credit posted by TCEH. Oncor has additional credit risk exposure to EFH Corp. and certain of its subsidiaries totaling approximately $20 million at the Petition Date, including an $18 million federal income tax receivable from EFH Corp. under the Federal and State Income Tax Allocation Agreement. Additional income tax receivable amounts may arise in the normal course under that agreement.
	Because Oncor would not seek regulatory rate recovery for such credit losses, Oncor's earnings could be reduced by the amount (after-tax) of any nonpayment by EFH Corp. and its subsidiaries of amounts owed to Oncor.
	Oncor has not established any reserves related to these exposures.
	Oncor Holdings Financial Statements — Condensed statements of consolidated income of Oncor Holdings and its subsidiaries for the three months ended March 31, 2014 and 2013 are presented below:
		Three Months Ended March 31,
		2014			2013
	Operating revenues	$	917		$	817
	Operation and maintenance expenses	(345		)	(298		)
	Depreciation and amortization	(210		)	(199		)
	Taxes other than income taxes	(108		)	(102		)
	Other income	4			5
	Other deductions	(3		)	(4		)
	Interest income	1			1
	Interest expense and related charges	(88		)	(94		)
	Income before income taxes	168			126
	Income tax expense	(67		)	(41		)
	Net income	101			85
	Net income attributable to noncontrolling interests	(21		)	(18		)
	Net income attributable to Oncor Holdings	$	80		$	67
	Assets and liabilities of Oncor Holdings at March 31, 2014 and December 31, 2013 are presented below:
		March 31,			December 31,
		2014			2013
	ASSETS
	Current assets:
	Cash and cash equivalents	$	32		$	28
	Restricted cash	58			52
	Trade accounts receivable — net	390			385
	Trade accounts and other receivables from affiliates	120			135
	Income taxes receivable from EFH Corp.	22			16
	Inventories	69			65
	Accumulated deferred income taxes	27			32
	Prepayments and other current assets	86			82
	Total current assets	804			795
	Restricted cash	16			16
	Other investments	91			91
	Property, plant and equipment — net	12,068			11,902
	Goodwill	4,064			4,064
	Regulatory assets — net	1,222			1,324
	Other noncurrent assets	79			71
	Total assets	$	18,344		$	18,263
	LIABILITIES
	Current liabilities:
	Short-term borrowings	$	979		$	745
	Long-term debt due currently	633			131
	Trade accounts payable — nonaffiliates	147			178
	Income taxes payable to EFH Corp.	85			23
	Accrued taxes other than income	65			169
	Accrued interest	64			95
	Other current liabilities	118			135
	Total current liabilities	2,091			1,476
	Accumulated deferred income taxes	1,901			1,905
	Long-term debt, less amounts due currently	4,852			5,381
	Other noncurrent liabilities and deferred credits	1,747			1,822
Total liabilities	$	10,591		$	10,584

Goodwill_And_Identifiable_Inta

Goodwill And Identifiable Intangible Assets	3 Months Ended
	Mar. 31, 2014
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 months ended March 31, 2014. None of the goodwill is being deducted for tax purposes.
	Goodwill before impairment charges	$	18,342
	Accumulated noncash impairment charges	(14,390		)
	Balance at March 31, 2014 and December 31, 2013	$	3,952
	Identifiable Intangible Assets
	Identifiable intangible assets, including amounts that arose in connection with accounting for the Merger, are comprised of the following:
			31-Mar-14							31-Dec-13
	Identifiable Intangible Asset		Gross			Accumulated		Net		Gross		Accumulated		Net
			Carrying			Amortization				Carrying		Amortization
			Amount							Amount
	Retail customer relationship		$	463		$	408	$	55	$	463	$	402	$	61
	Favorable purchase and sales contracts		352			145		207		352		139		213
	Capitalized in-service software		360			203		157		355		192		163
	Environmental allowances and credits		207			23		184		209		20		189
	Mining development costs		163			78		85		156		69		87
	Total identifiable intangible assets subject to amortization		$	1,545		$	857	688		$	1,535	$	822	713
	Retail trade name (not subject to amortization)							955						955
	Mineral interests (not currently subject to amortization)							9						11
	Total identifiable intangible assets							$	1,652					$	1,679
	Amortization expense related to identifiable intangible assets (including income statement line item) consisted of:
	Identifiable Intangible Asset		Income Statement Line		Segment	Three Months Ended March 31,
						2014		2013
	Retail customer relationship		Depreciation and amortization		Competitive Electric	$	6	$	6
	Favorable purchase and sales contracts		Operating revenues/fuel, purchased power costs and delivery fees		Competitive Electric	6		6
	Capitalized in-service software		Depreciation and amortization		Competitive Electric and Corporate and Other	11		10
	Environmental allowances and credits		Fuel, purchased power costs and delivery fees		Competitive Electric	4		3
	Mining development costs		Depreciation and amortization		Competitive Electric	8		8
	Total amortization expense (a)					$	35	$	33
	____________
	(a)	Amounts recorded in depreciation and amortization totaled $25 million and $24 million for the three months ended March 31, 2014 and 2013, respectively.
	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
	2014		$	134
	2015		$	123
	2016		$	101
	2017		$	78
	2018		$	58

Borrowing_Facilities_And_Debt

Borrowing Facilities And Debt	3 Months Ended
	Mar. 31, 2014
Debt and Capital Lease Obligations [Abstract]	'
Borrowing Facilities and Debt	'
	BORROWING FACILITIES AND DEBT
	Debtor-In-Possession (DIP) Facilities
	TCEH DIP Facility — In connection with the Bankruptcy Filing, TCEH received a binding commitment, subject to certain customary conditions, from certain financial institutions for a debtor-in-possession facility (the TCEH DIP Facility). The TCEH DIP Facility provides for up to $4.475 billion in financing upon entry of a final order consisting of (i) a senior secured, super-priority revolving credit facility of up to $1.95 billion, (ii) a senior secured, super-priority delayed-draw term loan in the amount of up to $1.1 billion, and (iii) a senior secured, super-priority term loan in the amount of $1.425 billion. On May 2, 2014, the Bankruptcy Court entered an interim order with respect to the TCEH DIP Facility as described below, and on May 5, 2014, the TCEH Debtors and the other parties thereto entered into the TCEH DIP Credit Agreement, which became effective on that date.
	The TCEH DIP Facility is a Senior Secured, Super-Priority Credit Agreement by and among EFCH, TCEH, and the subsidiaries of TCEH that are Debtors in the Chapter 11 Cases (the TCEH Debtors), the lenders that are party thereto from time to time and an administrative and collateral agent (the TCEH DIP Credit Agreement).
	On May 2, 2014, the Bankruptcy Court entered an interim order authorizing the TCEH Debtors to enter into the TCEH DIP Credit Agreement to borrow $2.33 billion in financing (as defined in the TCEH DIP Credit Agreement) consisting of borrowings in an aggregate principal amount of up to (a) $533 million under the revolving credit facility, (b) $1.1 billion under the delayed-draw term facility, of which up to $1.1 billion may be used for letters of credit to support mining land reclamation requirements as discussed immediately below and (c) $700 million under the term loan facility to fund general letters of credit, of which $500 million has been funded to a collateral account at this time. The interim order also authorized the TCEH Debtors to pay certain fees related to the administration of the TCEH DIP Facility. We intend to seek approval of the Bankruptcy Court to borrow all amounts allowed by the terms of the facility.
	The TCEH DIP Facility provides for a carve-out (the RCT Carve-Out) related to mining land reclamation requirements that TCEH's Luminant Mining subsidiary has with the RCT, which among other things, oversees lignite mining activity in Texas. The RCT Carve-Out will be used by Luminant Mining to secure up to $1.1 billion of its mining land reclamation obligations with the RCT.
	The principal amounts outstanding under the TCEH DIP Facility bear interest based on applicable LIBOR or base rates plus applicable margins as set forth in the TCEH DIP Facility. The TCEH DIP Facility also provides for certain additional fees payable to the agents and lenders, as well as availability fees payable with respect to any unused portions of the available TCEH DIP Facility.
	The TCEH DIP Facility will mature on the twenty-fourth month after the closing date of such facility. The maturity date may be extended to the thirtieth month after the closing date of the TCEH DIP Facility subject to the satisfaction of certain conditions, including the payment of a 25 basis points extension fee, a requirement that an acceptable plan of reorganization has been filed on or prior to such extension and the availability of certain metrics of liquidity applicable to the TCEH Debtors.
	The TCEH Debtors' obligations under the TCEH DIP Facility are secured by a lien covering substantially all of the TCEH Debtors' assets, rights and properties, subject to certain exceptions set forth in the TCEH DIP Facility. The TCEH DIP Facility provides that all obligations thereunder constitute administrative expenses in the Chapter 11 Cases, with administrative priority and senior secured status under Section 364(c) and 364(d) of the Bankruptcy Code and, subject to certain exceptions set forth in the TCEH DIP Facility, have priority over any and all administrative expense claims, unsecured claims and costs and expenses in the Chapter 11 Cases.
	The TCEH DIP Facility also permits certain hedging agreements to be secured on a pari-passu basis with the TCEH DIP Facility in the event those hedging agreements meet certain criteria set forth in the TCEH DIP Facility.
	The TCEH DIP Facility provides for affirmative and negative covenants applicable to the TCEH Debtors, including affirmative covenants requiring the TCEH Debtors to provide financial information, budgets and other information to the agents under the TCEH DIP Facility, and negative covenants restricting the TCEH Debtors' ability to incur additional indebtedness, grant liens, dispose of assets, make investments, pay dividends or take certain other actions, in each case except as permitted in the TCEH DIP Facility. The TCEH Debtors' ability to borrow under the TCEH DIP Facility is subject to the satisfaction of certain customary conditions precedent set forth therein.
	The TCEH DIP Facility provides for certain customary events of default, including events of default resulting from non-payment of principal, interest or other amounts when due, material breaches of representations and warranties, material breaches of covenants in the TCEH DIP Facility or ancillary loan documents, cross-defaults under other agreements or instruments and the entry of material judgments against the TCEH Debtors. The TCEH DIP Facility also includes an event of default that may arise from our failure to meet a consolidated super-priority leverage test. Upon the existence of an event of default, the TCEH DIP Facility provides that all principal, interest and other amounts due thereunder will become immediately due and payable, either automatically or at the election of specified lenders.
	EFIH First Lien DIP Facility — EFIH has received a binding commitment and agreements to participate, subject to certain customary conditions, for a $5.4 billion first-lien DIP facility described below (the EFIH First Lien DIP Facility). EFIH filed a motion with the Bankruptcy Court for approval of certain fees related to the EFIH First Lien DIP Facility.
	The proposed EFIH First Lien DIP Facility is a Senior Secured, Super-Priority Credit Agreement by and among the EFIH Debtors, the lenders that are party thereto from time to time and an administrative and collateral agent.
	On May 1, 2014, the Bankruptcy Court approved an interim order authorizing the EFIH Debtors to pay certain fees related to the EFIH Debtors' proposed EFIH First Lien DIP Facility in accordance with the EFIH First Lien DIP commitment letter and the EFIH First Lien DIP fee letter.
	See Note 2 for further discussion regarding the Restructuring Support and Lock-Up Agreement, the EFIH First Lien Settlement and the EFIH First Lien DIP Facility.
	The principal amounts outstanding under the EFIH First Lien DIP Facility will bear interest based on applicable LIBOR or base rates plus applicable margins as set forth in the EFIH First Lien DIP Facility. The EFIH First Lien DIP Facility also will provide for certain additional fees payable to the agents and lenders, as well as availability fees payable with respect to any unused portions of the available EFIH First Lien DIP Facility.
	The EFIH First Lien DIP Facility will mature on the twenty-fourth month after the closing date of the EFIH First Lien DIP Facility. The maturity date may be extended to the thirtieth month after the closing date of the EFIH First Lien DIP Facility subject to the satisfaction of certain conditions, including the payment of a 25 basis points extension fee, a requirement that an acceptable plan of reorganization has been filed on or prior to such extension and the availability of certain metrics of liquidity applicable to the EFIH Debtors.
	EFIH's obligations under the EFIH First Lien DIP Facility will be secured by a first lien covering substantially all of EFIH's assets, rights and properties, subject to certain exceptions set forth in the EFIH First Lien DIP Facility. The EFIH First Lien DIP Facility provides that all obligations thereunder will constitute administrative expenses in the Chapter 11 Cases, with administrative priority and senior secured state under Section 364(c) and 364(d) of the Bankruptcy Code and, subject to certain exceptions set forth in the EFIH First Lien DIP Facility, will have priority over any and all administrative expense claims, unsecured claims and costs and expenses in the Chapter 11 Cases.
	The EFIH First Lien DIP Facility will provide for affirmative and negative covenants applicable to the EFIH Debtors, including affirmative covenants requiring the EFIH Debtors to provide financial information, budgets and other information to the agents under the EFIH First Lien DIP Facility, and negative covenants restricting the EFIH Debtors' ability to incur additional indebtedness, grant liens, dispose of assets, pay dividends or take certain other actions, in each case except as permitted in the EFIH First Lien DIP Facility. EFIH's ability to borrow under the EFIH First Lien DIP Facility will be subject to the satisfaction of certain customary conditions precedent set forth therein. The Oncor Ring-Fenced Entities will not be restricted subsidiaries for purposes of the EFIH First Lien DIP Facility.
	The EFIH First Lien DIP Facility will provide for certain customary events of default, including events of default resulting from non-payment of principal, interest or other amounts when due, material breaches of representations and warranties, material breaches of covenants in the EFIH First Lien DIP Facility or ancillary loan documents, cross-defaults under other agreements or instruments and the entry of material judgments against EFIH. The EFIH First Lien DIP Facility will also include an event of default that may arise from its failure to meet a minimum liquidity test. Upon the existence of an event of default, the EFIH First Lien DIP Facility will provide that all principal, interest and other amounts due thereunder will become immediately due and payable, either automatically or at the election of specified lenders.
	EFIH Second Lien DIP Facility — The EFIH Second Lien DIP Facility will provide for a secured, super-priority term loan in the amount of $1.9 billion (with (a) an additional $95 million issued as a payment-in-kind closing fee and (b) additional amounts issued as payment-in-kind interest or a one-time fee if the Oncor TSA Amendment is not approved). The proposed EFIH Second Lien DIP Facility will be a Secured, Subordinated Super-Priority Note Purchase Agreement by and among the EFIH Debtors, the lenders that are party thereto from time to time and an administrative and collateral agent. On the Effective Date, the EFIH Second Lien DIP Notes will automatically convert (Equity Conversion) on a pro rata basis into approximately 64% of the equity interests of newly reorganized EFH Corp. (Reorganized EFH Corp.), subject to adjustment based on the principal amount of the EFIH Second Lien Notes.
	See Note 2 for further discussion of the Restructuring Support and Lock-Up Agreement, the EFIH Second Lien DIP Notes Offering and the Backstop Commitment received from certain holders of the EFIH Unsecured Notes.
	The principal amounts outstanding under the EFIH Second Lien DIP Facility will bear interest at a fixed rate of 8% per annum, subject to certain adjustments if the Bankruptcy Court has not approved the Oncor TSA Amendment within 90 days after the Petition Date.
	The EFIH Second Lien DIP Facility will mature on the twenty-fourth month after the closing date of the EFIH Second Lien DIP Facility.
	EFIH's obligations under the EFIH Second Lien DIP Facility will be secured by a second lien covering substantially all of EFIH's assets, rights and properties, subject to certain exceptions set forth in the EFIH Second Lien DIP Facility. The EFIH Second Lien DIP Facility will provide that all obligations thereunder will constitute administrative expenses in the Chapter 11 Cases, with administrative priority and senior secured state under Section 364(c) and 364(d) of the Bankruptcy Code and, subject to certain exceptions set forth in the EFIH Second Lien DIP Facility (including with respect to the EFIH First Lien DIP Facility), will have priority over any and all administrative expense claims, unsecured claims and costs and expenses in the Chapter 11 Cases.
	The EFIH Second Lien DIP Facility will provide for affirmative and negative covenants applicable to the EFIH Debtors, including affirmative covenants requiring the EFIH Debtors to provide financial information, budgets and other information to the agents under the EFIH Second Lien DIP Facility, and negative covenants restricting the EFIH Debtors' ability to incur additional indebtedness, grant liens, dispose of assets, pay dividends or take certain other actions, in each case except as permitted in the EFIH Second Lien DIP Facility. EFIH's ability to borrow under the EFIH Second Lien DIP Facility will be subject to the satisfaction of certain customary conditions precedent set forth therein. The Oncor Ring-Fenced Entities will not be restricted subsidiaries for purposes of the EFIH Second Lien DIP Facility.
	The EFIH Second Lien DIP Facility will provide for certain customary events of default, including events of default resulting from non-payment of principal, interest or other amounts when due, material breaches of representations and warranties, material breaches of covenants in the EFIH Second Lien DIP Facility or ancillary loan documents, cross-defaults under other agreements or instruments and the entry of material judgments against EFIH. Upon the existence of an event of default, the EFIH Second Lien DIP Facility will provide that all principal, interest and other amounts due thereunder will become immediately due and payable, either automatically or at the election of specified lenders.
	Borrowings Under Pre-Petition Credit Facilities
	At March 31, 2014 and December 31, 2013, outstanding borrowings totaled $2.054 billion under the TCEH Revolving Credit Facility at weighted average interest rates of 4.74% and 4.67%, respectively, excluding customary fees.
	Pre-Petition Credit Facilities at March 31, 2014
	The Bankruptcy Filing constituted an event of default under the TCEH credit facilities. Under the Bankruptcy Code, the creditors under such facilities are stayed from taking any action against the Debtors as a result of the default.
	Credit facilities and related cash borrowings at March 31, 2014 are presented below. The facilities are all senior secured facilities of TCEH.
				31-Mar-14
	Facility	Maturity		Facility				Cash			Available L/C Capacity
		Date		Limit				Borrowings
	TCEH Revolving Credit Facility (a)	Oct-16		$	2,054			$	2,054		$	—
	TCEH Letter of Credit (L/C) 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 borrowings under credit facilities. Borrowings under the facility bore interest at LIBOR plus 4.50%, and a commitment fee was payable quarterly in arrears at a rate per annum equal to 1.00% of the average daily unused portion of the facility.
	(b)	Facility, $42 million of which has a maturity date of 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 the TCEH L/C Facility have been recorded by TCEH as restricted cash that supports issuances of letters of credit.
	In the first quarter 2014, pollution control revenue bonds totaling $185 million in principal amount were tendered and the related letters of credit were drawn upon. Also in the first quarter 2014, TCEH issued a $157 million letter of credit to a subsidiary of EFH Corp. to secure its current and future amounts payable to the subsidiary arising from recurring transactions in the normal course of business, and the subsidiary drew on the letter of credit in the amount of $100 million to settle amounts receivable from TCEH. At March 31, 2014, the restricted cash totaled $660 million, a $285 million decrease from the balance at December 31, 2013 reflecting letters of credit drawn. At March 31, 2014, the restricted cash supports $656 million in letters of credit outstanding, leaving $4 million of available capacity. As a result of the Bankruptcy Filing, the available letter of credit capacity cannot be utilized. Letter of credit draws since March 31, 2014 have not been significant.
	Subsequent to the Bankruptcy Filing, $5 million of letters of credit were drawn upon by counterparties to settle amounts receivable from TCEH at the Petition Date.
	Debt
	The Bankruptcy Filing constituted an event of default under the Credit Agreement governing the TCEH Senior Secured Facilities and the indentures governing the company's other debt instruments listed below as well as capital lease obligations, and those debt obligations became immediately due and payable. As a result, the accompanying consolidated balance sheets as of March 31, 2014 and December 31, 2013 present all debt classified as current. Under the Bankruptcy Code, the creditors under these debt agreements are stayed from taking any action against the Debtors as a result of the default.
	At March 31, 2014 and December 31, 2013, notes, loans and other debt consisted of the following:
		March 31,				December 31,
		2014				2013
	EFH Corp. (parent entity)
	9.75% Fixed Senior Notes due October 15, 2019	$	2			$	2
	10% Fixed Senior Notes due January 15, 2020	3				3
	10.875% Fixed Senior Notes due November 1, 2017	33				33
	11.25% / 12.00% Senior Toggle Notes due November 1, 2017	27				27
	5.55% Fixed Series P Senior Notes due November 15, 2014 (a)	90				90
	6.50% Fixed Series Q Senior Notes due November 15, 2024 (a)	201				201
	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)	42				46
	Unamortized fair value premium related to Building Financing (b)(c)	8				9
	Unamortized fair value discount (c)	(118		)		(121		)
	Total EFH Corp.	579				581
	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				3,482
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	1,566				1,566
9.75% Fixed Senior Notes due October 15, 2019	2				2
Unamortized premium	265				284
Unamortized discount	(142		)		(146		)
Total EFIH	7,832				7,847
EFCH
9.58% Fixed Notes due in annual installments through December 4, 2019 (d)	29				29
8.254% Fixed Notes due in quarterly installments through December 31, 2021 (d)	32				34
1.038% 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)	(5		)		(6		)
Total EFCH	65				66
TCEH
Senior Secured Facilities:
3.737% TCEH Term Loan Facilities with maturity date of October 10, 2014 (e)(f)	3,809				3,809
3.736% TCEH Letter of Credit Facility with maturity date of October 10, 2014 (e)	42				42
4.737% TCEH Term Loan Facilities with maturity date of October 10, 2017 (a)(e)(f)	15,691				15,691
4.736% TCEH Letter of Credit Facility with maturity date of 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
	March 31,				December 31,
	2014				2013
10.50% / 11.25% Senior Toggle Notes due November 1, 2016	$	1,749			$	1,749
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
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
0.290% Floating Series 2001D-2 due May 1, 2033 (g)	17				97
0.393% Floating Taxable Series 2001I due December 1, 2036 (h)	2				62
—% Floating Series 2002A due May 1, 2037	—				45
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 (i)	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)	(103		)		(105		)
Other:
7.48% Fixed Secured Facility Bonds with amortizing payments through January 2017	35				36
7.46% Fixed Secured Facility Bonds with amortizing payments through January 2015	4				4
Capital leases	49				52
Other	3				3
Unamortized discount	(96		)		(103		)
Total TCEH	29,524				29,704
Total EFH Corp. consolidated	$	38,000			$	38,198
___________
(a)	Excludes the following debt held by EFIH or EFH Corp. (parent entity) and eliminated in consolidation. Pursuant to the terms of the Restructuring Support and Lock-Up Agreement, the debt is expected to be cancelled in connection with the Restructuring Plan, except for the TCEH 4.737% Term Loan Facilities.
	March 31,				December 31,
	2014				2013
EFH Corp. 5.55% Fixed Series P Senior Notes due November 15, 2014	$	281			$	281
EFH Corp. 6.50% Fixed Series Q Senior Notes due November 15, 2024	545				545
EFH Corp. 6.55% Fixed Series R Senior Notes due November 15, 2034	456				456
TCEH 4.737% 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			$	1,664
(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 March 31, 2014.
(f)	At March 31, 2014, interest rate was swapped to fixed on $18.077 billion principal amount of maturities through October 2014 and up to an aggregate $12.6 billion principal amount from October 2014 through October 2017. See discussion below regarding termination of the agreements following the Bankruptcy Filing.
(g)	Interest rates in effect at March 31, 2014. This series is in a daily interest rate mode and is supported by long-term irrevocable letters of credit.
(h)	Interest rate in effect at March 31, 2014. This series is in a weekly interest rate mode and is supported by long-term irrevocable letters of credit.
(i)	This series is in the multiannual interest rate mode and is 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.
Repayment of Debt in 2014
Repayments of debt in the three months ended March 31, 2014 totaled $191 million and consisted of $185 million of pollution control revenue bonds tendered, $3 million of payments of principal at scheduled maturity dates and $3 million of contractual payments under capital leases.
Information Regarding Other Significant Pre-Petition Debt
TCEH elected not to make interest payments due in April 2014 totaling $123 million on certain debt obligations.
TCEH Senior Secured Facilities — Borrowings under the TCEH Senior Secured Facilities totaled $22.616 billion at March 31, 2014 and consisted of:
•	$3.809 billion of TCEH Term Loan Facilities that have a maturity date in October 2014 with interest payable at LIBOR plus 3.50%;
•	$15.691 billion of TCEH Term Loan Facilities that have a maturity date in October 2017 with interest payable at LIBOR plus 4.50%, excluding $19 million aggregate principal amount held by EFH Corp.;
•	$42 million of cash borrowed under the TCEH Letter of Credit Facility that have a maturity date 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 that have a maturity date 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 represent the entire amount of commitments under the facility totaling $2.054 billion at March 31, 2014.
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 March 31, 2014, the principal amount of the TCEH 11.5% Senior Secured Notes totaled $1.750 billion. The notes have a maturity date 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.
The guarantees of the TCEH Senior Secured Notes by the Guarantors are effectively senior to any unsecured and second-priority debt of the Guarantors to the extent of the value of the TCEH Collateral. The guarantees are effectively subordinated to all debt of the Guarantors secured by assets that are not part of the TCEH Collateral, to the extent of the value of the collateral securing that debt.
TCEH 15% Senior Secured Second Lien Notes (including Series B) — At March 31, 2014, the principal amount of the TCEH 15% Senior Secured Second Lien Notes totaled $1.571 billion. These notes have a maturity date 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.
The guarantees of the TCEH Senior Secured Second Lien Notes by the Subsidiary Guarantors are effectively senior to any unsecured debt of the Subsidiary Guarantors to the extent of the value of the TCEH Collateral (after taking into account any first-priority liens on the TCEH Collateral). These guarantees are effectively subordinated to all debt of the Subsidiary Guarantors secured by the TCEH Collateral on a first-priority basis or that is secured by assets that are not part of the TCEH Collateral, to the extent of the value of the collateral securing that debt. EFCH's guarantee ranks equally with its unsecured debt (including debt it guarantees on an unsecured basis) and is effectively subordinated to any of its secured debt to the extent of the value of the collateral securing that debt.
TCEH 10.25% Senior Notes (including Series B) and 10.50%/11.25% Senior Toggle Notes (collectively, the TCEH Senior Notes) — At March 31, 2014, 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 have a maturity date 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 have a maturity date 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 March 31, 2014, the principal amount of the EFIH 6.875% Notes totaled $503 million. These notes have a maturity date 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.
There currently are no restricted subsidiaries under the indenture related to the EFIH 6.875% Notes (other than EFIH Finance, which has no assets). Oncor Holdings, the immediate parent of Oncor, and its subsidiaries are unrestricted subsidiaries under the indenture and, accordingly, are not subject to any of the restrictive covenants in the indenture.
The EFIH 6.875% Notes were issued in private placements and are not registered under the Securities Act. EFIH had 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 was not completed, the annual interest rate on the EFIH 6.875% Notes increased by 25 basis points (to 7.125%) on August 15, 2013 and by an additional 25 basis points (to 7.375%) on November 15, 2013.
EFIH 10% Senior Secured Notes — At March 31, 2014, the principal amount of the EFIH 10% Notes totaled $3.482 billion. The notes have a maturity date 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 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.
The $1.302 billion of EFIH 10% Notes issued in January 2013 were issued in private placements and are not registered under the Securities Act. EFIH had agreed to use its commercially reasonable efforts to register with the SEC notes having substantially identical terms as the EFIH 10% 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 10% Notes. Because the exchange offer was not completed, the annual interest rate on the EFIH 10% Notes increased by 25 basis points (to 10.25%) on January 30, 2014 and by an additional 25 basis points (to 10.50%) on April 30, 2014.
EFIH 11% Senior Secured Second Lien Notes — At March 31, 2014, the principal amount of the EFIH 11% Notes totaled $406 million. The notes have a maturity date 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 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 March 31, 2014, the principal amount of the EFIH 11.75% Notes totaled $1.750 billion. These notes have a maturity date 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 had 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 was not completed, the annual interest rate on the EFIH 11.75% Notes increased by 25 basis points (to 12.00%) on February 6, 2013 and by an additional 25 basis points (to 12.25%) on May 6, 2013.
EFIH 11.25%/12.25% Senior Toggle Notes — At March 31, 2014, the principal amount of the EFIH Toggle Notes totaled $1.566 billion. These notes have a maturity date 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. The terms of the Toggle Notes include an election by EFIH, for any interest period until June 1, 2016, 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. EFIH made its 2013 interest payments on the EFIH Toggle Notes by using the PIK feature of those notes.
The EFIH Toggle Notes were issued in private placements and are not registered under the Securities Act. EFIH had 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. Because the exchange offer was not completed, the annual interest rate on the EFIH Toggle Notes increased by 25 basis points (to 11.50%) on December 6, 2013 and by an additional 25 basis points (to 11.75%) on March 6, 2014.
EFH Corp. 10.875% Senior Notes and 11.25%/12.00% Senior Toggle Notes — At March 31, 2014, 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 have a maturity date 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.
Material Cross Default/Acceleration Provisions — Certain of our financing arrangements contain provisions that result in an event of default if there were a failure under other financing arrangements to meet payment terms or to observe other covenants that could or does result in an acceleration of payments due. Such provisions are referred to as "cross default" or "cross acceleration" provisions. The Bankruptcy Filing triggered defaults on our debt obligations, but pursuant to the Bankruptcy Code, the creditors are stayed from taking any actions against the Debtors as a result of such defaults.
Fair Value of Debt
At March 31, 2014 and December 31, 2013, the estimated fair value of our notes, loans and other debt (excluding capital leases) totaled $24.834 billion and $24.653 billion, respectively, and the carrying amount totaled $37.951 billion and $38.146 billion, respectively. At March 31, 2014 and December 31, 2013, the estimated fair value of our borrowings under the TCEH Revolving Credit Facilities totaled $1.458 billion and $1.397 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 March 31, 2014, 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 has employed interest rate swaps to hedge exposure to its variable rate debt. As reflected in the table below, at March 31, 2014, TCEH had entered into the following series of interest rate swap transactions that effectively fixed the interest rates at between 5.5% and 9.3%.
Fixed Rates					Expiration Dates		Notional Amount
5.5	%	-	9.30%		Oct-14			$	18.077	billion (a)
6.8	%	-	9.00%		October 2015 through October 2017			$	12.6	billion (b)
___________
(a)	Swaps related to an aggregate $1.5 billion principal amount of debt expired in 2014. Per the terms of the transactions, the notional amount of swaps entered into in 2011 grew by $1.388 billion in 2014, substantially offsetting the expired swaps.
(b)	These swaps were effective from October 2014 through October 2017. The $12.6 billion notional amount of swaps included $3 billion that expire in October 2015 with the remainder expiring in October 2017.
TCEH had also entered into interest rate basis swap transactions that further reduced the fixed borrowing costs achieved through the interest rate swaps. Basis swaps in effect at March 31, 2014 totaled $1.05 billion notional amount. The remaining basis swaps had expiration dates in August 2014.
The interest rate swaps have resulted in realized and unrealized net gains (losses), reported in interest expense and related charges, as follows:
	Three Months Ended March 31,
	2014				2013
Realized net loss	$	(145	)		$	(151	)
Unrealized net gain	64				148
Total	$	(81	)		$	(3	)
The cumulative unrealized mark-to-market net liability related to all TCEH interest rate swaps totaled $948 million and $1.012 billion at March 31, 2014 and December 31, 2013, respectively, of which $55 million and $56 million (both pretax), respectively, were reported in accumulated other comprehensive income. The net liability reflects a nonperformance risk adjustment as discussed in Note 8.
These instruments are deemed to be "forward contracts" under the Bankruptcy Code. The Bankruptcy Filing constituted an event of default under the interest rate swap agreements, and in accordance with the contractual terms, the counterparties terminated all the TCEH agreements shortly after the Bankruptcy Filing. All of the TCEH interest rate swaps were 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 9 for discussion of classification of the interest rate swap derivative liabilities as current and the estimated net settlement liability resulting from the terminations.

Commitments_And_Contingencies

Commitments And Contingencies	3 Months Ended
	Mar. 31, 2014
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 March 31, 2014, TCEH had outstanding letters of credit under its credit facilities totaling $656 million as follows:
	•	$350 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;
	•	$20 million to support floating rate pollution control revenue bond debt with an aggregate principal amount of $19 million;
	•	$61 million to support TCEH's REP financial requirements with the PUCT, and
	•	$225 million for miscellaneous credit support requirements.
	The Bankruptcy Filing may result in some or all letter of credit beneficiaries drawing on their letters of credit if the terms of a particular letter of credit so provide. The automatic stay under the Bankruptcy Code does not apply to letters of credit and third parties may draw on their letters of credit. See Note 5 for discussion of letter of credit draws in 2014.
	Litigation
	Aurelius Capital Master, Ltd. and ACP Master, Ltd. (Aurelius) filed a lawsuit in March 2013, amended in May 2013, in the US 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 alleged 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 sought recovery for the benefit of EFCH. EFCH and the directors filed a motion to dismiss this lawsuit in June 2013. In January 2014, the district court granted the motion to dismiss and in February 2014 entered final judgment dismissing the lawsuit. Aurelius has appealed the district court's judgment to the US Court of Appeals for the Fifth Circuit (Fifth Circuit 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. Oral argument was held in April 2014. 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 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 (a wholly owned subsidiary of TCEH) for alleged violations of the Clean Air Act (CAA) at Luminant's Big Brown generation facility. The Big Brown trial was held in February 2014. In pre-trial filings submitted in January 2014, the Sierra Club stated it was seeking over $337 million in civil penalties for the alleged violations and injunctive relief. In March 2014, the district court entered final judgment denying all of the Sierra Club's claims and all relief requested by the Sierra Club. The Sierra Club has appealed the district court's decision to the Fifth Circuit Court.
	In September 2010, the Sierra Club filed a lawsuit in the US District Court for the Eastern District of Texas (Texarkana Division) against EFH Corp. and Luminant Generation Company LLC for alleged violations of the CAA at Luminant's Martin Lake generation facility. In April 2014, the Martin Lake trial setting of May 2014 was vacated by the district court so that the district court could consider the effects of the decision in the Big Brown case. The Sierra Club has stated that it intends to ask the district court in this case to impose civil penalties of approximately $147 million. The Sierra Club has also stated that the district court can impose the maximum civil penalties available under the CAA to the government of up to $32,500 to $37,500 per day for each alleged violation depending on the date of the alleged violation. In addition, the Sierra Club has requested injunctive relief, including the installation of new emissions control equipment at the plant. An adverse outcome could require substantial capital expenditures that cannot be determined at this time and could possibly require payment of substantial penalties. While we are unable to estimate any possible loss or predict the outcome of the Martin Lake case, we believe that, as the judge ruled in the Big Brown case, the Sierra Club's claims are without merit, and we intend to vigorously defend the lawsuit.
	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.
	Notwithstanding the foregoing, the affirmative claims asserted against EFH Corp. and Luminant Generation Company LLC described above were automatically stayed as a result of the Bankruptcy Filing. The matters will be subject to resolution in accordance with the Bankruptcy Code and the orders of the Bankruptcy Court.
	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 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 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. The consolidated cases are now fully briefed and before the Fifth Circuit Court. Oral argument has been scheduled for June 2014.
	In August 2013, the US 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. In January 2014, the district court granted our motion to stay the lawsuit until the Fifth Circuit Court resolves our petitions for 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 against these allegations. The lawsuit requests civil penalties of up to $32,500 to $37,500 per day for each alleged violation (the maximum penalties available under the CAA), depending on the date of the alleged violation, and injunctive relief, including an order requiring the installation of best available control technology at the affected units. An adverse outcome could require substantial capital expenditures that cannot be determined at this time and could possibly require the payment of substantial penalties. 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's decision. The US Supreme Court granted review of the D.C. Circuit Court's decision in June 2013 and heard oral arguments in December 2013. In April 2014, the US Supreme Court issued its opinion in the CSAPR litigation, reversing the D.C. Circuit Court's decision in which that court vacated CSAPR. The US Supreme Court has remanded the case to the D.C. Circuit Court for further proceedings consistent with its opinion. We are evaluating the decision and cannot predict the timing or outcome of future proceedings related to CSAPR, including any compliance timeframe or the financial effects, if any.
	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. In February 2014, the Fifth Circuit Court ordered the EPA to issue a final rule on the standard permit for pollution control projects by May 19, 2014. We cannot predict the outcome of the EPA's reconsideration, including the financial effects, if any.
	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	3 Months Ended
	Mar. 31, 2014
Stockholders' Equity Note [Abstract]	'
Equity	'
	EQUITY
	Dividend Restrictions
	EFH Corp. has not declared or paid any dividends since the Merger.
	Under applicable law, we are 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. In addition, due to the Bankruptcy Filing, no dividends are eligible to be paid without the approval of the Bankruptcy Court.
	Noncontrolling Interests
	As discussed in Note 3, we consolidate certain VIEs, which results in a noncontrolling interests component of equity. Net loss attributable to the noncontrolling interests was immaterial for the three months ended March 31, 2014 and 2013.
	Equity
	The following table presents the changes to equity for the three months ended March 31, 2014:
		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, 2013	$	2		$	7,962		$	(21,157	)	$	(63	)	$	1		$	(13,255	)
	Net loss	—			—			(609		)	—			—			(609		)
	Effects of stock-based incentive compensation plans	—			2			—			—			—			2
	Change in unrecognized losses related to pension and OPEB plans (Note 10)	—			—			—			(1		)	—			(1		)
	Investment by noncontrolling interests	—			—			—			—			1			1
	Other	—			—			—			—			(2		)	(2		)
	Balance at March 31, 2014	$	2		$	7,964		$	(21,766	)	$	(64	)	$	—		$	(13,864	)
	____________
	(a)	Authorized shares totaled 2,000,000,000 at March 31, 2014. Outstanding shares totaled 1,669,861,383 and 1,669,861,383 at March 31, 2014 and December 31, 2013, respectively.
	The following table presents the changes to equity for the three months ended March 31, 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	—			—			(569		)	—			—			(569		)
	Effects of stock-based incentive compensation plans	—			2			—			—			—			2
	Change in unrecognized losses related to pension and OPEB plans	—			—			—			(2		)	—			(2		)
	Net effects of cash flow hedges	—			—			—			2			—			2
	Net effects related to Oncor	—			—			—			1			—			1
	Investment by noncontrolling interests	—			—			—			—			1			1
	Balance at March 31, 2013	$	2		$	7,961		$	(19,508	)	$	(46	)	$	103		$	(11,488	)
	____________
	(a)	Authorized shares totaled 2,000,000,000 at March 31, 2013. Outstanding shares totaled 1,681,908,837 and 1,680,539,245 at March 31, 2013 and December 31, 2012, respectively.
	Accumulated Other Comprehensive Income (Loss)
	The following table presents the changes to accumulated other comprehensive income (loss) for the three months ended March 31, 2014. 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, 2013	$	(56	)	$	(7	)	$	(63	)
	Amounts reclassified from accumulated other comprehensive income (loss) and reported in:
	Operating costs	—			(1		)	(1		)
	Depreciation and amortization	(1		)	—			(1		)
	Selling, general and administrative expenses	—			(1		)	(1		)
	Interest expense and related charges	1			—			1
	Income tax benefit (expense)	—			1			1
	Equity in earnings of unconsolidated subsidiaries	—			—			—
	Total amount reclassified from accumulated other comprehensive income (loss) during the period	—			(1		)	(1		)
	Balance at March 31, 2014	$	(56	)	$	(8	)	$	(64	)
	The following table presents the changes to accumulated other comprehensive income (loss) for the three months ended March 31, 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	—			(1		)	(1		)
	Selling, general and administrative expenses	—			(1		)	(1		)
	Interest expense and related charges	4			—			4
	Income tax benefit (expense)	(1		)	1			—
	Equity in earnings of unconsolidated subsidiaries	—			(1		)	(1		)
	Total amount reclassified from accumulated other comprehensive income (loss) during the period	3			(2		)	1
	Balance at March 31, 2013	$	(61	)	$	15		$	(46	)

Fair_Value_Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2014
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 debt 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 on a recurring basis consisted of the following:
	31-Mar-14
		Level 1			Level 2				Level 3 (a)				Total
	Assets:
	Commodity contracts	$	169		$	394			$	64			$	627
	Interest rate swaps	—			69				—				69
	Nuclear decommissioning trust – equity securities (b)	336			194				—				530
	Nuclear decommissioning trust – debt securities (b)	—			280				—				280
	Total assets	$	505		$	937			$	64			$	1,506
	Liabilities:
	Commodity contracts	$	284		$	41			$	13			$	338
	Interest rate swaps	—			81				948				1,029
	Total liabilities	$	284		$	122			$	961			$	1,367
	31-Dec-13
		Level 1			Level 2				Level 3 (a)				Total
	Assets:
	Commodity contracts	$	161		$	570			$	57			$	788
	Interest rate swaps	—			67				—				67
	Nuclear decommissioning trust – equity securities (b)	330			191				—				521
	Nuclear decommissioning trust – debt securities (b)	—			270				—				270
	Total assets	$	491		$	1,098			$	57			$	1,646
	Liabilities:
	Commodity contracts	$	231		$	14			$	18			$	263
	Interest rate swaps	—			80				1,012				1,092
	Total liabilities	$	231		$	94			$	1,030			$	1,355
	____________
	(a)	See table below for description of Level 3 assets and liabilities.
	(b)	The nuclear decommissioning trust investment is included in the other investments line in the balance sheet. See Note 12.
	Commodity contracts consist primarily of natural gas, electricity, fuel oil, uranium and coal agreements and include financial instruments entered into for hedging purposes as well as physical contracts that have not been designated "normal" purchases or sales. See Note 9 for further discussion regarding derivative instruments, including the termination of certain natural gas hedging agreements shortly after the Bankruptcy Filing.
	Interest rate swaps included variable-to-fixed rate swap instruments that hedged the interest costs of our debt as well as interest rate basis swaps designed to effectively reduce the hedged borrowing costs. See Notes 5 and 9 for discussion of the termination of interest rate swaps shortly after the Bankruptcy Filing.
	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 months ended March 31, 2014 and 2013. 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 for the three months ended March 31, 2014 and 2013.
	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 March 31, 2014 and December 31, 2013:
	31-Mar-14
			Fair Value
	Contract Type (a)		Assets			Liabilities				Total				Valuation Technique	Significant Unobservable Input	Range (b)
	Electricity purchases and sales		$	1		$	(1	)		$	—			Valuation Model	Illiquid pricing locations (c)	$35 to $45/ MWh
															Hourly price curve shape (d)	$20 to $70/ MWh
	Electricity spread options		16			(2		)		14				Option Pricing Model	Gas to power correlation (e)	45% to 95%
															Power volatility (f)	10% to 30%
	Electricity congestion revenue rights		39			(3		)		36				Market Approach (g)	Illiquid price differences between settlement points (h)	$0.00 to $25.00
	Coal purchases		2			(6		)		(4		)		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		—			(948		)		(948		)		Valuation Model	Nonperformance risk adjustment (l)	20% to 30%
	Other (m)		6			(1		)		5
	Total		$	64		$	(961	)		$	(897	)
	31-Dec-13
			Fair Value
	Contract Type (a)		Assets			Liabilities				Total				Valuation Technique	Significant Unobservable Input	Range (b)
Electricity purchases and sales		$	2		$	(2	)		$	—			Valuation Model	Illiquid pricing locations (c)	$25 to $45/ MWh
														Hourly price curve shape (d)	$20 to $70/ MWh
Electricity spread options		15			(2		)		13				Option Pricing Model	Gas to power correlation (e)	45% to 95%
														Power volatility (f)	10% to 30%
Electricity congestion revenue rights		35			(2		)		33				Market Approach (g)	Illiquid price differences between settlement points (h)	$0.00 to $25.00
Coal purchases		—			(11		)		(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		—			(1,012		)		(1,012		)		Valuation Model	Nonperformance risk adjustment (l)	25% to 35%
Other (m)		5			(1		)		4
Total		$	57		$	(1,030	)		$	(973	)
____________
(a)	Electricity purchase and sales contracts include 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 were held by TCEH to hedge exposure to its variable rate debt (see Note 5).
(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 debt trading values. See discussion immediately below regarding Level 3 liabilities.
(m)	Other contracts include various transactions such as ancillary services, natural gas, diesel options and coal options.
The following table presents the changes in fair value of the Level 3 assets and liabilities for the three months ended March 31, 2014 and 2013. The Level 3 net liability balance at March 31, 2014 reflects a nonperformance risk adjustment in the valuation of the TCEH interest rate swaps, which were 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 March 31, 2014, the estimated fair value of these interest rate swaps totaled $1.252 billion before consideration of nonperformance risk adjustment and $948 million 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 March 31,
	2014			2013
Net asset (liability) balance at beginning of period	$	(973	)	$	29
Total unrealized valuation gains (losses)	(85		)	9
Purchases, issuances and settlements (a):
Purchases	9			4
Issuances	(1		)	—
Settlements	151			16
Transfers into Level 3 (b)	—			1
Transfers out of Level 3 (b)	2			—
Net change (c)	76			30
Net asset (liability) balance at end of period	$	(897	)	$	59
Unrealized valuation gains (losses) relating to instruments held at end of period	$	(71	)	$	14
____________
(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 in 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 loss from commodity hedging and trading activities. Changes in values of interest rate swaps transferred into Level 3 in third quarter 2013 are reported in the income statement in interest expense and related charges. Activity excludes changes in fair value in the month the positions 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	3 Months Ended
	Mar. 31, 2014
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 natural gas hedging positions and the hedging of interest costs on our debt. See Note 8 for a discussion of the fair value of derivatives. Because certain of these instruments are deemed to be "forward contracts" under the Bankruptcy Code, they are not subject to the automatic stay, and counterparties may elect to terminate the agreements.
	Commodity Hedging and Trading Activity — TCEH has natural gas hedging positions 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. TCEH has entered into market transactions involving natural gas-related financial instruments and has sold forward natural gas through 2014 in order to hedge a portion of electricity price exposure related to expected lignite/coal and nuclear fueled generation. TCEH also enters into derivatives, including electricity, natural gas, fuel oil, uranium, emission and coal instruments, generally for short-term hedging purposes. To a limited extent, TCEH also enters into derivative transactions for proprietary trading purposes, principally in natural gas and electricity markets. Unrealized gains and losses arising from changes in the fair value of hedging and trading instruments 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 have been 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 were 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.
	Termination of Commodity Hedges and Interest Rate Swaps — These instruments are deemed to be "forward contracts" under the Bankruptcy Code. The Bankruptcy Filing constituted an event of default under the related agreements, and in accordance with the contractual terms, counterparties terminated certain positions shortly after the Bankruptcy Filing. The positions terminated consisted almost entirely of natural gas hedging positions and interest rate swaps that were 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. The terminated natural gas hedging positions represented approximately 60% of the derivative assets and the terminated interest rate swaps represented substantially all of the interest rate swap derivative liabilities as of March 31, 2014 as presented in the table below.
	Entities with a first-lien security interest included counterparties to both our natural gas hedging positions and interest rate swaps, which had entered into master agreements that provided for netting and setoff of amounts related to these positions, as well as counterparties to only our interest rate swaps. While the amount has not yet been finalized, the preliminary estimate of the net settlement liability resulting from the terminations totals approximately $1.2 billion. The estimated net liability is subject to the terms of settlement of TCEH's first-lien claims ultimately approved by the Bankruptcy Court. See Note 2 for discussion of the Restructuring Support and Lock-Up Agreement.
	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 March 31, 2014 and December 31, 2013:
	31-Mar-14
		Derivative assets								Derivative liabilities
		Commodity contracts				Interest rate swaps				Commodity contracts				Interest rate swaps				Total
	Current assets	$	617			$	69			$	—			$	—			$	686
	Noncurrent assets	10				—				—				—				10
	Current liabilities	—				—				(338		)		(1,029		)		(1,367		)
	Net assets (liabilities)	$	627			$	69			$	(338	)		$	(1,029	)		$	(671	)
	31-Dec-13
		Derivative assets								Derivative liabilities
		Commodity contracts				Interest rate swaps				Commodity contracts				Interest rate swaps				Total
	Current assets	$	784			$	67			$	—			$	—			$	851
	Noncurrent assets	4				—				—				—				4
	Current liabilities	—				—				(263		)		(1,092		)		(1,355		)
	Net assets (liabilities)	$	788			$	67			$	(263	)		$	(1,092	)		$	(500	)
	In consideration of the termination rights of counterparties arising from the Bankruptcy Filing, derivative liabilities classified as current at March 31, 2014 and December 31, 2013 include $593 million and $647 million, respectively, that otherwise would be classified as noncurrent, essentially all of which relates to interest rate swaps.
	At March 31, 2014 and December 31, 2013, 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 March 31,
	Derivative (income statement presentation)		2014				2013
	Commodity contracts (Net gain (loss) from commodity hedging and trading activities) (a)		$	(179	)		$	(200	)
	Interest rate swaps (Interest expense and related charges) (b)		(82		)		(3		)
	Net gain (loss)		$	(261	)		$	(203	)
	____________
	(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 12).
	The pretax effect (all losses) on net income and other comprehensive income (OCI) of derivative instruments previously accounted for as cash flow hedges was immaterial in both the three months ended March 31, 2014 and 2013. There were no amounts recognized in OCI for the three months ended March 31, 2014 and 2013.
	Accumulated other comprehensive income related to cash flow hedges (excluding Oncor's interest rate hedge) totaled $37 million in net losses (after-tax) at both March 31, 2014 and December 31, 2013, substantially all of which relates to interest rate swaps previously accounted for as cash flow hedges. We expect that $1 million of net losses (after-tax) related to cash flow hedges included in accumulated other comprehensive income at March 31, 2014 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. We may enter into offsetting positions with the same counterparty, resulting in both assets and liabilities. Volatility in underlying commodity prices can result in significant changes in assets and liabilities 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 March 31, 2014 and December 31, 2013, 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 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.
	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:
	31-Mar-14
			Amounts Presented in Balance Sheet				Offsetting Instruments (a)				Financial Collateral (Received) Pledged (b)				Net Amounts
	Derivative assets:
	Commodity contracts		$	627			$	(334	)		$	(201	)		$	92
	Interest rate swaps		69				(69		)		—				—
	Total derivative assets		696				(403		)		(201		)		92
	Derivative liabilities:
	Commodity contracts		(338		)		181				114				(43		)
	Interest rate swaps		(1,029		)		222				—				(807		)
	Total derivative liabilities		(1,367		)		403				114				(850		)
	Net amounts		$	(671	)		$	—			$	(87	)		$	(758	)
	31-Dec-13
			Amounts Presented in Balance Sheet				Offsetting Instruments (a)				Financial Collateral (Received) Pledged (b)				Net Amounts
	Derivative assets:
	Commodity contracts		$	788			$	(389	)		$	(299	)		$	100
	Interest rate swaps		67				(67		)		—				—
	Total derivative assets		855				(456		)		(299		)		100
	Derivative liabilities:
	Commodity contracts		(263		)		168				70				(25		)
	Interest rate swaps		(1,092		)		288				—				(804		)
	Total derivative liabilities		(1,355		)		456				70				(829		)
	Net amounts		$	(500	)		$	—			$	(229	)		$	(729	)
____________
(a)	Offsetting 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.
Derivative Volumes
The following table presents the gross notional amounts of derivative volumes at March 31, 2014 and December 31, 2013:
		31-Mar-14				31-Dec-13
Derivative type		Notional Volume								Unit of Measure
Interest rate swaps:
Floating/fixed (a)		$	32,377			$	32,490			Million US dollars
Basis		$	1,050			$	1,050			Million US dollars
Natural gas (b)		2,282				2,150				Million MMBtu
Electricity		14,541				16,482				GWh
Congestion Revenue Rights (c)		80,702				77,799				GWh
Coal		12				9				Million US tons
Fuel oil		27				26				Million gallons
Uranium		450				450				Thousand pounds
____________
(a)	Includes notional amount of interest rate swaps that had maturity dates through October 2014 as well as notional amount of swaps effective from October 2014 that had maturity dates through October 2017 (see Note 5).
(b)	Represents gross notional forward sales, purchases and options transactions, locational basis swaps and other natural gas transactions.
(c)	Represents gross forward purchases associated with instruments used to hedge electricity price differences between settlement points within ERCOT.
See discussion above regarding termination of natural gas hedging and interest rate swap agreements shortly after the Bankruptcy Filing.
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 have already been effective.
At March 31, 2014 and December 31, 2013, the fair value of liabilities related to derivative instruments under agreements with credit risk-related contingent features that were not fully collateralized totaled $8 million and $4 million, respectively. The liquidity exposure associated with these liabilities was reduced by cash and letter of credit postings with the counterparties totaling $7 million and $3 million at March 31, 2014 and December 31, 2013, respectively. All of the credit risk-related contingent features related to these derivatives were triggered upon the Bankruptcy Filing.
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 as a result of the Bankruptcy Filing. At March 31, 2014 and December 31, 2013, the fair value of derivative liabilities subject to such cross-default provisions, largely related to interest rate swaps, totaled $1.052 billion and $1.103 billion, respectively, before consideration of the amount of assets subject to the liens. The liquidity exposure associated with these liabilities, when reduced by cash and letter of credit postings with the counterparties and derivative assets under netting arrangements, and excluding the nonperformance risk adjustment, totaled $1.112 billion and $1.154 billion at March 31, 2014 and December 31, 2013, respectively. All of the credit risk-related contingent features related to these derivatives, including amounts related to cross-default provisions, were triggered upon the Bankruptcy Filing. 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 $1.060 billion and $1.107 billion at March 31, 2014 and December 31, 2013, 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.
See discussion at beginning of this note regarding termination of commodity hedges and interest rate swaps.
Concentrations of Credit Risk Related to Derivatives
We have concentrations of credit risk with the counterparties to our derivative contracts. At March 31, 2014, total credit risk exposure to all counterparties related to derivative contracts totaled $800 million (including associated accounts receivable). The net exposure to those counterparties totaled $176 million at March 31, 2014 after taking into effect netting arrangements, setoff provisions and collateral, with the largest net exposure to a single counterparty totaling $45 million. At March 31, 2014, the credit risk exposure to the banking and financial sector represented 86% of the total credit risk exposure and 43% of the net exposure, a significant amount of which is related to the natural gas hedging positions. The termination of natural gas hedging agreements by counterparties shortly after the Bankruptcy Filing did not significantly affect the net credit risk exposure amount presented.
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.

Related_Party_Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2014
Related Party Transactions [Abstract]	'
Related Party Transactions	'
	RELATED PARTY TRANSACTIONS
	The following represent our significant related-party transactions.
	•	On a quarterly basis, we have paid a management fee to the Sponsor Group under the terms of a management agreement. Related amounts expensed and reported as SG&A expense totaled $10 million for both the three months ended March 31, 2014 and 2013. No payments were made in the three months ended March 31, 2014, while payments totaled $10 million for the three months ended March 31, 2013. Beginning with the quarterly management fee due December 31, 2013, the Sponsor Group, while reserving the right to receive the fees, directed EFH Corp. to suspend payments of the management fees for an indefinite period.
	•	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.
	•	Affiliates of GS Capital Partners were 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 for EFH Corp. 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.
	•	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 March 31, 2014, EFIH held $1.282 billion principal amount of EFH Corp. debt and $79 million principal amount of TCEH debt. At March 31, 2014, EFH Corp. held $303 million principal amount of TCEH debt. In the first quarter 2013, EFIH distributed 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.
	•	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 $241 million and $225 million for the three months ended March 31, 2014 and 2013, respectively. The fees are based on rates regulated by the PUCT that apply to all REPs. The balance sheets at March 31, 2014 and December 31, 2013 reflect amounts due currently to Oncor totaling $120 million and $135 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 Federal and State Income Tax Allocation Agreement.
	•	A subsidiary of EFH Corp. bills Oncor for financial and other administrative services and shared facilities at cost. Such amounts reduced reported SG&A expense by $9 million and $8 million for the three months ended March 31, 2014 and 2013, respectively.
	•	A subsidiary of EFH Corp. bills TCEH subsidiaries for information technology, financial, accounting and other administrative services at cost. These charges totaled $56 million and $62 million for the three months ended March 31, 2014 and 2013, respectively.
	•	See Note 5 for discussion of a letter of credit issued by TCEH in 2014 to a subsidiary of EFH Corp. to secure its amounts payable to the subsidiary arising from recurring transactions in the normal course.
	•	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 $4 million for both the three months ended March 31, 2014 and 2013. 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 March 31, 2014 and December 31, 2013, the excess of the trust fund balance over the decommissioning liability resulted in a payable totaling $413 million and $400 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 Federal and State Income Tax Allocation 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 March 31, 2014, our current amount receivable from Oncor Holdings related to federal and state income taxes (included in net payables due to unconsolidated subsidiary) totaled $63 million, which included $61 million receivable from Oncor. The receivable from Oncor consists of a $51 million federal income tax receivable and $28 million state margin tax receivable net of an $18 million federal income tax payable. At December 31, 2013, our current amount receivable totaled $7 million, which included $5 million receivable from Oncor. The receivable from Oncor represents a $23 million state margin tax receivable net of an $18 million federal income tax payable.
	For the three months ended March 31, 2014 and 2013, EFH Corp. received income tax payments from Oncor Holdings totaling $5 million and $9 million, respectively. EFH Corp. received no income tax payments from Oncor for the three months ended March 31, 2014 and 2013.
	•	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 both March 31, 2014 and December 31, 2013, TCEH had posted letters of credit in the amount of $9 million for the benefit of Oncor.
	•	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 March 31, 2014 and December 31, 2013, the receivable amounts totaled $845 million and $838 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. Net amounts of pension and OPEB expenses recognized in the three months ended March 31, 2014 and 2013 are not material.
	•	In the first quarter 2014, a cash contribution totaling $84 million was made to the EFH Corp. retirement plan assets, of which $64 million was contributed by Oncor and $20 million was contributed by TCEH, which resulted in the EFH Corp. retirement plan being fully funded as calculated under the provisions of ERISA. As a result of the Bankruptcy Filing, participants in the EFH Corp. retirement plan who choose to retire would not be eligible for the lump sum payout option under the retirement plan unless the EFH Corp. retirement plan is fully funded. The payment by TCEH was accounted for as an advance to EFH Corp. that will be settled as pension and OPEB expenses are allocated to TCEH in the normal course.
	•	In the second quarter 2014, Oncor and EFH Corp. entered into an agreement whereby Oncor will cease participation in EFH Corp.’s OPEB Plan and establish its own OPEB plan for Oncor’s eligible retirees and their dependents effective July 1, 2014. Participants in the EFH Corp. OPEB plan with split service will become participants in the Oncor plan. The methodology for OPEB cost allocations between EFH Corp. and Oncor is not expected to change, and the agreement is not expected to have a material effect on the net assets or cash flows of EFH Corp.
	•	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	3 Months Ended
	Mar. 31, 2014
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 3 for discussion of the reporting of Oncor Holdings and, accordingly, the Regulated Delivery segment, as an equity method investment. See Note 10 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 2013 Form 10-K. Our chief operating decision maker uses more than one measure to assess segment performance, including reported segment net income (loss), which is the measure most comparable to consolidated net income (loss) prepared based on GAAP. 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. Certain shared services costs are allocated to the segments.
		Three Months Ended March 31,
		2014			2013
	Operating revenues (all Competitive Electric)	$	1,517		$	1,260
	Equity in earnings of unconsolidated subsidiaries (net of tax) — Regulated Delivery (net of noncontrolling interest of $21 and $17)	$	80		$	67
	Net income (loss):
	Competitive Electric	$	(567	)	$	(547	)
	Regulated Delivery	80			67
	Corporate and Other	(122		)	(89		)
	Consolidated	$	(609	)	$	(569	)

Supplementary_Financial_Inform

Supplementary Financial Information	3 Months Ended
	Mar. 31, 2014
Supplementary Financial Information [Abstract]	'
Supplementary Financial Information	'
	SUPPLEMENTARY FINANCIAL INFORMATION
	Other Income and Deductions
		Three Months Ended March 31,
		2014			2013
	Other income:
	Office space rental income (a)	$	3		$	3
	Insurance/litigation settlements (b)	—			2
	All other	6			3
	Total other income	$	9		$	8
	Other deductions:
	Ongoing employee retirement benefit expense related to discontinued businesses (a)	$	—		$	(1	)
	All other	—			4
	Total other deductions	$	—		$	3
	____________
	(a)	Reported in Corporate and Other.
	(b)	Reported in Competitive Electric segment.
	Interest Expense and Related Charges
		Three Months Ended March 31,
		2014			2013
	Interest paid/accrued (including net amounts settled/accrued under interest rate swaps)	$	831		$	839
	Interest expense on toggle notes payable in additional principal (Note 5)	49			41
	Unrealized mark-to-market net (gain) loss on interest rate swaps (a)	(65		)	(150		)
	Amortization of interest rate swap losses at dedesignation of hedge accounting	(1		)	2
	Amortization of fair value debt discounts resulting from purchase accounting	5			5
	Amortization of debt issuance, amendment and extension costs and discounts	51			54
	Capitalized interest	(7		)	(7		)
	Total interest expense and related charges	$	863		$	784
	____________
	(a)	Three months ended March 31, 2014 and 2013 amounts include net gains totaling $64 million and $148 million, respectively, related to TCEH swaps (see Note 5) and net gains totaling $1 million and $2 million, respectively, related to EFH Corp. swaps substantially closed through offsetting positions.
	Restricted Cash
		31-Mar-14						31-Dec-13
		Current			Noncurrent Assets			Current			Noncurrent Assets
		Assets						Assets
	Amounts related to TCEH's Letter of Credit Facility (Note 5) (a)	$	660		$	—		$	945		$	—
	Other	4			—			4			—
	Total restricted cash	$	664		$	—		$	949		$	—
	____________
	(a)	At both March 31, 2014 and December 31, 2013, in consideration of the Bankruptcy Filing, all amounts have been classified as current. See Note 5 for discussion of letter of credit draws in 2014.
	Trade Accounts Receivable
		March 31,			December 31,
		2014			2013
	Wholesale and retail trade accounts receivable	$	652		$	732
	Allowance for uncollectible accounts	(17		)	(14		)
	Trade accounts receivable — net	$	635		$	718
	Gross trade accounts receivable at March 31, 2014 and December 31, 2013 included unbilled revenues of $209 million and $272 million, respectively.
	Allowance for Uncollectible Accounts Receivable
		Three Months Ended March 31,
		2014			2013
	Allowance for uncollectible accounts receivable at beginning of period	$	14		$	9
	Increase for bad debt expense	10			6
	Decrease for account write-offs	(7		)	(5		)
	Allowance for uncollectible accounts receivable at end of period	$	17		$	10
	Inventories by Major Category
		March 31,			December 31,
		2014			2013
	Materials and supplies	$	213		$	216
	Fuel stock	142			154
	Natural gas in storage	18			29
	Total inventories	$	373		$	399
	Other Investments
		March 31,			December 31,
		2014			2013
	Nuclear plant decommissioning trust	$	810		$	791
Assets related to employee benefit plans, including employee savings programs, net of distributions	61			61
Land	37			37
Miscellaneous other	2			2
Total other investments	$	910		$	891
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 10). The nuclear decommissioning trust fund is not a debtor under the Bankruptcy Filing. A summary of investments in the fund follows:
	31-Mar-14
	Cost (a)			Unrealized gain			Unrealized loss			Fair market
										value
Debt securities (b)	$	272		$	10		$	(2	)	$	280
Equity securities (c)	258			277			(5		)	530
Total	$	530		$	287		$	(7	)	$	810
	31-Dec-13
	Cost (a)			Unrealized gain			Unrealized loss			Fair market
										value
Debt securities (b)	$	266		$	8		$	(4	)	$	270
Equity securities (c)	255			271			(5		)	521
Total	$	521		$	279		$	(9	)	$	791
____________
(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 3.91% and 3.96% at March 31, 2014 and December 31, 2013, respectively, and an average maturity of 5 years and 6 years at March 31, 2014 and December 31, 2013, respectively.
(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 March 31, 2014 mature as follows: $111 million in one to five years, $57 million in five to ten years and $112 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 March 31,
	2014			2013
Realized gains	$	1		$	—
Proceeds from sales of securities	$	33		$	41
Investments in securities	$	(37	)	$	(45	)
Property, Plant and Equipment
At March 31, 2014 and December 31, 2013, property, plant and equipment of $17.6 billion and $17.8 billion, respectively, is stated net of accumulated depreciation and amortization of $8.5 billion and $8.2 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 three months ended March 31, 2014:
	Nuclear Plant Decommissioning			Mining Land Reclamation			Other			Total
Liability at December 31, 2013	$	390		$	98		$	36		$	524
Additions:
Accretion	6			6			—			12
Reductions:
Payments	—			(22		)	—			(22		)
Adjustment to estimate of reclamation costs	—			(2		)	—			(2		)
Liability at March 31, 2014	396			80			36			512
Less amounts due currently	—			(66		)	—			(66		)
Noncurrent liability at March 31, 2014	$	396		$	14		$	36		$	446
Other Noncurrent Liabilities and Deferred Credits
The balance of other noncurrent liabilities and deferred credits consists of the following:
	March 31,			December 31,
	2014			2013
Uncertain tax positions, including accrued interest	$	246		$	246
Retirement plan and other employee benefits (a)	1,034			1,057
Asset retirement and mining reclamation obligations	446			440
Unfavorable purchase and sales contracts	583			589
Nuclear decommissioning cost over-recovery (Note 10)	413			400
Other	28			30
Total other noncurrent liabilities and deferred credits	$	2,750		$	2,762
____________
(a)	Includes $845 million and $838 million at March 31, 2014 and December 31, 2013, respectively, representing pension and OPEB liabilities related to Oncor (see Note 10).
Unfavorable Purchase and Sales Contracts — The amortization of unfavorable purchase and sales contracts totaled $6 million for both the three months ended March 31, 2014 and 2013. See Note 4 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
2014		$	24
2015		$	23
2016		$	23
2017		$	23
2018		$	23
Supplemental Cash Flow Information
	Three Months Ended March 31,
	2014			2013
Cash payments related to:
Interest paid (a)	$	622		$	731
Capitalized interest	(7		)	(7		)
Interest paid (net of capitalized interest) (a)	$	615		$	724
Income taxes	$	—		$	—
Noncash investing and financing activities:
Construction expenditures (b)	$	30		$	57
Debt exchange and extension transactions (c)	$	—		$	(326	)
____________
(a)	Net of amounts received under interest rate swap agreements.
(b)	Represents end-of-period accruals.
(c)	For the three months ended March 31, 2013 includes: $340 million of term loans issued under the TCEH Term Loan Facilities, $1.302 billion of EFIH debt issued in exchange for $1.310 billion of EFH Corp. and EFIH debt and $89 million of EFIH debt issued in exchange for $95 million of EFH Corp. debt. Also see Note 5.

Business_And_Significant_Accou1

Business And Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2014
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 2013 Form 10-K. The condensed consolidated financial statements have been prepared as if EFH Corp. is a going concern but do not reflect the application of ASC 852, Reorganizations. 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 3). 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. 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 2013 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)	3 Months Ended
	Mar. 31, 2014
Consolidation Of Variable Interest Entities [Abstract]	'
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 months ended March 31, 2014 and 2013 are presented below:
		Three Months Ended March 31,
		2014			2013
	Operating revenues	$	917		$	817
	Operation and maintenance expenses	(345		)	(298		)
	Depreciation and amortization	(210		)	(199		)
	Taxes other than income taxes	(108		)	(102		)
	Other income	4			5
	Other deductions	(3		)	(4		)
	Interest income	1			1
	Interest expense and related charges	(88		)	(94		)
	Income before income taxes	168			126
	Income tax expense	(67		)	(41		)
	Net income	101			85
	Net income attributable to noncontrolling interests	(21		)	(18		)
	Net income attributable to Oncor Holdings	$	80		$	67
Schedule of assets and liabilities of Oncor Holdings	'
	Assets and liabilities of Oncor Holdings at March 31, 2014 and December 31, 2013 are presented below:
		March 31,			December 31,
		2014			2013
	ASSETS
	Current assets:
	Cash and cash equivalents	$	32		$	28
	Restricted cash	58			52
	Trade accounts receivable — net	390			385
	Trade accounts and other receivables from affiliates	120			135
	Income taxes receivable from EFH Corp.	22			16
	Inventories	69			65
	Accumulated deferred income taxes	27			32
	Prepayments and other current assets	86			82
	Total current assets	804			795
	Restricted cash	16			16
	Other investments	91			91
	Property, plant and equipment — net	12,068			11,902
	Goodwill	4,064			4,064
	Regulatory assets — net	1,222			1,324
	Other noncurrent assets	79			71
	Total assets	$	18,344		$	18,263
	LIABILITIES
	Current liabilities:
	Short-term borrowings	$	979		$	745
	Long-term debt due currently	633			131
	Trade accounts payable — nonaffiliates	147			178
	Income taxes payable to EFH Corp.	85			23
	Accrued taxes other than income	65			169
	Accrued interest	64			95
	Other current liabilities	118			135
	Total current liabilities	2,091			1,476
	Accumulated deferred income taxes	1,901			1,905
	Long-term debt, less amounts due currently	4,852			5,381
	Other noncurrent liabilities and deferred credits	1,747			1,822
	Total liabilities	$	10,591		$	10,584

Goodwill_And_Identifiable_Inta1

Goodwill And Identifiable Intangible Assets (Tables)	3 Months Ended
	Mar. 31, 2014
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 months ended March 31, 2014. None of the goodwill is being deducted for tax purposes.
	Goodwill before impairment charges	$	18,342
	Accumulated noncash impairment charges	(14,390		)
	Balance at March 31, 2014 and December 31, 2013	$	3,952
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:
			31-Mar-14							31-Dec-13
	Identifiable Intangible Asset		Gross			Accumulated		Net		Gross		Accumulated		Net
			Carrying			Amortization				Carrying		Amortization
			Amount							Amount
	Retail customer relationship		$	463		$	408	$	55	$	463	$	402	$	61
	Favorable purchase and sales contracts		352			145		207		352		139		213
	Capitalized in-service software		360			203		157		355		192		163
	Environmental allowances and credits		207			23		184		209		20		189
	Mining development costs		163			78		85		156		69		87
	Total identifiable intangible assets subject to amortization		$	1,545		$	857	688		$	1,535	$	822	713
	Retail trade name (not subject to amortization)							955						955
	Mineral interests (not currently subject to amortization)							9						11
	Total identifiable intangible assets							$	1,652					$	1,679
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 March 31,
						2014		2013
	Retail customer relationship		Depreciation and amortization		Competitive Electric	$	6	$	6
	Favorable purchase and sales contracts		Operating revenues/fuel, purchased power costs and delivery fees		Competitive Electric	6		6
	Capitalized in-service software		Depreciation and amortization		Competitive Electric and Corporate and Other	11		10
	Environmental allowances and credits		Fuel, purchased power costs and delivery fees		Competitive Electric	4		3
	Mining development costs		Depreciation and amortization		Competitive Electric	8		8
	Total amortization expense (a)					$	35	$	33
	____________
	(a)	Amounts recorded in depreciation and amortization totaled $25 million and $24 million for the three months ended March 31, 2014 and 2013, respectively.
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
	2014		$	134
	2015		$	123
	2016		$	101
	2017		$	78
	2018		$	58

Borrowing_Facilities_and_Debt_

Borrowing Facilities and Debt (Tables)	3 Months Ended
	Mar. 31, 2014
Debt and Capital Lease Obligations [Abstract]	'
Schedule of Line of Credit Facilities	'
	Credit facilities and related cash borrowings at March 31, 2014 are presented below. The facilities are all senior secured facilities of TCEH.
				31-Mar-14
	Facility	Maturity		Facility				Cash			Available L/C Capacity
		Date		Limit				Borrowings
	TCEH Revolving Credit Facility (a)	Oct-16		$	2,054			$	2,054		$	—
	TCEH Letter of Credit (L/C) 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 borrowings under credit facilities. Borrowings under the facility bore interest at LIBOR plus 4.50%, and a commitment fee was payable quarterly in arrears at a rate per annum equal to 1.00% of the average daily unused portion of the facility.
	(b)	Facility, $42 million of which has a maturity date of 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.
Schedule of Long-term Debt Instruments	'
	Debt
	The Bankruptcy Filing constituted an event of default under the Credit Agreement governing the TCEH Senior Secured Facilities and the indentures governing the company's other debt instruments listed below as well as capital lease obligations, and those debt obligations became immediately due and payable. As a result, the accompanying consolidated balance sheets as of March 31, 2014 and December 31, 2013 present all debt classified as current. Under the Bankruptcy Code, the creditors under these debt agreements are stayed from taking any action against the Debtors as a result of the default.
	At March 31, 2014 and December 31, 2013, notes, loans and other debt consisted of the following:
		March 31,				December 31,
		2014				2013
	EFH Corp. (parent entity)
	9.75% Fixed Senior Notes due October 15, 2019	$	2			$	2
	10% Fixed Senior Notes due January 15, 2020	3				3
	10.875% Fixed Senior Notes due November 1, 2017	33				33
	11.25% / 12.00% Senior Toggle Notes due November 1, 2017	27				27
	5.55% Fixed Series P Senior Notes due November 15, 2014 (a)	90				90
	6.50% Fixed Series Q Senior Notes due November 15, 2024 (a)	201				201
	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)	42				46
	Unamortized fair value premium related to Building Financing (b)(c)	8				9
	Unamortized fair value discount (c)	(118		)		(121		)
	Total EFH Corp.	579				581
	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				3,482
	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	1,566				1,566
	9.75% Fixed Senior Notes due October 15, 2019	2				2
	Unamortized premium	265				284
	Unamortized discount	(142		)		(146		)
	Total EFIH	7,832				7,847
	EFCH
	9.58% Fixed Notes due in annual installments through December 4, 2019 (d)	29				29
	8.254% Fixed Notes due in quarterly installments through December 31, 2021 (d)	32				34
	1.038% 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)	(5		)		(6		)
	Total EFCH	65				66
	TCEH
	Senior Secured Facilities:
	3.737% TCEH Term Loan Facilities with maturity date of October 10, 2014 (e)(f)	3,809				3,809
	3.736% TCEH Letter of Credit Facility with maturity date of October 10, 2014 (e)	42				42
	4.737% TCEH Term Loan Facilities with maturity date of October 10, 2017 (a)(e)(f)	15,691				15,691
	4.736% TCEH Letter of Credit Facility with maturity date of 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
		March 31,				December 31,
		2014				2013
	10.50% / 11.25% Senior Toggle Notes due November 1, 2016	$	1,749			$	1,749
	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
	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
	0.290% Floating Series 2001D-2 due May 1, 2033 (g)	17				97
	0.393% Floating Taxable Series 2001I due December 1, 2036 (h)	2				62
	—% Floating Series 2002A due May 1, 2037	—				45
	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 (i)	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)	(103		)		(105		)
Other:
7.48% Fixed Secured Facility Bonds with amortizing payments through January 2017	35				36
7.46% Fixed Secured Facility Bonds with amortizing payments through January 2015	4				4
Capital leases	49				52
Other	3				3
Unamortized discount	(96		)		(103		)
Total TCEH	29,524				29,704
Total EFH Corp. consolidated	$	38,000			$	38,198
___________
(a)	Excludes the following debt held by EFIH or EFH Corp. (parent entity) and eliminated in consolidation. Pursuant to the terms of the Restructuring Support and Lock-Up Agreement, the debt is expected to be cancelled in connection with the Restructuring Plan, except for the TCEH 4.737% Term Loan Facilities.
	March 31,				December 31,
	2014				2013
EFH Corp. 5.55% Fixed Series P Senior Notes due November 15, 2014	$	281			$	281
EFH Corp. 6.50% Fixed Series Q Senior Notes due November 15, 2024	545				545
EFH Corp. 6.55% Fixed Series R Senior Notes due November 15, 2034	456				456
TCEH 4.737% 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			$	1,664
(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 March 31, 2014.
(f)	At March 31, 2014, interest rate was swapped to fixed on $18.077 billion principal amount of maturities through October 2014 and up to an aggregate $12.6 billion principal amount from October 2014 through October 2017. See discussion below regarding termination of the agreements following the Bankruptcy Filing.
(g)	Interest rates in effect at March 31, 2014. This series is in a daily interest rate mode and is supported by long-term irrevocable letters of credit.
(h)	Interest rate in effect at March 31, 2014. This series is in a weekly interest rate mode and is supported by long-term irrevocable letters of credit.
(i)	This series is in the multiannual interest rate mode and is 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.
Schedule of Interest Rate Derivatives	'
	As reflected in the table below, at March 31, 2014, TCEH had entered into the following series of interest rate swap transactions that effectively fixed the interest rates at between 5.5% and 9.3%.
	Fixed Rates					Expiration Dates		Notional Amount
	5.5	%	-	9.30%		Oct-14			$	18.077	billion (a)
	6.8	%	-	9.00%		October 2015 through October 2017			$	12.6	billion (b)
	___________
	(a)	Swaps related to an aggregate $1.5 billion principal amount of debt expired in 2014. Per the terms of the transactions, the notional amount of swaps entered into in 2011 grew by $1.388 billion in 2014, substantially offsetting the expired swaps.
	(b)	These swaps were effective from October 2014 through October 2017. The $12.6 billion notional amount of swaps included $3 billion that expire in October 2015 with the remainder expiring in October 2017.
	The interest rate swaps have resulted in realized and unrealized net gains (losses), reported in interest expense and related charges, as follows:
		Three Months Ended March 31,
		2014				2013
	Realized net loss	$	(145	)		$	(151	)
	Unrealized net gain	64				148
	Total	$	(81	)		$	(3	)

Equity_Tables

Equity (Tables)	3 Months Ended
	Mar. 31, 2014
Stockholders' Equity Note [Abstract]	'
Schedule of Stockholders Equity	'
	The following table presents the changes to equity for the three months ended March 31, 2014:
		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, 2013	$	2		$	7,962		$	(21,157	)	$	(63	)	$	1		$	(13,255	)
	Net loss	—			—			(609		)	—			—			(609		)
	Effects of stock-based incentive compensation plans	—			2			—			—			—			2
	Change in unrecognized losses related to pension and OPEB plans (Note 10)	—			—			—			(1		)	—			(1		)
	Investment by noncontrolling interests	—			—			—			—			1			1
	Other	—			—			—			—			(2		)	(2		)
	Balance at March 31, 2014	$	2		$	7,964		$	(21,766	)	$	(64	)	$	—		$	(13,864	)
	____________
	(a)	Authorized shares totaled 2,000,000,000 at March 31, 2014. Outstanding shares totaled 1,669,861,383 and 1,669,861,383 at March 31, 2014 and December 31, 2013, respectively.
	The following table presents the changes to equity for the three months ended March 31, 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	—			—			(569		)	—			—			(569		)
	Effects of stock-based incentive compensation plans	—			2			—			—			—			2
	Change in unrecognized losses related to pension and OPEB plans	—			—			—			(2		)	—			(2		)
	Net effects of cash flow hedges	—			—			—			2			—			2
	Net effects related to Oncor	—			—			—			1			—			1
	Investment by noncontrolling interests	—			—			—			—			1			1
	Balance at March 31, 2013	$	2		$	7,961		$	(19,508	)	$	(46	)	$	103		$	(11,488	)
	____________
	(a)	Authorized shares totaled 2,000,000,000 at March 31, 2013. Outstanding shares totaled 1,681,908,837 and 1,680,539,245 at March 31, 2013 and December 31, 2012, 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 three months ended March 31, 2014. 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, 2013	$	(56	)	$	(7	)	$	(63	)
	Amounts reclassified from accumulated other comprehensive income (loss) and reported in:
	Operating costs	—			(1		)	(1		)
	Depreciation and amortization	(1		)	—			(1		)
	Selling, general and administrative expenses	—			(1		)	(1		)
	Interest expense and related charges	1			—			1
	Income tax benefit (expense)	—			1			1
	Equity in earnings of unconsolidated subsidiaries	—			—			—
	Total amount reclassified from accumulated other comprehensive income (loss) during the period	—			(1		)	(1		)
	Balance at March 31, 2014	$	(56	)	$	(8	)	$	(64	)
	The following table presents the changes to accumulated other comprehensive income (loss) for the three months ended March 31, 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	—			(1		)	(1		)
	Selling, general and administrative expenses	—			(1		)	(1		)
	Interest expense and related charges	4			—			4
	Income tax benefit (expense)	(1		)	1			—
	Equity in earnings of unconsolidated subsidiaries	—			(1		)	(1		)
	Total amount reclassified from accumulated other comprehensive income (loss) during the period	3			(2		)	1
	Balance at March 31, 2013	$	(61	)	$	15		$	(46	)

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2014
Fair Value Disclosures [Abstract]	'
Schedule of assets and liabilities measured at fair value on a recurring basis	'
	Assets and liabilities measured at fair value on a recurring basis consisted of the following:
	31-Mar-14
		Level 1			Level 2				Level 3 (a)				Total
	Assets:
	Commodity contracts	$	169		$	394			$	64			$	627
	Interest rate swaps	—			69				—				69
	Nuclear decommissioning trust – equity securities (b)	336			194				—				530
	Nuclear decommissioning trust – debt securities (b)	—			280				—				280
	Total assets	$	505		$	937			$	64			$	1,506
	Liabilities:
	Commodity contracts	$	284		$	41			$	13			$	338
	Interest rate swaps	—			81				948				1,029
	Total liabilities	$	284		$	122			$	961			$	1,367
	31-Dec-13
		Level 1			Level 2				Level 3 (a)				Total
	Assets:
	Commodity contracts	$	161		$	570			$	57			$	788
	Interest rate swaps	—			67				—				67
	Nuclear decommissioning trust – equity securities (b)	330			191				—				521
	Nuclear decommissioning trust – debt securities (b)	—			270				—				270
	Total assets	$	491		$	1,098			$	57			$	1,646
	Liabilities:
	Commodity contracts	$	231		$	14			$	18			$	263
	Interest rate swaps	—			80				1,012				1,092
	Total liabilities	$	231		$	94			$	1,030			$	1,355
	____________
	(a)	See table below for description of Level 3 assets and liabilities.
	(b)	The nuclear decommissioning trust investment is included in the other investments line in the balance sheet. See Note 12.
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 March 31, 2014 and December 31, 2013:
	31-Mar-14
			Fair Value
	Contract Type (a)		Assets			Liabilities				Total				Valuation Technique	Significant Unobservable Input	Range (b)
	Electricity purchases and sales		$	1		$	(1	)		$	—			Valuation Model	Illiquid pricing locations (c)	$35 to $45/ MWh
															Hourly price curve shape (d)	$20 to $70/ MWh
	Electricity spread options		16			(2		)		14				Option Pricing Model	Gas to power correlation (e)	45% to 95%
															Power volatility (f)	10% to 30%
	Electricity congestion revenue rights		39			(3		)		36				Market Approach (g)	Illiquid price differences between settlement points (h)	$0.00 to $25.00
	Coal purchases		2			(6		)		(4		)		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		—			(948		)		(948		)		Valuation Model	Nonperformance risk adjustment (l)	20% to 30%
	Other (m)		6			(1		)		5
	Total		$	64		$	(961	)		$	(897	)
	31-Dec-13
			Fair Value
	Contract Type (a)		Assets			Liabilities				Total				Valuation Technique	Significant Unobservable Input	Range (b)
	Electricity purchases and sales		$	2		$	(2	)		$	—			Valuation Model	Illiquid pricing locations (c)	$25 to $45/ MWh
															Hourly price curve shape (d)	$20 to $70/ MWh
	Electricity spread options		15			(2		)		13				Option Pricing Model	Gas to power correlation (e)	45% to 95%
															Power volatility (f)	10% to 30%
	Electricity congestion revenue rights		35			(2		)		33				Market Approach (g)	Illiquid price differences between settlement points (h)	$0.00 to $25.00
	Coal purchases		—			(11		)		(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		—			(1,012		)		(1,012		)		Valuation Model	Nonperformance risk adjustment (l)	25% to 35%
	Other (m)		5			(1		)		4
	Total		$	57		$	(1,030	)		$	(973	)
	____________
	(a)	Electricity purchase and sales contracts include 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 were held by TCEH to hedge exposure to its variable rate debt (see Note 5).
	(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 debt trading values. See discussion immediately below regarding Level 3 liabilities.
	(m)	Other contracts include various transactions such as ancillary services, natural gas, diesel options and coal options.
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 months ended March 31, 2014 and 2013. The Level 3 net liability balance at March 31, 2014 reflects a nonperformance risk adjustment in the valuation of the TCEH interest rate swaps, which were 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 March 31, 2014, the estimated fair value of these interest rate swaps totaled $1.252 billion before consideration of nonperformance risk adjustment and $948 million 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 March 31,
		2014			2013
	Net asset (liability) balance at beginning of period	$	(973	)	$	29
	Total unrealized valuation gains (losses)	(85		)	9
	Purchases, issuances and settlements (a):
	Purchases	9			4
	Issuances	(1		)	—
	Settlements	151			16
	Transfers into Level 3 (b)	—			1
	Transfers out of Level 3 (b)	2			—
	Net change (c)	76			30
	Net asset (liability) balance at end of period	$	(897	)	$	59
	Unrealized valuation gains (losses) relating to instruments held at end of period	$	(71	)	$	14
	____________
	(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 in 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 loss from commodity hedging and trading activities. Changes in values of interest rate swaps transferred into Level 3 in third quarter 2013 are reported in the income statement in interest expense and related charges. Activity excludes changes in fair value in the month the positions 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)	3 Months Ended
	Mar. 31, 2014
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 March 31, 2014 and December 31, 2013:
	31-Mar-14
		Derivative assets								Derivative liabilities
		Commodity contracts				Interest rate swaps				Commodity contracts				Interest rate swaps				Total
	Current assets	$	617			$	69			$	—			$	—			$	686
	Noncurrent assets	10				—				—				—				10
	Current liabilities	—				—				(338		)		(1,029		)		(1,367		)
	Net assets (liabilities)	$	627			$	69			$	(338	)		$	(1,029	)		$	(671	)
	31-Dec-13
		Derivative assets								Derivative liabilities
		Commodity contracts				Interest rate swaps				Commodity contracts				Interest rate swaps				Total
	Current assets	$	784			$	67			$	—			$	—			$	851
	Noncurrent assets	4				—				—				—				4
	Current liabilities	—				—				(263		)		(1,092		)		(1,355		)
	Net assets (liabilities)	$	788			$	67			$	(263	)		$	(1,092	)		$	(500	)
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 March 31,
	Derivative (income statement presentation)		2014				2013
	Commodity contracts (Net gain (loss) from commodity hedging and trading activities) (a)		$	(179	)		$	(200	)
	Interest rate swaps (Interest expense and related charges) (b)		(82		)		(3		)
	Net gain (loss)		$	(261	)		$	(203	)
	____________
	(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 12).
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:
	31-Mar-14
			Amounts Presented in Balance Sheet				Offsetting Instruments (a)				Financial Collateral (Received) Pledged (b)				Net Amounts
	Derivative assets:
	Commodity contracts		$	627			$	(334	)		$	(201	)		$	92
	Interest rate swaps		69				(69		)		—				—
	Total derivative assets		696				(403		)		(201		)		92
	Derivative liabilities:
	Commodity contracts		(338		)		181				114				(43		)
	Interest rate swaps		(1,029		)		222				—				(807		)
	Total derivative liabilities		(1,367		)		403				114				(850		)
	Net amounts		$	(671	)		$	—			$	(87	)		$	(758	)
	31-Dec-13
			Amounts Presented in Balance Sheet				Offsetting Instruments (a)				Financial Collateral (Received) Pledged (b)				Net Amounts
	Derivative assets:
	Commodity contracts		$	788			$	(389	)		$	(299	)		$	100
	Interest rate swaps		67				(67		)		—				—
	Total derivative assets		855				(456		)		(299		)		100
	Derivative liabilities:
	Commodity contracts		(263		)		168				70				(25		)
	Interest rate swaps		(1,092		)		288				—				(804		)
	Total derivative liabilities		(1,355		)		456				70				(829		)
	Net amounts		$	(500	)		$	—			$	(229	)		$	(729	)
	____________
	(a)	Offsetting 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.
Schedule of Gross Notional Amounts of Derivative Volumes	'
	The following table presents the gross notional amounts of derivative volumes at March 31, 2014 and December 31, 2013:
			31-Mar-14				31-Dec-13
	Derivative type		Notional Volume								Unit of Measure
	Interest rate swaps:
	Floating/fixed (a)		$	32,377			$	32,490			Million US dollars
	Basis		$	1,050			$	1,050			Million US dollars
	Natural gas (b)		2,282				2,150				Million MMBtu
	Electricity		14,541				16,482				GWh
	Congestion Revenue Rights (c)		80,702				77,799				GWh
	Coal		12				9				Million US tons
	Fuel oil		27				26				Million gallons
	Uranium		450				450				Thousand pounds
	____________
	(a)	Includes notional amount of interest rate swaps that had maturity dates through October 2014 as well as notional amount of swaps effective from October 2014 that had maturity dates through October 2017 (see Note 5).
	(b)	Represents gross notional forward sales, purchases and options transactions, locational basis swaps and other natural gas transactions.
	(c)	Represents gross forward purchases associated with instruments used to hedge electricity price differences between settlement points within ERCOT.

Segment_Information_Tables

Segment Information (Tables)	3 Months Ended
	Mar. 31, 2014
Segment Reporting [Abstract]	'
Schedule of segment reporting information, by segment	'
		Three Months Ended March 31,
		2014			2013
	Operating revenues (all Competitive Electric)	$	1,517		$	1,260
	Equity in earnings of unconsolidated subsidiaries (net of tax) — Regulated Delivery (net of noncontrolling interest of $21 and $17)	$	80		$	67
	Net income (loss):
	Competitive Electric	$	(567	)	$	(547	)
	Regulated Delivery	80			67
	Corporate and Other	(122		)	(89		)
	Consolidated	$	(609	)	$	(569	)

Supplementary_Financial_Inform1

Supplementary Financial Information (Tables)	3 Months Ended
	Mar. 31, 2014
Supplementary Financial Information [Abstract]	'
Schedule of other income and deductions	'
	Other Income and Deductions
		Three Months Ended March 31,
		2014			2013
	Other income:
	Office space rental income (a)	$	3		$	3
	Insurance/litigation settlements (b)	—			2
	All other	6			3
	Total other income	$	9		$	8
	Other deductions:
	Ongoing employee retirement benefit expense related to discontinued businesses (a)	$	—		$	(1	)
	All other	—			4
	Total other deductions	$	—		$	3
	____________
	(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 March 31,
		2014			2013
	Interest paid/accrued (including net amounts settled/accrued under interest rate swaps)	$	831		$	839
	Interest expense on toggle notes payable in additional principal (Note 5)	49			41
	Unrealized mark-to-market net (gain) loss on interest rate swaps (a)	(65		)	(150		)
	Amortization of interest rate swap losses at dedesignation of hedge accounting	(1		)	2
	Amortization of fair value debt discounts resulting from purchase accounting	5			5
	Amortization of debt issuance, amendment and extension costs and discounts	51			54
	Capitalized interest	(7		)	(7		)
	Total interest expense and related charges	$	863		$	784
	____________
	(a)	Three months ended March 31, 2014 and 2013 amounts include net gains totaling $64 million and $148 million, respectively, related to TCEH swaps (see Note 5) and net gains totaling $1 million and $2 million, respectively, related to EFH Corp. swaps substantially closed through offsetting positions.
Schedule of restricted cash	'
	Restricted Cash
		31-Mar-14						31-Dec-13
		Current			Noncurrent Assets			Current			Noncurrent Assets
		Assets						Assets
	Amounts related to TCEH's Letter of Credit Facility (Note 5) (a)	$	660		$	—		$	945		$	—
	Other	4			—			4			—
	Total restricted cash	$	664		$	—		$	949		$	—
	____________
	(a)	At both March 31, 2014 and December 31, 2013, in consideration of the Bankruptcy Filing, all amounts have been classified as current. See Note 5 for discussion of letter of credit draws in 2014.
Schedule of accounts, notes, loans and financing receivable [Table Text Block]	'
	Allowance for Uncollectible Accounts Receivable
		Three Months Ended March 31,
		2014			2013
	Allowance for uncollectible accounts receivable at beginning of period	$	14		$	9
	Increase for bad debt expense	10			6
	Decrease for account write-offs	(7		)	(5		)
	Allowance for uncollectible accounts receivable at end of period	$	17		$	10
	Trade Accounts Receivable
		March 31,			December 31,
		2014			2013
	Wholesale and retail trade accounts receivable	$	652		$	732
	Allowance for uncollectible accounts	(17		)	(14		)
	Trade accounts receivable — net	$	635		$	718
Schedule of inventories by major category	'
	Inventories by Major Category
		March 31,			December 31,
		2014			2013
	Materials and supplies	$	213		$	216
	Fuel stock	142			154
	Natural gas in storage	18			29
	Total inventories	$	373		$	399
Summary of other investments	'
	Other Investments
		March 31,			December 31,
		2014			2013
	Nuclear plant decommissioning trust	$	810		$	791
	Assets related to employee benefit plans, including employee savings programs, net of distributions	61			61
	Land	37			37
	Miscellaneous other	2			2
	Total other investments	$	910		$	891
Summary of investments in the fund	'
	The nuclear decommissioning trust fund is not a debtor under the Bankruptcy Filing. A summary of investments in the fund follows:
		31-Mar-14
		Cost (a)			Unrealized gain			Unrealized loss			Fair market
											value
	Debt securities (b)	$	272		$	10		$	(2	)	$	280
	Equity securities (c)	258			277			(5		)	530
	Total	$	530		$	287		$	(7	)	$	810
		31-Dec-13
		Cost (a)			Unrealized gain			Unrealized loss			Fair market
											value
	Debt securities (b)	$	266		$	8		$	(4	)	$	270
	Equity securities (c)	255			271			(5		)	521
	Total	$	521		$	279		$	(9	)	$	791
	____________
	(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 3.91% and 3.96% at March 31, 2014 and December 31, 2013, respectively, and an average maturity of 5 years and 6 years at March 31, 2014 and December 31, 2013, respectively.
	(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 March 31,
		2014			2013
	Realized gains	$	1		$	—
	Proceeds from sales of securities	$	33		$	41
	Investments in securities	$	(37	)	$	(45	)
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 three months ended March 31, 2014:
		Nuclear Plant Decommissioning			Mining Land Reclamation			Other			Total
	Liability at December 31, 2013	$	390		$	98		$	36		$	524
	Additions:
	Accretion	6			6			—			12
	Reductions:
	Payments	—			(22		)	—			(22		)
	Adjustment to estimate of reclamation costs	—			(2		)	—			(2		)
	Liability at March 31, 2014	396			80			36			512
	Less amounts due currently	—			(66		)	—			(66		)
	Noncurrent liability at March 31, 2014	$	396		$	14		$	36		$	446
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:
		March 31,			December 31,
		2014			2013
	Uncertain tax positions, including accrued interest	$	246		$	246
	Retirement plan and other employee benefits (a)	1,034			1,057
	Asset retirement and mining reclamation obligations	446			440
	Unfavorable purchase and sales contracts	583			589
	Nuclear decommissioning cost over-recovery (Note 10)	413			400
	Other	28			30
	Total other noncurrent liabilities and deferred credits	$	2,750		$	2,762
	____________
	(a)	Includes $845 million and $838 million at March 31, 2014 and December 31, 2013, respectively, representing pension and OPEB liabilities related to Oncor (see Note 10).
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
	2014		$	24
	2015		$	23
	2016		$	23
	2017		$	23
	2018		$	23
Schedule of supplemental cash flow information	'
	Supplemental Cash Flow Information
		Three Months Ended March 31,
		2014			2013
	Cash payments related to:
	Interest paid (a)	$	622		$	731
	Capitalized interest	(7		)	(7		)
	Interest paid (net of capitalized interest) (a)	$	615		$	724
	Income taxes	$	—		$	—
	Noncash investing and financing activities:
	Construction expenditures (b)	$	30		$	57
	Debt exchange and extension transactions (c)	$	—		$	(326	)
	____________
	(a)	Net of amounts received under interest rate swap agreements.
	(b)	Represents end-of-period accruals.
	(c)	For the three months ended March 31, 2013 includes: $340 million of term loans issued under the TCEH Term Loan Facilities, $1.302 billion of EFIH debt issued in exchange for $1.310 billion of EFH Corp. and EFIH debt and $89 million of EFIH debt issued in exchange for $95 million of EFH Corp. debt. Also see Note 5.

Business_And_Significant_Accou2

Business And Significant Accounting Policies (Details)	3 Months Ended
	Mar. 31, 2014	Nov. 30, 2008	Mar. 31, 2014
	Reportable_segment	Oncor [Member]	Energy Future Intermediate Holding CO LLC [Member]
			Oncor [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	'	'
Equity method investment, Maximum ownership percentage for accounting treatment (as a percent)	50.00%	'	'

Subsequent_Event_Bankruptcy_Fi1

Subsequent Event - Bankruptcy Filing (Details) (USD $)

0 Months Ended

0 Months Ended

0 Months Ended

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

2-May-14

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [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]

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]

Second Lien Debtor-in-Possession Agreement [Member]

Second Lien Debtor-in-Possession Agreement [Member]

Second Lien Debtor-in-Possession Facility [Member]

Second Lien Debtor-in-Possession Facility [Member]

Mandatorily 8% Convertible Second Lien Subordinated Secured Financing Tranche A-2 Notes due 2016 [Member]

Mandatorily 8% Convertible Second Lien Subordinated Secured Financing Tranche A-1 Notes due 2016 [Member]

Backstop Commitment [Member]

Commitment Letter and Backstop Commitment Agreement [Member]

Commitment Letter and Backstop Commitment Agreement [Member]

Senior Secured Super-Priority Term Loan [Member]

RSA First Lien Note Parties [Member]

EFIH Second Lien Note Parties [Member]

Certain Remaining Holders of EFIH First Lien Notes [Member]

Non-Settling EFIH First and Second Lien Holders [Member]

Senior Secured Debt [Member]

Unsecured Debt [Member]

Unsecured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Senior Secured Debt [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Debtor-in-Possession Financing, First Lien Debt Facility Agreement [Member]

Second Lien Debtor-in-Possession Agreement [Member]

Debtor-in-Possession Financing, First Lien Debt Facility Agreement [Member]

Subsequent Event [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]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Second Lien Debtor-in-Possession Facility [Member]

Second Lien Debtor-in-Possession Facility [Member]

Debtor-In-Possession Facility [Member]

Debtor-In-Possession Facility [Member]

Debtor-In-Possession Facility [Member]

Debtor-In-Possession Facility [Member]

Commitment Letter [Member]

Energy Future Intermediate Holding CO LLC [Member]

Non-Interest Bearing Mandatorily Convertible Second Lien Subordinated Secured Financing Tranche B Notes due 2016 [Member]

Debtor-In-Possession Facility [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Debtor-In-Possession Facility [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Energy Future Intermediate Holding CO 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]

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

First Lien Debtor-in-Possession Facility [Member]

Second Lien Debtor-in-Possession Facility [Member]

First Lien Debtor-in-Possession Facility [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]

Subsequent Event [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debtor-in-Possession Financing, Debt Settlement, Equity Interest Debt Holders will Receive

'

100.00%

1.00%

98.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Conversion, Equity Interest Debt Holder, Right To Purchase

'

'

9.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Interest Rate, Stated Percentage

'

'

'

'

6.88%

10.00%

11.00%

11.75%

'

'

'

'

'

8.00%

'

'

'

'

'

'

'

'

Debtor-in-Possession Financing, Debt Settlement, Settlement Price, Option One, Percentage of Principal and Percentage of Accrued and Unpaid Interest, Percentage of Principal

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

105.00%

'

105.00%

'

Debtor-in-Possession Financing, Debt Settlement, Settlement Price, Option One, Percentage of Principal and Percentage of Accrued and Unpaid Interest, Percentage of Accrued and Unpaid Interest

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

101.00%

'

101.00%

'

Debtor-in-Possession Financing, Debt Settlement, Settlement Price, Option Two, Percentage of Principal and All Accrued and Unpaid Interest, Percentage of Principal

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

104.00%

'

'

'

Debtor-in-Possession Financing, Debt Settlement, Settlement Price, Percent of Principal and Aggregate Amount of Claim Related to Makewhole Provisions, Percentage of Principal

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

100.00%

Debtor-in-Possession Financing, Debt Settlement, Settlement Price, Percent of Principal and Aggregate Amount of Claim Related to Makewhole Provisions, Percentage of Claims on Makewhole Provision

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

Debtor-in-Possession Financing, Special Offering, Principal Amount

'

'

'

'

'

'

'

'

'

'

'

'

$1,900,000,000

'

'

'

$95,000,000

'

'

'

'

'

Debtor-in-Possession Financing, Commitment Letter

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,900,000,000

'

'

'

'

'

'

'

Debt Instrument, Execution Fee Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40,000,000

'

'

'

'

'

'

Debt Instrument, Early Termination Fee Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

380,000,000

'

'

'

'

'

'

Debt Instrument, Break-up Fee Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

57,000,000

'

'

'

'

'

'

Debtor-in-Possession Financing, Debt Settlement, Settlement Price, Pro-rata Amount of Cash Provided That Tax Payments Reach Projected Threshold Percentage, Amount of Cash

'

'

'

55,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debtor-in-Possession Financing, Debt Settlement, Settlement Price, Pro-rata Amount of Cash Provided That Tax Payments Reach Projected Threshold Percentage, Threshold Percentage

'

'

'

80.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debtor-in-Possession Financing, Debt Settlement, Equity Interest Equity Interest Holders will Receive in Reorganized Entity

1.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Second Lien Debtor-in-Possession Facility, Equity Conversion, Prorated Conversion, Equity Percentage

'

'

'

'

'

'

'

'

'

64.00%

'

64.00%

'

'

'

'

'

'

'

'

'

'

Second Lien Debtor-in-Possession Facility, Interest Rate Terms, Alternative Interest Rate if Court does not Approve Amendment in Certain Number of Days, Number of Days

'

'

'

'

'

'

'

'

'

'

'90 days

'90 days

'

'

'

'

'

'

'

'

'

'

Second Lien Debtor-in-Possession Facility, Interest Rate Terms, Alternative Interest Rate if Court does not Approve Amendment in Certain Number of Days, Incremental Interest Increase

'

'

'

'

'

'

'

'

4.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Second Lien Debtor-in-Possession Facility, Terms, Notes Issuable if Amendment is not Approved by Threshold Date, Percentage of Outstanding Notes Lien Holder Would get In New Notes, Percentage

'

'

'

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Debtor-in-Possession Financing, Amount Arranged

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

700,000,000

'

'

'

'

Debtor-in-Possession Financing, Second-lien, Amount

'

'

'

'

'

'

'

'

'

'

'

$1,900,000,000

'

'

'

'

'

'

'

'

'

'

Variable_Interest_Entities_Onc

Variable Interest Entities (Oncor Holdings and Distributions from Oncor Holdings) (Details) (USD $)

3 Months Ended

3 Months Ended

In Millions, unless otherwise specified

Mar. 31, 2014

Mar. 31, 2013

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Dec. 31, 2013

Mar. 31, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Oncor [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Oncor Holdings [Member]

Oncor Holdings [Member]

Oncor Holdings [Member]

Internal Revenue Service (IRS) [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Receivable Attributable to Income Taxes [Member]

Receivable Attributable to Income Taxes [Member]

Energy Future Intermediate Holding CO LLC [Member]

Oncor Holdings [Member]

Oncor Holdings [Member]

Oncor [Member]

Oncor Holdings [Member]

Oncor Holdings [Member]

Oncor Holdings or Oncor [Member]

Internal Revenue Service (IRS) [Member]

Receivable Attributable to Income Taxes [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Oncor Holdings [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Parent [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Oncor [Member]

Energy Future Holdings Corp. [Member]

Receivable Attributable to Income Taxes [Member]

Schedule of Equity Method Investments [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity method investment, ownership (as a percent)

'

'

'

'

'

80.00%

'

'

'

'

'

'

'

'

'

'

Investment in unconsolidated subsidiary

$6,002

'

$5,959

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of equity method investment consolidated revenues related to services provided to entity (as a percent)

'

'

'

'

'

'

26.00%

28.00%

'

'

'

'

'

'

'

'

Distributions of earnings from unconsolidated subsidiaries

37

31

'

'

'

'

'

'

37

31

'

'

'

'

'

'

Eligible distributions after accounting for regulatory restrictions

'

'

'

'

'

'

'

'

239

'

'

'

'

'

'

'

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)

'

'

'

'

'

'

'

'

58.40%

'

'

'

'

'

'

'

Regulatory capitalization, ratio of debt to equity, equity (as a percent)

'

'

'

'

'

'

'

'

41.60%

'

'

'

'

'

'

'

Trade accounts and other receivables from affiliates

'

'

'

'

'

'

'

'

120

'

135

'

109

'

'

'

Equity Method Investment, Summarized Financial Information, Unbilled Receivables, Current

'

'

'

'

'

'

'

'

'

'

'

'

37

'

'

'

Equity Method Investment, Trade Accounts And Other Receivables Secured By Letter of Credit

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5

'

Equity Method Investments, Credit Risk Exposure, Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

20

'

'

Due from affiliate, current

'

'

'

$61

$5

'

'

'

'

'

'

$51

'

'

'

$18

Variable_Interest_Entities_Onc1

Variable Interest Entities (Oncor Holdings Financial Statements) (Details) (Oncor Holdings [Member], USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
Oncor Holdings [Member]	'	'	'
Schedule of Equity Method Investments [Line Items]	'	'	'
Operating revenues	$917	$817	'
Operation and maintenance expenses	-345	-298	'
Depreciation and amortization	-210	-199	'
Taxes other than income taxes	-108	-102	'
Other income	4	5	'
Other deductions	-3	-4	'
Interest income	1	1	'
Interest expense and related charges	-88	-94	'
Income before income taxes	168	126	'
Income tax expense	-67	-41	'
Net income	101	85	'
Net income attributable to noncontrolling interests	-21	-18	'
Net income attributable to Oncor Holdings	80	67	'
Current assets:	'	'	'
Cash and cash equivalents	32	'	28
Restricted cash	58	'	52
Trade accounts receivable — net	390	'	385
Trade accounts and other receivables from affiliates	120	'	135
Income taxes receivable from EFH Corp.	22	'	16
Inventories	69	'	65
Accumulated deferred income taxes	27	'	32
Prepayments and other current assets	86	'	82
Total current assets	804	'	795
Restricted cash	16	'	16
Other investments	91	'	91
Property, plant and equipment — net	12,068	'	11,902
Goodwill	4,064	'	4,064
Regulatory assets — net	1,222	'	1,324
Other noncurrent assets	79	'	71
Total assets	18,344	'	18,263
Current liabilities:	'	'	'
Short-term borrowings	979	'	745
Long-term debt due currently	633	'	131
Trade accounts payable — nonaffiliates	147	'	178
Income taxes payable to EFH Corp.	85	'	23
Accrued taxes other than income	65	'	169
Accrued interest	64	'	95
Other current liabilities	118	'	135
Total current liabilities	2,091	'	1,476
Accumulated deferred income taxes	1,901	'	1,905
Long-term debt, less amounts due currently	4,852	'	5,381
Other noncurrent liabilities and deferred credits	1,747	'	1,822
Total liabilities	$10,591	'	$10,584

Goodwill_And_Identifiable_Inta2

Goodwill And Identifiable Intangible Assets (Goodwill) (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Goodwill [Line Items]	'	'
Balance, goodwill	$3,952	$3,952
Competitive Electric [Member]	'	'
Goodwill [Line Items]	'	'
Goodwill before impairment charges	18,342	18,342
Accumulated impairment charges	-14,390	-14,390
Balance, goodwill	$3,952	$3,952

Goodwill_And_Identifiable_Inta3

Goodwill And Identifiable Intangible Assets (Identifiable Intangible Assets Reported in the Balance Sheet) (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Finite-Lived and Indefinite-Lived Intangible [Line Items]	'	'
Gross Carrying Amount	$1,545	$1,535
Accumulated Amortization	857	822
Total identifiable intangible assets subject to amortization, net	688	713
Total identifiable intangible assets	1,652	1,679
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	9	11
Retail customer relationship [Member]	'	'
Finite-Lived and Indefinite-Lived Intangible [Line Items]	'	'
Gross Carrying Amount	463	463
Accumulated Amortization	408	402
Total identifiable intangible assets subject to amortization, net	55	61
Favorable purchase and sales contracts [Member]	'	'
Finite-Lived and Indefinite-Lived Intangible [Line Items]	'	'
Gross Carrying Amount	352	352
Accumulated Amortization	145	139
Total identifiable intangible assets subject to amortization, net	207	213
Capitalized in-service software [Member]	'	'
Finite-Lived and Indefinite-Lived Intangible [Line Items]	'	'
Gross Carrying Amount	360	355
Accumulated Amortization	203	192
Total identifiable intangible assets subject to amortization, net	157	163
Environmental allowances and credits [Member]	'	'
Finite-Lived and Indefinite-Lived Intangible [Line Items]	'	'
Gross Carrying Amount	207	209
Accumulated Amortization	23	20
Total identifiable intangible assets subject to amortization, net	184	189
Mining development costs [Member]	'	'
Finite-Lived and Indefinite-Lived Intangible [Line Items]	'	'
Gross Carrying Amount	163	156
Accumulated Amortization	78	69
Total identifiable intangible assets subject to amortization, net	$85	$87

Goodwill_And_Identifiable_Inta4

Goodwill And Identifiable Intangible Assets (Amortization Expense Related to Intangible Assets (including income statement line item)) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013
Finite-Lived Intangible Assets [Line Items]	'		'
Amortization expense	$35	[1]	$33	[1]
Depreciation and amortization [Member]	'		'
Finite-Lived Intangible Assets [Line Items]	'		'
Amortization expense	25		24
Retail customer relationship [Member] | Depreciation and amortization [Member] | Competitive Electric [Member]	'		'
Finite-Lived Intangible Assets [Line Items]	'		'
Amortization expense	6		6
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		6
Capitalized in-service software [Member] | Depreciation and amortization [Member] | Competitive Electric and Corporate and Other [Member]	'		'
Finite-Lived Intangible Assets [Line Items]	'		'
Amortization expense	11		10
Environmental allowances and credits [Member] | Fuel, purchased power costs and delivery fees [Member] | Competitive Electric [Member]	'		'
Finite-Lived Intangible Assets [Line Items]	'		'
Amortization expense	4		3
Mining development costs [Member] | Depreciation and amortization [Member] | Competitive Electric [Member]	'		'
Finite-Lived Intangible Assets [Line Items]	'		'
Amortization expense	$8		$8
[1]	Amounts recorded in depreciation and amortization totaled $25 million and $24 million for the three months ended March 31, 2014 and 2013, respectively.

Goodwill_And_Identifiable_Inta5

Goodwill And Identifiable Intangible Assets (Estimated Amortization of Intangible Assets) (Details) (USD $)	Mar. 31, 2014
In Millions, unless otherwise specified
Estimated Amortization Expense	'
2014	$134
2015	123
2016	101
2017	78
2018	$58

Borrowing_Facilities_and_Debt_1

Borrowing Facilities and Debt (Debtor-In-Possession (DIP) Facilities) (Details) (USD $)

Mar. 31, 2014

Mar. 31, 2014

Apr. 29, 2014

2-May-14

2-May-14

2-May-14

2-May-14

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

Apr. 29, 2014

2-May-14

Energy Future Intermediate Holding CO LLC [Member]

Energy Future Intermediate Holding CO LLC [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Commitment From Certain Financial Institutions Pending Bankruptcy Court Authorization [Member]

Commitment From Certain Financial Institutions Pending Bankruptcy Court Authorization [Member]

Commitment From Certain Financial Institutions Pending Bankruptcy Court Authorization [Member]

Commitment From Certain Financial Institutions Pending Bankruptcy Court Authorization [Member]

Commitment From Certain Financial Institutions Pending Bankruptcy Court Authorization [Member]

Amounts Authorized By Bankruptcy Court [Member]

Senior Secured Debt [Member]

Senior Secured Debt [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]

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]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [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]

Debtor-In-Possession Facility [Member]

Debtor-In-Possession Facility [Member]

Debtor-In-Possession Facility [Member]

Debtor-In-Possession Facility [Member]

Debtor-In-Possession Facility [Member]

Debtor-In-Possession Facility [Member]

Debtor-In-Possession Facility [Member]

Debtor-In-Possession Facility [Member]

Debtor-In-Possession Facility [Member]

Debtor-In-Possession Facility [Member]

Debtor-In-Possession Facility [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]

Energy Future Intermediate Holding CO LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Senior Secured Super-Priority Revolving Credit Facility [Member]

Senior Secured Super-Priority Delayed Draw Term Loan Facility [Member]

Letter of Credit, Delayed Draw Term Loan, Mining Reclamation [Member]

Senior Secured Super-Priority Term Loan [Member]

Mining Reclamation Carve-Out Election Facility [Member]

Second Lien Debtor-in-Possession Facility [Member]

First Lien Debtor-in-Possession Facility [Member]

Second Lien Debtor-in-Possession Facility [Member]

Mandatorily 8% Convertible Second Lien Subordinated Secured Financing Tranche A-1 Notes due 2016 [Member]

Debtor-In-Possession Facility [Member]

Debtor-In-Possession Facility [Member]

Debtor-In-Possession Facility [Member]

Debtor-In-Possession Facility [Member]

Debtor-In-Possession Facility [Member]

Debtor-In-Possession Facility [Member]

Senior Secured Super-Priority Revolving Credit Facility [Member]

Senior Secured Super-Priority Delayed Draw Term Loan Facility [Member]

Senior Secured Super-Priority Term Loan [Member]

Senior Secured Super-Priority Term Loan [Member]

Line of Credit Facility [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debtor-in-Possession Financing, Amount Arranged

'

'

'

$533,000,000

$1,100,000,000

$1,100,000,000

$700,000,000

$1,100,000,000

'

'

'

'

'

$4,475,000,000

$1,950,000,000

$1,100,000,000

$1,425,000,000

$5,400,000,000

$2,330,000,000

Debtor-In-Possession Financing, Term Loan Facility, Amounts Funded To A Collateral Account

'

'

'

'

'

'

500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Term

'

'

'24 months

'

'

'

'

'

'

'

'24 months

'24 months

'

'

'

'

'

'

'

Debt Instrument, Extension Fee, Twenty-Fifth Through Thirtieth Month

'

'

0.25%

'

'

'

'

'

'

0.25%

'

'

'

'

'

'

'

'

'

Debtor-in-Possession Financing, Second-lien, Amount

'

'

'

'

'

'

'

'

'

'

'

1,900,000,000

'

'

'

'

'

'

'

Debtor-In-Possession Financing, Closing Fee Paid In Payment-In-Kind Interest

'

'

'

'

'

'

'

'

'

'

'

$95,000,000

'

'

'

'

'

'

'

Second Lien Debtor-in-Possession Facility, Equity Conversion, Prorated Conversion, Equity Percentage

'

'

'

'

'

'

'

'

'

'

'

64.00%

'

'

'

'

'

'

'

Debt Instrument, Interest Rate, Stated Percentage

6.88%

10.00%

'

'

'

'

'

'

'

'

'

'

8.00%

'

'

'

'

'

'

Second Lien Debtor-in-Possession Facility, Interest Rate Terms, Alternative Interest Rate if Court does not Approve Amendment in Certain Number of Days, Number of Days

'

'

'

'

'

'

'

'

'90 days

'

'

'90 days

'

'

'

'

'

'

'

Borrowing_Facilities_and_Debt_2

Borrowing Facilities and Debt (Borrowings Under Other Credit Facilities) (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Short-term Debt [Line Items]	'	'
Short-term borrowings	$2,054	$2,054
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)	4.74%	4.67%

Borrowing_Facilities_and_Debt_3

Borrowing Facilities and Debt (Credit Facilities) (Details) (USD $)

3 Months Ended

1 Months Ended

3 Months Ended

1 Months Ended

In Millions, unless otherwise specified

Mar. 31, 2014

Mar. 31, 2013

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

31-May-14

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]

Subsequent Event [Member]

Pollution control revenue bonds [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Letter of Credit [Member]

Letter of Credit [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Revolving Credit Facility maturing October 2016 [Member]

Letter of Credit Facility maturing October 2017 [Member]

Letter of Credit Facility maturing October 2014 [Member]

Credit Facilities [Line Items]

'

'

'

'

'

'

'

'

'

'

Facility Limit

'

'

'

$3,116

'

$2,054

[1]

$2,054

[1]

$1,062

[2]

'

'

Cash Borrowings

'

'

'

3,116

'

'

2,054

[1]

1,062

[2]

'

'

Available L/C Capacity

'

'

'

0

'

'

0

0

'

'

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, Current Maturities

'

'

'

'

'

'

'

'

42

'

Repayments of Debt

'

'

'

'

185

'

'

'

'

'

Letters Of Credit Issued To Affiliated Party

'

'

'

'

'

'

'

157

'

'

Letters Of Credit Drawn By Affiliated Party

'

'

'

'

'

'

'

100

'

'

Restricted cash

0

'

0

'

'

'

'

660

'

'

Reduction of Restricted Cash Related To TCEH Letter of Credit Facility

285

0

'

'

'

'

'

'

'

'

Restricted Cash, Amount supported in letters of credit outstanding

'

'

'

'

'

'

'

656

'

'

Resticted cash, additional letters of credit that can be supported

'

'

'

'

'

'

'

4

'

'

Letters of Credit Drawn By Nonaffiliated Counterparties

'

'

'

'

'

'

'

'

'

$5

[1]

Facility used for borrowings for general corporate purposes. Borrowings are classified as borrowings under credit facilities. Borrowings under the facility bore interest at LIBOR plus 4.50%, and a commitment fee was payable quarterly in arrears at a rate per annum equal to 1.00% of the average daily unused portion of the facility.

[2]

Facility, $42 million of which has a maturity date of 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.

Borrowing_Facilities_and_Debt_4

Borrowing Facilities and Debt (Debt) (Details) (USD $)	Mar. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Debt Instrument [Line Items]	'		'
Long-term debt due currently	$38,000		$38,198
Debt and capital lease obligations	38,000		38,198
Consolidation, Eliminations [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt	1,664		1,664
EFH Corp. [Member]	'		'
Debt Instrument [Line Items]	'		'
Unamortized fair value premium (discount)	-118	[1]	-121	[1]
Debt and capital lease obligations	579		581
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 due currently	2		2
Debt Instrument, Interest Rate, Stated Percentage	9.75%		'
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 due currently	3		3
Debt Instrument, Interest Rate, Stated Percentage	10.00%		'
EFH Corp. [Member] | Fixed Senior Notes [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term debt due currently	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 due currently	33		33
Debt Instrument, Interest Rate, Stated Percentage	10.88%		'
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 due currently	27		27
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 due currently	90	[2]	90	[2]
Debt Instrument, Interest Rate, Stated Percentage	5.55%	[2]	'
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	281		281
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 due currently	201	[2]	201	[2]
Debt Instrument, Interest Rate, Stated Percentage	6.50%	[2]	'
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	545		545
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 due currently	291	[2]	291	[2]
Debt Instrument, Interest Rate, Stated Percentage	6.55%	[2]	'
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	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 due currently	42	[3]	46	[3]
Unamortized fair value premium (discount)	8	[1],[3]	9	[1],[3]
Debt Instrument, Interest Rate, Stated Percentage	8.82%	[3]	'
Energy Future Intermediate Holding CO LLC [Member]	'		'
Debt Instrument [Line Items]	'		'
Unamortized premium	265		284
Unamortized discount	-142		-146
Debt and capital lease obligations	7,832		7,847
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 due currently	2		2
Debt Instrument, Interest Rate, Stated Percentage	9.75%		'
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 due currently	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 due currently	3,482		3,482
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 due currently	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 due currently	1,750		1,750
Debt Instrument, Interest Rate, Stated Percentage	11.75%		'
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 due currently	1,566		1,566
Energy Future Competitive Holdings Company [Member]	'		'
Debt Instrument [Line Items]	'		'
Unamortized fair value premium (discount)	-5	[1]	-6	[1]
Debt and capital lease obligations	65		66
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 due currently	29	[4]	29	[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 due currently	32	[4]	34	[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 due currently	1	[5]	1	[5]
Effective interest rate (as a percent)	1.04%	[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 due currently	8		8
Debt Instrument, Interest Rate, Stated Percentage	8.18%		'
Texas Competitive Electric Holdings Company LLC [Member]	'		'
Debt Instrument [Line Items]	'		'
Capital lease obligations	49		52
Other	3		3
Unamortized discount	-96		-103
Debt and capital lease obligations	29,524		29,704
Texas Competitive Electric Holdings Company LLC [Member] | Pollution control revenue bonds [Member]	'		'
Debt Instrument [Line Items]	'		'
Unamortized fair value premium (discount)	-103	[1]	-105	[1]
Texas Competitive Electric Holdings Company LLC [Member] | Senior Secured Debt [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term debt due currently	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 due currently	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 due currently	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 due currently	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 due currently	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 due currently	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	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 due currently	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	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 due currently	1,749		1,749
Texas Competitive Electric Holdings Company LLC [Member] | Term loan Facilities [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term debt due currently	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 due currently	3,809	[5],[6]	3,809	[5],[6]
Interest rate at period end (as a percent)	3.74%	[5],[6]	'
Texas Competitive Electric Holdings Company LLC [Member] | Term loan Facilities [Member] | TCEH Term Loan Facilities maturing October 10, 2014 [Member] | Consolidation, Eliminations [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term debt due currently	19	[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	18,077	[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 due currently	15,691	[2],[5],[6]	15,691	[2],[5],[6]
Interest rate at period end (as a percent)	4.74%	[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	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 due currently	42	[5]	42	[5]
Interest rate at period end (as a percent)	3.74%	[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 due currently	1,020	[5]	1,020	[5]
Interest rate at period end (as a percent)	4.74%	[5]	'
Texas Competitive Electric Holdings Company LLC [Member] | Fixed/Floating Series [Member] | Sabine River Authority of Texas [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term debt due currently	'		'
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 due currently	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 due currently	111		111
Debt Instrument, Interest Rate, Stated Percentage	7.70%		'
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 due currently	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 due currently	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 due currently	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 due currently	17	[9]	97	[9]
Effective interest rate (as a percent)	0.29%	[9]	'
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 due currently	2	[10]	62	[10]
Effective interest rate (as a percent)	0.39%	[10]	'
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 due currently	0		45
Effective interest rate (as a percent)	0.00%		'
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 due currently	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 due currently	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 due currently	31	[11]	31	[11]
Debt Instrument, Interest Rate, Stated Percentage	5.40%	[11]	'
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 due currently	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 due currently	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 due currently	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 due currently	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 due currently	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 due currently	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 due currently	35		36
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 due currently	$4		$4
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%		'
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%		'
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. Pursuant to the terms of the Restructuring Support and Lock-Up Agreement, the debt is expected to be cancelled in connection with the Restructuring Plan, except for the TCEH 4.737% Term Loan Facilities. March 31, 2014 December 31, 2013EFH Corp. 5.55% Fixed Series P Senior Notes due November 15, 2014$281 $281EFH Corp. 6.50% Fixed Series Q Senior Notes due November 15, 2024545 545EFH Corp. 6.55% Fixed Series R Senior Notes due November 15, 2034456 456TCEH 4.737% 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 $1,664
[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 March 31, 2014.
[6]	At March 31, 2014, interest rate was swapped to fixed on $18.077 billion principal amount of maturities through October 2014 and up to an aggregate $12.6 billion principal amount from October 2014 through October 2017. See discussion below regarding termination of the agreements following the Bankruptcy Filing.
[7]	Swaps related to an aggregate $1.5 billion principal amount of debt expired in 2014. Per the terms of the transactions, the notional amount of swaps entered into in 2011 grew by $1.388 billion in 2014, substantially offsetting the expired swaps.
[8]	These swaps were effective from October 2014 through October 2017. The $12.6 billion notional amount of swaps included $3 billion that expire in October 2015 with the remainder expiring in October 2017.
[9]	Interest rates in effect at March 31, 2014. This series is in a daily interest rate mode and is supported by long-term irrevocable letters of credit.
[10]	Interest rate in effect at March 31, 2014. This series is in a weekly interest rate mode and is supported by long-term irrevocable letters of credit.
[11]	This series is in the multiannual interest rate mode and is 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.

Borrowing_Facilities_and_Debt_5

Borrowing Facilities and Debt (2014 Debt-Related Activity) (Details) (USD $)	3 Months Ended		1 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014
			Pollution control revenue bonds [Member]
			Texas Competitive Electric Holdings Company LLC [Member]
Debt Instrument [Line Items]	'	'	'
Repurchases of long-term debt	$191	$16	'
Repayments of Debt	'	'	185
Repayments of principal at scheduled maturity dates	3	'	'
Repayments of contractual payments under capitalized lease obligations	$3	'	'

Borrowing_Facilities_and_Debt_6

Borrowing Facilities and Debt (Information Regarding Other Significant Outstanding Debt) (Details) (USD $)

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Apr. 30, 2014

In Millions, unless otherwise specified

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]

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]

Until June 1, 2016 [Member]

Subsequent Event [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]

Senior Notes [Member]

Texas Competitive Electric Holdings Company LLC [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]

10.50 / 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]

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]

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]

Energy Future Intermediate Holding CO LLC [Member]

Financial guarantee [Member]

Consolidation, Eliminations [Member]

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

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest Payment Amount, Election To Use Permitted Grace Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$123

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%

'

'

'

'

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%

'

'

'

'

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%

'

10.25%

'

'

'

12.00%

'

'

'

'

11.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

7.38%

'

10.50%

'

'

'

12.25%

'

'

'

'

11.75%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

0.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity

'

'

3,116

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,054

[1]

'

'

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%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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%

'

Notes, loans and other debt (Note 5)

$38,000

$38,198

'

'

$503

$503

$3,482

$3,482

$406

$406

$1,750

$1,750

$1,571

$1,750

$1,750

$1,566

$1,566

$60

$4,874

$363

$1,833

[2]

$1,833

[2]

$1,749

$1,749

$22,616

$3,809

[3],[4]

$3,809

[3],[4]

$19

[3],[4]

$15,691

[2],[3],[4]

$15,691

[2],[3],[4]

$42

[3]

$42

[3]

$1,020

[3]

$1,020

[3]

'

'

'

[1]

Facility used for borrowings for general corporate purposes. Borrowings are classified as borrowings under credit facilities. Borrowings under the facility bore interest at LIBOR plus 4.50%, and a commitment fee was payable quarterly in arrears at a rate per annum equal to 1.00% of the average daily unused portion of the facility.

[2]

Excludes the following debt held by EFIH or EFH Corp. (parent entity) and eliminated in consolidation. Pursuant to the terms of the Restructuring Support and Lock-Up Agreement, the debt is expected to be cancelled in connection with the Restructuring Plan, except for the TCEH 4.737% Term Loan Facilities. March 31, 2014 December 31, 2013EFH Corp. 5.55% Fixed Series P Senior Notes due November 15, 2014$281 $281EFH Corp. 6.50% Fixed Series Q Senior Notes due November 15, 2024545 545EFH Corp. 6.55% Fixed Series R Senior Notes due November 15, 2034456 456TCEH 4.737% 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 $1,664

[3]

Interest rates in effect at March 31, 2014.

[4]

At March 31, 2014, interest rate was swapped to fixed on $18.077 billion principal amount of maturities through October 2014 and up to an aggregate $12.6 billion principal amount from October 2014 through October 2017. See discussion below regarding termination of the agreements following the Bankruptcy Filing.

Borrowing_Facilities_and_Debt_7

Borrowing Facilities and Debt (Fair Value of Long-Term Debt) (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Borrowings under credit facilities (Note 5)	$2,054	$2,054
Carrying Amount [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Long-term debt (including current maturities)	37,951	38,146
Level 2 [Member] | Fair Value [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Long-term debt (including current maturities)	24,834	24,653
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	1,458	1,397
Revolving Credit Facility [Member] | Texas Competitive Electric Holdings Company LLC [Member]	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'
Borrowings under credit facilities (Note 5)	$2,054	$2,054

Borrowing_Facilities_and_Debt_8

Borrowing Facilities and Debt (TCEH Interest Rate Swap Transactions) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013		Dec. 31, 2013
Derivative [Line Items]	'		'		'
Unrealized net gain	$65	[1]	$150	[1]	'
Interest Rate Swap [Member]	'		'		'
Derivative [Line Items]	'		'		'
Derivative, Notional Amount	32,377	[2]	'		32,490	[2]
Interest Rate Swap [Member] | Texas Competitive Electric Holdings Company LLC [Member]	'		'		'
Derivative [Line Items]	'		'		'
Realized net loss	-145		-151		'
Unrealized net gain	64		148		'
Total	-81		-3		'
Accumulated Unrealized Gain (Loss) On Interest Rate Derivative Instruments Not Designated As Hedging Instruments Net Of Nonperformance Risk Adjustments	948		'		1,012
Accumulated unrealized gain (loss) on interest rate derivative instruments not designated as hedging instruments other comprehensive income, pre-tax	55		'		56
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]	'		'
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		'		'
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]	'		'
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]	'		'
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]	'		'
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]	'		'
Basis swap [Member]	'		'		'
Derivative [Line Items]	'		'		'
Derivative, Notional Amount	1,050		'		1,050
Basis swap [Member] | Texas Competitive Electric Holdings Company LLC [Member] | October 2012 through October 2014 [Member]	'		'		'
Derivative [Line Items]	'		'		'
Derivative, Notional Amount	1,050		'		'
Debt obligation expiring in 2012 [Member] | Interest Rate Swap [Member] | Texas Competitive Electric Holdings Company LLC [Member]	'		'		'
Derivative [Line Items]	'		'		'
Long-term debt, gross	1,500		'		'
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	1,388		'		'
Line of Credit [Member] | Term Loan Facilities maturing October 2014 [Member] | Texas Competitive Electric Holdings Company LLC [Member]	'		'		'
Derivative [Line Items]	'		'		'
Derivative, Notional Amount	$18,077	[4]	'		'
[1]	Three months ended March 31, 2014 and 2013 amounts include net gains totaling $64 million and $148 million, respectively, related to TCEH swaps (see Note 5) and net gains totaling $1 million and $2 million, respectively, related to EFH Corp. swaps substantially closed through offsetting positions.
[2]	Includes notional amount of interest rate swaps that had maturity dates through October 2014 as well as notional amount of swaps effective from October 2014 that had maturity dates through October 2017 (see Note 5).
[3]	These swaps were effective from October 2014 through October 2017. The $12.6 billion notional amount of swaps included $3 billion that expire in October 2015 with the remainder expiring in October 2017.
[4]	Swaps related to an aggregate $1.5 billion principal amount of debt expired in 2014. Per the terms of the transactions, the notional amount of swaps entered into in 2011 grew by $1.388 billion in 2014, substantially offsetting the expired swaps.

Commitments_And_Contingencies_

Commitments And Contingencies (Narrative) (Details) (USD $)

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Feb. 29, 2012

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

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]

Sierra Club Versus EFH Corp and Luminant (Martin Lake Generation Facility) [Member]

Sierra Club Versus EFH Corp And Luminant (Big Brown Generation Facility) [Member]

Maximum [Member]

Maximum [Member]

Minimum [Member]

Minimum [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]

Pending Litigation [Member]

Pending Litigation [Member]

Sierra Club Versus EFH Corp and Luminant (Martin Lake Generation Facility) [Member]

EPA Versus Luminant and Big Brown Power Company (Big Brown and Martin Lake Generation Facilities) [Member]

Sierra Club Versus EFH Corp and Luminant (Martin Lake Generation Facility) [Member]

EPA Versus Luminant and Big Brown Power Company (Big Brown and Martin Lake Generation Facilities) [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]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Pending Litigation [Member]

Commitments and Contingencies [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum exposure, undiscounted

'

'

'

'

'

'

$1,900,000,000

$500,000,000

$1,400,000,000

'

'

'

'

'

'

'

Letters of Credit

'

656,000,000

350,000,000

20,000,000

61,000,000

225,000,000

'

'

'

'

'

'

'

'

'

'

Loss Contingency, Damages Sought, Value

'

'

'

'

'

'

'

'

'

'

147,000,000

337,000,000

'

'

'

'

Loss Contingency Damages Sought Value Per Day

'

'

'

'

'

'

'

'

'

'

'

'

37,500

37,500

32,500

32,500

Long-term debt, current maturities

$19,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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)	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2013	Dec. 31, 2012
Equity	'	'	'	'
Common Stock, Shares Authorized	2,000,000,000	'	2,000,000,000	'
Common stock, shares outstanding	1,669,861,383	1,669,861,383	1,681,908,837	1,680,539,245

Equity_Changes_to_Equity_Detai

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

3 Months Ended

3 Months Ended

In Millions, unless otherwise specified

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2013

Dec. 31, 2012

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

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

($13,255)

($10,923)

$2

[1]

$2

[1]

$2

[2]

$2

[2]

$7,962

$7,959

($21,157)

($18,939)

($63)

($47)

$1

$102

Net loss

-609

-569

'

'

'

'

'

'

-609

-569

'

'

'

'

Effects of stock-based incentive compensation plans

2

2

'

'

'

'

2

2

'

'

'

'

'

'

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

-1

-2

'

'

'

'

'

'

'

'

-1

-2

'

'

Net effects of cash flow hedges

0

2

'

'

'

'

'

'

'

'

'

2

'

'

Net effects related to Oncor

0

1

'

'

'

'

'

'

'

'

'

1

'

'

Investments by noncontrolling interest

1

1

'

'

'

'

'

'

'

'

'

'

1

1

Stockholders' Equity, Other

-2

'

'

'

'

'

'

'

'

'

'

'

-2

'

Ending balance

($13,864)

($11,488)

$2

[1]

$2

[1]

$2

[2]

$2

[2]

$7,964

$7,961

($21,766)

($19,508)

($64)

($46)

$0

$103

[1]

Authorized shares totaled 2,000,000,000 at March 31, 2014. Outstanding shares totaled 1,669,861,383 and 1,669,861,383 at March 31, 2014 and December 31, 2013, respectively.

[2]

Authorized shares totaled 2,000,000,000 at March 31, 2013. Outstanding shares totaled 1,681,908,837 and 1,680,539,245 at March 31, 2013 and December 31, 2012, respectively.

Equity_Accumulated_Other_Compr

Equity (Accumulated Other Comprehensive Income (Loss)) (Details) (USD $)

3 Months Ended

3 Months Ended

In Millions, unless otherwise specified

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2013

Dec. 31, 2012

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2013

Dec. 31, 2012

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Dedesignated Cash Flow Hedges – Interest Rate Swaps [Member]

Dedesignated Cash Flow Hedges – Interest Rate Swaps [Member]

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]

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]

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]

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]

Accumulated Other Comprehensive Income (Loss) [Roll Forward]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Beginning balance

($63)

($47)

($56)

($56)

($61)

($64)

($8)

($7)

$15

$17

'

'

'

'

'

'

Amounts reclassified from accumulated other comprehensive income (loss) and reported in:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Operating costs

'

'

'

'

'

'

'

'

'

'

-1

-1

0

0

-1

-1

Depreciation and amortization

-330

-351

'

'

'

'

'

'

'

'

-1

'

-1

'

0

'

Selling, general and administrative expenses

-200

-162

'

'

'

'

'

'

'

'

-1

-1

0

0

-1

-1

Interest expense and related charges (Note 12)

-863

-784

'

'

'

'

'

'

'

'

1

4

1

4

0

0

Income Tax Expense (Benefit)

360

475

'

'

'

'

'

'

'

'

1

0

0

-1

1

1

Equity in earnings of unconsolidated subsidiaries (net of tax) (Note 3)

80

67

'

'

'

'

'

'

'

'

0

-1

0

0

0

-1

Total other comprehensive income (loss)

-1

1

'

'

'

'

'

'

'

'

-1

1

0

3

-1

-2

Ending balance

($64)

($46)

($56)

($56)

($61)

($64)

($8)

($7)

$15

$17

'

'

'

'

'

'

Fair_Value_Measurements_Schedu

Fair Value Measurements (Schedule of Assets and Liabilities Measured at Fair Value on a Recurring Basis) (Details) (USD $)	Mar. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Assets:	'		'
Nuclear decommissioning trust	$810		$791
Equity securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	530	[1]	521	[1]
Debt securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	280	[2]	270	[2]
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]	'		'
Assets:	'		'
Total assets	505		491
Liabilities:	'		'
Total liabilities	284		231
Fair Value, Measurements, Recurring [Member] | Level 1 [Member] | Equity securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	336	[3]	330	[3]
Fair Value, Measurements, Recurring [Member] | Level 1 [Member] | Debt securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	'		'
Fair Value, Measurements, Recurring [Member] | Level 1 [Member] | Commodity contracts [Member]	'		'
Assets:	'		'
Derivative Assets	169		161
Liabilities:	'		'
Derivative Liabilities	284		231
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	937		1,098
Liabilities:	'		'
Total liabilities	122		94
Fair Value, Measurements, Recurring [Member] | Level 2 [Member] | Equity securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	194	[3]	191	[3]
Fair Value, Measurements, Recurring [Member] | Level 2 [Member] | Debt securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	280	[3]	270	[3]
Fair Value, Measurements, Recurring [Member] | Level 2 [Member] | Commodity contracts [Member]	'		'
Assets:	'		'
Derivative Assets	394		570
Liabilities:	'		'
Derivative Liabilities	41		14
Fair Value, Measurements, Recurring [Member] | Level 2 [Member] | Interest Rate Swap [Member]	'		'
Assets:	'		'
Derivative Assets	69		67
Liabilities:	'		'
Derivative Liabilities	81		80
Fair Value, Measurements, Recurring [Member] | Level 3 [Member]	'		'
Assets:	'		'
Total assets	64	[4]	57	[4]
Liabilities:	'		'
Total liabilities	961	[4]	1,030	[4]
Fair Value, Measurements, Recurring [Member] | Level 3 [Member] | Equity securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	'		'
Fair Value, Measurements, Recurring [Member] | Level 3 [Member] | Debt securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	'		'
Fair Value, Measurements, Recurring [Member] | Level 3 [Member] | Commodity contracts [Member]	'		'
Assets:	'		'
Derivative Assets	64	[4]	57	[4]
Liabilities:	'		'
Derivative Liabilities	13	[4]	18	[4]
Fair Value, Measurements, Recurring [Member] | Level 3 [Member] | Interest Rate Swap [Member]	'		'
Assets:	'		'
Derivative Assets	'		'
Liabilities:	'		'
Derivative Liabilities	948	[4]	1,012	[4]
Fair Value, Measurements, Recurring [Member] | Total [Member]	'		'
Assets:	'		'
Total assets	1,506		1,646
Liabilities:	'		'
Total liabilities	1,367		1,355
Fair Value, Measurements, Recurring [Member] | Total [Member] | Equity securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	530	[3]	521	[3]
Fair Value, Measurements, Recurring [Member] | Total [Member] | Debt securities [Member]	'		'
Assets:	'		'
Nuclear decommissioning trust	280	[3]	270	[3]
Fair Value, Measurements, Recurring [Member] | Total [Member] | Commodity contracts [Member]	'		'
Assets:	'		'
Derivative Assets	627		788
Liabilities:	'		'
Derivative Liabilities	338		263
Fair Value, Measurements, Recurring [Member] | Total [Member] | Interest Rate Swap [Member]	'		'
Assets:	'		'
Derivative Assets	69		67
Liabilities:	'		'
Derivative Liabilities	$1,029		$1,092
[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 3.91% and 3.96% at March 31, 2014 and December 31, 2013, respectively, and an average maturity of 5 years and 6 years at March 31, 2014 and December 31, 2013, respectively.
[3]	The nuclear decommissioning trust investment is included in the other investments line in the balance sheet. See Note 12.
[4]	See table below for description of Level 3 assets and liabilities.

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 $)	3 Months Ended		12 Months Ended
	Mar. 31, 2014		Dec. 31, 2013
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Assets	$64,000,000	[1]	$57,000,000	[1]
Liabilities	-961,000,000	[1]	-1,030,000,000	[1]
Derivative Assets (Liabilities), at Fair Value, Net	-897,000,000	[1]	-973,000,000	[1]
Electricity purchases and sales [Member] | Valuation Model [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Assets	1,000,000	[1]	2,000,000	[1]
Liabilities	-1,000,000	[1]	-2,000,000	[1]
Derivative Assets (Liabilities), at Fair Value, Net	0	[1]	0	[1]
Electricity spread options [Member] | Option Pricing Model [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Assets	16,000,000	[1]	15,000,000	[1]
Liabilities	-2,000,000	[1]	-2,000,000	[1]
Derivative Assets (Liabilities), at Fair Value, Net	14,000,000	[1]	13,000,000	[1]
Electricity congestion revenue rights [Member] | Market Approach [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Assets	39,000,000	[1],[2]	35,000,000	[1],[2]
Liabilities	-3,000,000	[1],[2]	-2,000,000	[1],[2]
Derivative Assets (Liabilities), at Fair Value, Net	36,000,000	[1],[2]	33,000,000	[1],[2]
Coal purchases [Member] | Market Approach [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Assets	2,000,000	[1],[2]	0	[1],[2]
Liabilities	-6,000,000	[1],[2]	-11,000,000	[1],[2]
Derivative Assets (Liabilities), at Fair Value, Net	-4,000,000	[1],[2]	-11,000,000	[1],[2]
Interest Rate Swap [Member] | Market Approach [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Assets	0	[1]	0	[1]
Liabilities	-948,000,000	[1]	-1,012,000,000	[1]
Derivative Assets (Liabilities), at Fair Value, Net	-948,000,000	[1]	-1,012,000,000	[1]
Other [Member]	'		'
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]	'		'
Assets	6,000,000	[1]	5,000,000	[1]
Liabilities	-1,000,000	[1]	-1,000,000	[1]
Derivative Assets (Liabilities), at Fair Value, Net	5,000,000	[1]	4,000,000	[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)	35	[1],[3],[4]	25	[1],[3],[4]
Hourly price curve shape (in usd per MWh)	20	[1],[3],[5]	20	[1],[3],[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],[3],[6]	45.00%	[1],[3],[6]
Power volatility (as a percent)	10.00%	[1],[3],[7]	10.00%	[1],[3],[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],[3],[8]	0	[1],[2],[3],[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],[3],[9]	0.00%	[1],[2],[3],[9]
Recovery rate (as a percent)	0.00%	[1],[10],[2],[3]	0.00%	[1],[10],[2],[3]
Illiquid price variances between mines	0	[1],[11],[2],[3]	0	[1],[11],[2],[3]
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	20.00%	[1],[12],[3]	25.00%	[1],[12],[3]
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]	45	[1],[3],[4]
Hourly price curve shape (in usd per MWh)	70	[1],[3],[5]	70	[1],[3],[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)	95.00%	[1],[3],[6]	95.00%	[1],[3],[6]
Power volatility (as a percent)	30.00%	[1],[3],[7]	30.00%	[1],[3],[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	25	[1],[2],[3],[8]	25	[1],[2],[3],[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],[3],[9]	40.00%	[1],[2],[3],[9]
Recovery rate (as a percent)	40.00%	[1],[10],[2],[3]	40.00%	[1],[10],[2],[3]
Illiquid price variances between mines	$1	[1],[11],[2],[3]	$1	[1],[11],[2],[3]
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	30.00%	[1],[12],[3]	35.00%	[1],[12],[3]
[1]	Electricity purchase and sales contracts include 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 were held by TCEH to hedge exposure to its variable rate debt (see Note 5).
[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]	The range of the inputs may be influenced by factors such as time of day, delivery period, season and location.
[4]	Based on the historical range of forward average monthly ERCOT West Hub prices.
[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 debt trading values. See discussion immediately below regarding Level 3 liabilities.

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
In Millions, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013		Mar. 31, 2014	Dec. 31, 2013
	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]		Interest Rate Swap [Member]	Interest Rate Swap [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	'		'		$1,252	'
Accumulated Unrealized Gain (Loss) On Interest Rate Derivative Instruments Not Designated As Hedging Instruments Net Of Nonperformance Risk Adjustments	'		'		948	1,012
Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'		'		'	'
Net asset (liability) balance at beginning of period	-973		29		'	'
Total unrealized valuation gains (losses)	-85		9		'	'
Purchases, issuances and settlements:	'		'		'	'
Purchases	9	[1]	4	[1]	'	'
Issuances	-1	[1]	0	[1]	'	'
Settlements	151	[1]	16	[1]	'	'
Transfers into Level 3	0	[2]	1	[2]	'	'
Transfers out of Level 3	2	[2]	0	[2]	'	'
Net change	76	[3]	30	[3]	'	'
Net asset (liability) balance at end of period	-897		59		'	'
Unrealized valuation gains (losses) relating to instruments held at end of period	($71)		$14		'	'
[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 in 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 loss from commodity hedging and trading activities. Changes in values of interest rate swaps transferred into Level 3 in third quarter 2013 are reported in the income statement in interest expense and related charges. Activity excludes changes in fair value in the month the positions 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 $)

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

2-May-14

31-May-14

31-May-14

Current assets [Member]

Current assets [Member]

Noncurrent assets [Member]

Noncurrent assets [Member]

Current liabilities [Member]

Current liabilities [Member]

Commodity contracts [Member]

Commodity contracts [Member]

Commodity contracts [Member]

Commodity contracts [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 Rate Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Subsequent Event [Member]

Current assets [Member]

Current assets [Member]

Noncurrent assets [Member]

Noncurrent assets [Member]

Current liabilities [Member]

Current liabilities [Member]

Current assets [Member]

Current assets [Member]

Noncurrent assets [Member]

Noncurrent assets [Member]

Current liabilities [Member]

Current liabilities [Member]

Commodity contracts [Member]

Interest Rate Swap [Member]

Derivatives, Fair Value [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative Asset, Fair Value, Portion Of Positions Terminated By Counterparties

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

60.00%

'

Derivative Liability, Fair Value, Portion Of Positions Terminated By Counterparties

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

Net Settlement Liability, Positions Terminated By Counterparties

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1,200,000,000

'

'

Derivative asset, Fair Value, Gross Asset

696,000,000

855,000,000

'

'

'

'

'

'

627,000,000

788,000,000

617,000,000

784,000,000

10,000,000

4,000,000

'

'

69,000,000

67,000,000

69,000,000

67,000,000

0

0

'

'

'

'

'

Derivative liabilities, Fair Value, Gross Asset

'

'

'

'

'

'

'

'

'

'

0

0

0

0

'

'

'

'

0

0

0

0

'

'

'

'

'

Derivative Assets And Liability, Fair Value, Gross Assets

'

'

686,000,000

851,000,000

10,000,000

4,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative asset, Fair Value, Gross Liability

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

0

0

'

'

'

Derivative liabilities, Fair Value, Gross Liability

-1,367,000,000

-1,355,000,000

'

'

'

'

'

'

-338,000,000

-263,000,000

'

'

'

'

-338,000,000

-263,000,000

-1,029,000,000

-1,092,000,000

'

'

'

'

-1,029,000,000

-1,092,000,000

'

'

'

Derivative Assets And Liability, Fair Value, Gross Liability

'

'

'

'

'

'

-1,367,000,000

-1,355,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative asset, Fair Value, Net

'

'

'

'

'

'

'

'

627,000,000

788,000,000

'

'

'

'

'

'

69,000,000

67,000,000

'

'

'

'

'

'

'

'

'

Derivative liabilities, Fair Value, Net

'

'

'

'

'

'

'

'

-338,000,000

-263,000,000

'

'

'

'

'

'

-1,029,000,000

-1,092,000,000

'

'

'

'

'

'

'

'

'

Derivative, Fair Value, Net

-671,000,000

-500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative Liability, Fair Value, Noncurrent Classified As Current Due To Event Of Default

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$593,000,000

$647,000,000

'

'

'

'

'

'

'

'

'

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

3 Months Ended

In Millions, unless otherwise specified

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

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]

Interest expense and related charges [Member]

Interest expense and related charges [Member]

Commodity contracts [Member]

Commodity contracts [Member]

Interest Rate Swap [Member]

Interest Rate Swap [Member]

Derivative Instruments, Gain (Loss) [Line Items]

'

'

'

'

'

'

'

'

Net gain (loss)

($261)

($203)

'

'

($179)

[1]

($200)

[1]

($82)

[2]

($3)

[2]

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

'

'

37

37

'

'

'

'

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

'

'

($1)

'

'

'

'

'

[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 12).

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 $)	Mar. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Derivatives, Fair Value [Line Items]	'		'
Derivative assets: Amounts Presented in Balance Sheet	$696		$855
Derivative assets: Offsetting Financial Instruments	-403	[1]	-456	[1]
Derivative assets: Financial Collateral (Received) Pledged	-201	[2]	-299	[2]
Derivative assets: Net Amounts	92		100
Derivative liabilities: Amounts Presented in Balance Sheet	-1,367		-1,355
Derivative liabilities: Offsetting Financial Instruments	403	[1]	456	[1]
Derivative liabilities: Financial Collateral (Received) Pledged	114	[2]	70	[2]
Derivative liabilities: Net Amounts	-850		-829
Derivative, Fair Value, Net	-671		-500
Derivative (Assets) Liability, Fair Value of Collateral, Net	-87	[2]	-229	[2]
Derivative Assets (Liability), Fair Value, Amount Offset Against Collateral	-758		-729
Commodity contracts [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative assets: Amounts Presented in Balance Sheet	627		788
Derivative assets: Offsetting Financial Instruments	-334	[1]	-389	[1]
Derivative assets: Financial Collateral (Received) Pledged	-201	[2]	-299	[2]
Derivative assets: Net Amounts	92		100
Derivative liabilities: Amounts Presented in Balance Sheet	-338		-263
Derivative liabilities: Offsetting Financial Instruments	181	[1]	168	[1]
Derivative liabilities: Financial Collateral (Received) Pledged	114	[2]	70	[2]
Derivative liabilities: Net Amounts	-43		-25
Interest Rate Swap [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative assets: Amounts Presented in Balance Sheet	69		67
Derivative assets: Offsetting Financial Instruments	-69	[1]	-67	[1]
Derivative assets: Financial Collateral (Received) Pledged	0	[2]	0	[2]
Derivative assets: Net Amounts	0		0
Derivative liabilities: Amounts Presented in Balance Sheet	-1,029		-1,092
Derivative liabilities: Offsetting Financial Instruments	222	[1]	288	[1]
Derivative liabilities: Financial Collateral (Received) Pledged	0	[2]	0	[2]
Derivative liabilities: Net Amounts	($807)		($804)
[1]	Offsetting 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.

Commodity_And_Other_Derivative5

Commodity And Other Derivative Contractual Assets And Liabilities (Derivative Volumes) (Details) (USD $)	Mar. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Interest rate swaps - Floating/fixed [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative, Notional Amount	$32,377	[1]	$32,490	[1]
Interest rate swaps - Basis [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Derivative, Notional Amount	$1,050		$1,050
Natural Gas Derivative [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Nonmonetary Notional Volume	2,282,000,000	[2]	2,150,000,000	[2]
Electricity (in GWh) [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Nonmonetary Notional Volume	14,541		16,482
Congestion Revenue RIghts (in GWh) [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Nonmonetary Notional Volume	80,702	[3]	77,799	[3]
Coal (in tons) [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Nonmonetary Notional Volume	12,000,000		9,000,000
Fuel oil (in gallons) [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Nonmonetary Notional Volume	27,000,000		26,000,000
Uranium (in pounds) [Member]	'		'
Derivatives, Fair Value [Line Items]	'		'
Nonmonetary Notional Volume	450,000		450,000
[1]	Includes notional amount of interest rate swaps that had maturity dates through October 2014 as well as notional amount of swaps effective from October 2014 that had maturity dates through October 2017 (see Note 5).
[2]	Represents gross notional forward sales, purchases and options transactions, locational basis swaps and other natural gas transactions.
[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 $)	Mar. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Credit Derivatives [Line Items]	'	'
Derivative, Net Liability Position, Aggregate Fair Value	$1,060	$1,107
Credit risk derivative with contingent feature [Member]	'	'
Credit Derivatives [Line Items]	'	'
Derivative, Net Liability Position, Aggregate Fair Value	8	4
Liquidity exposure associated with liabilities reduced by cash and letter of credit postings with the counterparties	7	3
Cross-default credit derivative [Member]	'	'
Credit Derivatives [Line Items]	'	'
Derivative, Net Liability Position, Aggregate Fair Value	1,052	1,103
Liquidity exposure associated with liabilities reduced by cash and letter of credit postings with the counterparties	12	6
Assets Needed for Immediate Settlement, Aggregate Fair Value	$1,112	$1,154

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 $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014
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	$800
Net exposure to those counterparties after taking into effect master netting arrangements, setoff provisions and collateral	176
Largest net exposure to single counterparty	$45
Credit risk exposure to Banking and financial sector percentage	86.00%
Net exposure to banking and financial sector percentage	43.00%

Related_Party_Transactions_Nar

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

3 Months Ended

3 Months Ended

3 Months Ended

1 Months Ended

In Millions, unless otherwise specified

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Feb. 28, 2014

Feb. 28, 2014

Feb. 28, 2014

Oncor [Member]

Oncor [Member]

Oncor [Member]

Oncor Holdings [Member]

Oncor Holdings [Member]

Sponsor Group [Member]

Sponsor Group [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]

Debt held by related party [Member]

Debt held by related party [Member]

Debt held by related party [Member]

Returned debt as dividend [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]

Collateral posted [Member]

Collateral posted [Member]

State and Local Jurisdiction [Member]

State and Local Jurisdiction [Member]

Internal Revenue Service (IRS) [Member]

Internal Revenue Service (IRS) [Member]

Internal Revenue Service (IRS) [Member]

Pension Plan, Defined Benefit [Member]

Pension Plan, Defined Benefit [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Oncor [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]

Oncor [Member]

Oncor [Member]

Oncor Holdings [Member]

Oncor Holdings [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Receivable Attributable to Income Taxes [Member]

Receivable Attributable to Income Taxes [Member]

Receivable Attributable to Income Taxes [Member]

Payable Attributable To Income Taxes [Member]

Payable Attributable To Income Taxes [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Pension Plan, Defined Benefit [Member]

Rating-Agencies-Downgrades

Texas Competitive Electric Holdings Company LLC [Member]

Senior Notes [Member]

Senior Notes [Member]

Senior Notes [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Oncor [Member]

Majority-Owned Subsidiary, Unconsolidated [Member]

EFH Corp. [Member]

Texas Competitive Electric Holdings Company LLC [Member]

Related Party Transaction [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Selling, general and administrative expenses from transactions with related party

'

'

$9

$8

'

'

'

$10

$10

$56

$62

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Related Party Transaction, Selling, General and Administrative Cost Paid in Transactions With Related Party

'

'

'

'

'

'

'

0

10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

0

-680

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term Debt, Gross

'

'

'

'

'

'

'

'

'

'

'

'

'

'

303

1,282

79

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Principal Amounts Cancelled, Payment as Dividend

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,360

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Related party transaction, amounts of transaction

'

'

'

'

'

'

'

'

'

'

'

241

225

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Due to Affiliate

'

'

'

'

'

'

'

'

'

'

'

120

'

135

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Delivery fee surcharge remitted to related party

'

'

'

'

'

'

'

'

'

'

'

4

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Due to affiliate, noncurrent

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

413

400

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Due from affiliate, current

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

61

5

63

7

'

'

'

23

51

'

'

'

'

'

Due to Affiliate, Current

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

28

'

'

18

18

'

'

'

Related party tax expense, due from affiliates, current

'

'

0

0

'

5

9

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Letter of credit posted as collateral

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9

9

'

'

'

'

'

'

'

'

Accounts receivable, related parties, noncurrent

'

'

845

'

838

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Defined Benefit Plan Contributions By Employer Excluding Affiliated Supplemental Plan

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

84

'

'

Defined Benefit Plan, Contributions by Employer

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20

64

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

'

'

'

'

'

'

'

'

'

'

'

$170

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Segment_Information_Details

Segment Information (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
	Reportable_segment
Segment Reporting Information [Line Items]	'	'
Number of reportable segments (in reportable segments)	2	'
Operating revenues (all Competitive Electric)	$1,517	$1,260
Equity in earnings of unconsolidated subsidiaries (net of tax) — Regulated Delivery (net of noncontrolling interest of $21 and $17)	80	67
Net income (loss):	-609	-569
Competitive Electric [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Operating revenues (all Competitive Electric)	1,517	1,260
Net income (loss):	-567	-547
Regulated Delivery [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Equity in earnings of unconsolidated subsidiaries (net of tax) — Regulated Delivery (net of noncontrolling interest of $21 and $17)	80	67
Net income (loss):	80	67
Corp. and Other [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Net income (loss):	-122	-89
Noncontrolling Interest [Member]	'	'
Segment Reporting Information [Line Items]	'	'
Equity in earnings of unconsolidated subsidiaries (net of tax) — Regulated Delivery (net of noncontrolling interest of $21 and $17)	$21	$17

Supplementary_Financial_Inform2

Supplementary Financial Information (Other Income and Deductions) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013
Other income:	'		'
Office space rental income	$3	[1]	$3	[1]
Insurance/litigation settlements	0	[2]	2	[2]
All other	6		3
Total other income	9		8
Other deductions:	'		'
Ongoing employee retirement benefit expense related to discontinued businesses	0	[1]	-1	[1]
All other	0		4
Total other deductions	$0		$3
[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
In Millions, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013
Interest Expense and Related Charges [Line Items]	'		'
Interest paid/accrued (including net amounts settled/accrued under interest rate swaps)	$831		$839
Interest expense on toggle notes payable in additional principal	49		41
Unrealized mark-to-market net (gain) loss on interest rate swaps	-65	[1]	-150	[1]
Amortization of interest rate swap losses at dedesignation of hedge accounting	-1		2
Amortization of fair value debt discounts resulting from purchase accounting	5		5
Amortization of debt issuance, amendment and extension costs and discounts	51		54
Capitalized interest	-7		-7
Total interest expense and related charges	863		784
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	-64		-148
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)		($2)
[1]	Three months ended March 31, 2014 and 2013 amounts include net gains totaling $64 million and $148 million, respectively, related to TCEH swaps (see Note 5) and net gains totaling $1 million and $2 million, respectively, related to EFH Corp. swaps substantially closed through offsetting positions.

Supplementary_Financial_Inform4

Supplementary Financial Information (Restricted Cash) (Details) (USD $)	Mar. 31, 2014		Dec. 31, 2013
In Millions, unless otherwise specified
Restricted Cash and Investments, Current	$664		$949
Restricted Cash and Investments, Noncurrent	0		0
Other Restricted Cash [Member]	'		'
Restricted Cash and Investments, Current	4		4
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	660	[1]	945	[1]
Restricted Cash and Investments, Noncurrent	$0		$0
[1]	At both March 31, 2014 and December 31, 2013, in consideration of the Bankruptcy Filing, all amounts have been classified as current. See Note 5 for discussion of letter of credit draws in 2014.

Supplementary_Financial_Inform5

Supplementary Financial Information (Trade Accounts Receivable and Allowance for Doubtful Accounts) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
Supplementary Financial Information [Abstract]	'	'	'
Wholesale and retail trade accounts receivable	$652	'	$732
Allowance for uncollectible accounts	-17	-10	'
Trade accounts receivable — net	635	'	718
Unbilled Receivables, Current	209	'	272
Allowance for Doubtful Accounts Receivable [Roll Forward]	'	'	'
Allowance for uncollectible accounts receivable at beginning of period	14	9	'
Increase for bad debt expense	10	6	'
Decrease for account write-offs	-7	-5	'
Allowance for uncollectible accounts receivable at end of period	$17	$10	'

Supplementary_Financial_Inform6

Supplementary Financial Information (Inventories by Major Category and Other Investments) (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Inventories by Major Category	'	'
Materials and supplies	$213	$216
Fuel stock	142	154
Natural gas in storage	18	29
Total inventories	373	399
Other Investments	'	'
Nuclear plant decommissioning trust	810	791
Assets related to employee benefit plans, including employee savings programs, net of distributions	61	61
Land	37	37
Miscellaneous other	2	2
Total other investments	$910	$891

Supplementary_Financial_Inform7

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

3 Months Ended

3 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Mar. 31, 2014

Mar. 31, 2013

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

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

'

'

'

3.91%

3.96%

'

'

Decommissioning Fund Investments, Debt securities, average maturity

'

'

'

'5 years

'6 years

'

'

Cost

$530

[1]

'

$521

[1]

$272

[1],[2]

$266

[1],[2]

$258

[1],[3]

$255

[1],[3]

Unrealized gain

287

'

279

10

[2]

8

[2]

277

[3]

271

[3]

Unrealized loss

-7

'

-9

-2

[2]

-4

[2]

-5

[3]

-5

[3]

Fair market value

810

'

791

280

[2]

270

[2]

530

[3]

521

[3]

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

'

'

'

111

'

'

'

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

'

'

'

57

'

'

'

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

'

'

'

112

'

'

'

Realized gains

1

0

'

'

'

'

'

Proceeds from sales of securities

33

41

'

'

'

'

'

Investments in securities

($37)

($45)

'

'

'

'

'

[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 3.91% and 3.96% at March 31, 2014 and December 31, 2013, respectively, and an average maturity of 5 years and 6 years at March 31, 2014 and December 31, 2013, respectively.

[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_Inform8

Supplementary Financial Information (Property, Plant and Equipment) (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
Supplementary Financial Information [Abstract]	'	'
Property, plant and equipment — net (Note 12)	$17,558,000,000	$17,791,000,000
Less accumulated amortization/depreciation	$8,500,000,000	$8,200,000,000

Supplementary_Financial_Inform9

Supplementary Financial Information (Asset Retirement and Mining Reclamation Obligations) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'	'
Beginning balance, Liability	$524	'
Additions:	'	'
Accretion	12	'
Reductions:	'	'
Payments	-22	'
Adjustment to estimate of reclamation costs	-2	'
Ending balance, Liability	512	'
Less amounts due currently	-66	'
Noncurrent liability at March 31, 2014	446	440
Nuclear Plant Decommissioning [Member]	'	'
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'	'
Beginning balance, Liability	390	'
Additions:	'	'
Accretion	6	'
Reductions:	'	'
Payments	0	'
Adjustment to estimate of reclamation costs	0	'
Ending balance, Liability	396	'
Less amounts due currently	0	'
Noncurrent liability at March 31, 2014	396	'
Mining Land Reclamation [Member]	'	'
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'	'
Beginning balance, Liability	98	'
Additions:	'	'
Accretion	6	'
Reductions:	'	'
Payments	-22	'
Adjustment to estimate of reclamation costs	-2	'
Ending balance, Liability	80	'
Less amounts due currently	-66	'
Noncurrent liability at March 31, 2014	14	'
Other Asset Retirement Obligations [Member]	'	'
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]	'	'
Beginning balance, Liability	36	'
Additions:	'	'
Accretion	0	'
Reductions:	'	'
Payments	0	'
Adjustment to estimate of reclamation costs	0	'
Ending balance, Liability	36	'
Less amounts due currently	'	'
Noncurrent liability at March 31, 2014	$36	'

Recovered_Sheet1

Supplementary Financial Information (Other Noncurrent Liabilities and Deferred Credits) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014		Mar. 31, 2013	Dec. 31, 2013
Other Noncurrent Liabilities Noncurrent and Deferred Credits [Line Items]	'		'	'
Uncertain tax positions, including accrued interest	$246		'	$246
Retirement plan and other employee benefits	1,034	[1]	'	1,057	[1]
Asset retirement and mining reclamation obligations	446		'	440
Unfavorable purchase and sales contracts	583		'	589
Nuclear decomissioning cost over-recovery	413		'	400
Other	28		'	30
Total other noncurrent liabilities and deferred credits	2,750		'	2,762
Amortization of Deferred Charges	'		'	'
Amortization of Unfavorable Purchase and Sales Contracts	6		6	'
Estimated Future Amortization Expense	'		'	'
2014	24		'	'
2015	23		'	'
2016	23		'	'
2017	23		'	'
2018	23		'	'
Oncor [Member]	'		'	'
Other Noncurrent Liabilities Noncurrent and Deferred Credits [Line Items]	'		'	'
Retirement plan and other employee benefits	$845		'	$838
[1]	Includes $845 million and $838 million at March 31, 2014 and December 31, 2013, respectively, representing pension and OPEB liabilities related to Oncor (see Note 10).

Recovered_Sheet2

Supplementary Financial Information (Supplemental Cash Flow Information) (Details) (USD $)	1 Months Ended	3 Months Ended				1 Months Ended	12 Months Ended	1 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Jan. 31, 2013	Mar. 31, 2014		Mar. 31, 2013		Jan. 31, 2013	Dec. 31, 2013	Jan. 31, 2013	Dec. 31, 2013
						Senior Notes [Member]	Senior Notes [Member]	Senior Secured Debt [Member]	Senior Secured Debt [Member]
						EFH Corp. [Member]	11.25%/12.25% Senior Toggle notes due 2018 [Member]	EFH Corp. [Member]	10% Senior Secured notes due 2020 [Member]
							Energy Future Intermediate Holding CO LLC [Member]		Energy Future Intermediate Holding CO LLC [Member]
Condensed Cash Flow Statements, Captions [Line Items]	'	'		'		'	'	'	'
Debt Issuance Fee Paid By Issuance Of Debt	$340	'		'		'	'	'	'
Long Term Debt And Capital Leases Issued, Principal Amount	'	'		'		'	89	'	1,302
Principal Amount Of Affiliate Debt Acquired In Exchange Transaction	'	'		'		95	'	1,310	'
Cash payments related to:	'	'		'		'	'	'	'
Interest paid	'	622	[1]	731	[1]	'	'	'	'
Capitalized interest	'	-7		-7		'	'	'	'
Interest paid (net of capitalized interest)	'	615		724		'	'	'	'
Income taxes	'	0		0		'	'	'	'
Noncash investing and financing activities:	'	'		'		'	'	'	'
Construction expenditures	'	30	[2]	57	[2]	'	'	'	'
Debt exchange and extension transactions (c)	'	$0	[3]	($326)	[3]	'	'	'	'
[1]	Net of amounts received under interest rate swap agreements.
[2]	Represents end-of-period accruals.
[3]	For the three months ended March 31, 2013 includes: $340 million of term loans issued under the TCEH Term Loan Facilities, $1.302 billion of EFIH debt issued in exchange for $1.310 billion of EFH Corp. and EFIH debt and $89 million of EFIH debt issued in exchange for $95 million of EFH Corp. debt. Also see Note 5.