Energy Future Competitive 10-Q 9 May 16 2016 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2016	May. 09, 2016
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q1
Entity Registrant Name	Energy Future Competitive Holdings Co LLC
Entity Central Index Key	1,445,049
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding A		0
Entity Outstanding Membership Interests	At May 9, 2016 the outstanding membership interest in Energy Future Competitive Holdings Company LLC was directly held by Energy Future Holdings Corp.

Condensed Statements Of Consoli

Condensed Statements Of Consolidated Income (Loss) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Income Statement [Abstract]
Operating revenues	$ 1,049	$ 1,272
Fuel, purchased power costs and delivery fees	(554)	(613)
Net gain from commodity hedging and trading activities	64	103
Operating costs	(219)	(193)
Depreciation and amortization	(139)	(215)
Selling, general and administrative expenses	(160)	(161)
Impairment of goodwill (Note 4)	0	(700)
Impairment of long-lived assets (Note 6)	0	(676)
Other income (Note 16)	1	3
Other deductions (Note 16)	(21)	(60)
Interest expense and related charges (Note 7)	(336)	(317)
Reorganization items (Note 8)	(22)	(73)
Loss before income taxes	(337)	(1,630)
Income tax (expense) benefit (Note 5)	(4)	293
Net loss	(341)	(1,337)
Other comprehensive income, net of tax effects – cash flow hedges derivative value net loss related to hedged transactions recognized during the period (net of tax benefit of $— in all periods)	0	1
Comprehensive loss	$ (341)	$ (1,336)

Condensed Statement of Consolid

Condensed Statement of Consolidated Income (Loss) Parenthetical - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Income Statement [Abstract]
Other comprehensive income, net of tax effects – cash flow hedges derivative value net loss related to hedged transactions recognized during the period (net of tax benefit of $— in all periods)	$ 0	$ 0

Condensed Statements Of Consol4

Condensed Statements Of Consolidated Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Cash flows - operating activities:
Net loss	$ (341)	$ (1,337)
Adjustments to reconcile net loss to cash used in operating activities:
Depreciation and amortization	167	251
Deferred income tax benefit, net	0	(303)
Impairment of goodwill (Note 4)	0	700
Impairment of long-lived assets (Note 6)	0	676
Contract claims adjustments (Note 8)	1	32
Unrealized net (gain) loss from mark-to-market valuations of commodity positions	41	(102)
Increase for bad debt expense	5	9
Write-off of Intangible Assets, Finite-lived	20	59
Other, net	15	18
Changes in operating assets and liabilities:
Margin deposits, net	17	79
Other operating assets and liabilities, including liabilities subject to compromise	(111)	(180)
Cash used in operating activities	(191)	(107)
Cash flows — financing activities:
Repayments/repurchases of debt (Note 9)	(5)	(9)
Cash used in financing activities	(5)	(9)
Cash flows — investing activities:
Capital expenditures	(83)	(115)
Nuclear fuel purchases	(10)	(5)
Settlements of notes/advances due from affiliates	0	0
Changes in restricted cash	(142)	28
Proceeds from sales of nuclear decommissioning trust fund securities (Note 16)	67	23
Investments in nuclear decommissioning trust fund securities (Note 16)	(71)	(27)
Other, net	3	(14)
Cash used in investing activities	(236)	(110)
Net change in cash and cash equivalents	(432)	(226)
Cash and cash equivalents – beginning balance	1,400	1,843
Cash and cash equivalents – ending balance	$ 968	$ 1,617

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 968	$ 1,400
Restricted cash (Note 16)	661	519
Trade accounts receivable — net (Note 16)	447	533
Advance to parent (Note 15)	6	6
Inventories (Note 16)	448	428
Commodity and other derivative contractual assets (Note 14)	499	465
Other current assets	93	71
Total current assets	3,122	3,422
Restricted cash (Note 16)	507	507
Advance to parent (Note 15)	16	18
Investments (Note 16)	984	962
Property, plant and equipment — net (Note 16)	9,273	9,349
Goodwill (Note 4)	152	152
Identifiable intangible assets — net (Note 4)	1,170	1,179
Other noncurrent assets	50	39
Total assets	15,274	15,628
Current liabilities:
Borrowings under debtor-in-possession credit facility (Note 9)	1,425	1,425
Long-term debt due currently (Note 9)	29	31
Trade accounts payable	351	394
Trade accounts and other payables to affiliates	103	119
Commodity and other derivative contractual liabilities (Note 14)	261	203
Margin deposits related to commodity contracts	176	152
Accrued income taxes payable to parent (Note 15)	14	10
Accrued taxes other than income	66	98
Accrued interest	123	120
Other current liabilities	228	274
Total current liabilities	2,776	2,826
Long-term debt, less amounts due currently (Note 9)	21	23
Liabilities subject to compromise (Note 10)	33,776	33,776
Accumulated deferred income taxes	213	213
Other noncurrent liabilities and deferred credits (Note 16)	1,819	1,780
Total liabilities	$ 38,605	$ 38,618
Commitments and Contingencies (Note 11)
Membership interests (Note 12):	$ (23,331)	$ (22,990)
Total liabilities and membership interests	$ 15,274	$ 15,628

Business And Significant Accoun

Business And Significant Accounting Policies	3 Months Ended
	Mar. 31, 2016
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 EFCH and/or its subsidiaries, as apparent in the context. See Glossary for defined terms. EFCH, a Delaware limited liability company and a wholly owned subsidiary of EFH Corp., is a Dallas, Texas-based holding company. We conduct our operations almost entirely through our wholly owned subsidiary, TCEH. 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 retail electricity operations. Key management activities, including commodity risk management and electricity sourcing for our retail and wholesale customers, are performed on an integrated basis; consequently, there are no reportable business segments. Bankruptcy Proceeding 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 (collectively, 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 2 for further discussion regarding the Chapter 11 Cases, the Plan of Reorganization and the Disclosure Statement. Basis of Presentation, Including Application of Bankruptcy Accounting The condensed consolidated financial statements have been prepared in accordance with US GAAP. The condensed consolidated financial statements have been prepared as if EFCH is a going concern and contemplate the realization of assets and liabilities in the normal course of business. The condensed consolidated financial statements reflect the application of Financial Accounting Standards Board Accounting Standards Codification 852, Reorganizations (ASC 852) . During the pendency of the Chapter 11 Cases, 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. ASC 852 applies to entities that have filed a petition for bankruptcy under Chapter 11 of the Bankruptcy Code. The guidance requires that transactions and events directly associated with the reorganization be distinguished from the ongoing operations of the business. In addition, the guidance provides for changes in the accounting and presentation of liabilities. See Notes 8 and 10 for discussion of these accounting and reporting changes. 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 2015 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 and estimates of expected allowed claims. 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. Changes in Accounting Standards In February 2016, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update 2016-2 (ASU 2016-02), Leases . The ASU amends previous GAAP to require the recognition of lease assets and liabilities for operating leases. The ASU will be effective for fiscal years beginning after December 15, 2018, including interim periods within those years. Retrospective application to comparative periods will be required in the year of adoption. We are currently evaluating the impact of this ASU on our financial statements. In March 2016, the FASB issued Accounting Standards Update 2016-08 (ASU 2016-08), Revenue from Contracts with Customers (Topic 606): Principal versus Agent Considerations (Reporting Revenue Gross versus Net) . ASU 2016-08 clarifies the implementation guidance for principal versus agent considerations related to ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , which provides the core principle and key steps in determining the recognition of revenue. The effective date for these updates has been deferred to fiscal years beginning after December 15, 2017. We are currently assessing the impact of these ASUs on our financial statements.

Chapter 11 Cases

Chapter 11 Cases	3 Months Ended
	Mar. 31, 2016
Reorganizations [Abstract]
Chapter 11 Cases	CHAPTER 11 CASES On 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, 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 Chapter 11 Cases, 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. Plan of Reorganization The Terminated Plan was confirmed by the Bankruptcy Court in December 2015. As described below, in May 2016, certain first lien creditors of TCEH delivered a Plan Support Termination Notice (as defined in the Plan Support Agreement) to the Debtors and the other parties to the Plan Support Agreement notifying such parties of the occurrence of a Plan Support Termination Event (as defined in the Plan Support Agreement). The delivery of the Plan Support Termination Notice caused the Terminated Plan to become null and void. Following the occurrence of the Plan Support Termination Event as described above and termination of the Merger and Purchase Agreement as described below, the Debtors filed the Plan of Reorganization and the Disclosure Statement with the Bankruptcy Court in May 2016. The Plan of Reorganization provides that the confirmation and effective date of the Plan of Reorganization with respect to the TCEH Debtors may occur separate from, and independent of, the confirmation and effective date of the Plan of Reorganization with respect to the Debtors other than the TCEH Debtors (the EFH Debtors). The Plan of Reorganization, subject to certain conditions and required regulatory approvals, provides for, among other things: • with respect to the TCEH Debtors, either (i) a tax-free spin-off from EFH Corp. (the Reorganized TCEH Spin-Off), including a transaction that will result in a partial step-up in the tax basis of certain TCEH assets, or (ii) a taxable transaction that results in the assets of the TCEH Debtors being distributed to Reorganized TCEH, and • with respect to the EFH Debtors, the reorganization of EFH Corp. and EFIH (Reorganized EFH) either pursuant to (a) an equity investment (which may be from existing creditors or third-party investors) or (b) pursuant to a standalone plan of reorganization, in which creditors receive certain allocated pro rata shares of common stock of Reorganized EFH. Information contained in the Plan of Reorganization and the Disclosure Statement is subject to change, whether as a result of amendments to the Plan of Reorganization, requirements by the Bankruptcy Court, actions of third parties, or otherwise. The Bankruptcy Code does not permit solicitation of acceptances of a plan of reorganization until the Bankruptcy Court approves the applicable disclosure statement relating to such plan of reorganization. Accordingly, this quarterly report on Form 10-Q is not intended to be a solicitation for a vote on the Plan of Reorganization. There can be no assurance that the Bankruptcy Court will approve the Disclosure Statement, that the Debtors' stakeholders will vote to accept the Plan of Reorganization, or that the Bankruptcy Court will confirm the Plan of Reorganization. The Debtors will emerge from bankruptcy if and when a plan of reorganization receives the requisite approval from holders of claims, the Bankruptcy Court enters an order confirming such plan of reorganization, and certain conditions to the effectiveness of such plan of reorganization are satisfied. Plan Support Agreement In August 2015 (as amended in September 2015 and November 2015), each of the Debtors entered into a Plan Support Agreement (Plan Support Agreement) with various of their respective creditors, the Sponsor Group, the official committee of TCEH unsecured creditors and the Investor Group in order to effect an agreed upon restructuring of the Debtors pursuant to the Terminated Plan along with, upon certain events, an Alternative Restructuring (as defined in the Plan Support Agreement), which includes the Plan of Reorganization. The Bankruptcy Court approved the Debtors' entry into the Plan Support Agreement in September 2015. In May 2016, certain first lien creditors of TCEH (the Required TCEH First Lien Creditors) delivered a Plan Support Termination Notice to the Debtors and the other parties to the Plan Support Agreement notifying such parties of the occurrence of a Plan Support Termination Event pursuant to Section 11(g) of the Plan Support Agreement. The Plan Support Termination Notice stated that the Plan Support Outside Date can only be extended beyond April 30, 2016 if: (i) all required approvals from the PUCT with respect to the consummation of the Terminated Plan had been obtained before such date, or (ii) the Required Investor Parties (as defined in the Plan Support Agreement) submit a written request, which is received by the Required TCEH First Lien Creditors no later than April 30, 2016, to extend the Plan Support Outside Date for thirty days. The Plan Support Termination Notice stated that neither of the foregoing extensions had been triggered as of the date of the Plan Support Termination Notice. The delivery of the Plan Support Termination Notice caused the Terminated Plan to become null and void. The delivery of the Plan Support Termination Notice does not terminate the obligations of certain of the parties thereto to not object to or interfere with an Alternative Restructuring (including the Plan of Reorganization), subject to certain conditions. The parties' obligations with respect to such Alternative Restructuring, which remain in effect, may be terminated upon the occurrence of certain events described in the Plan Support Agreement. In addition, under the Plan Support Agreement, the supporting parties have committed to support the inclusion of releases with respect to the claims described in the Settlement Agreement (described below) in the context of an alternative plan (which would become effective when a plan of reorganization contemplating an Alternative Restructuring, such as the Plan of Reorganization, becomes effective). Settlement Agreement The Settling Parties entered into a settlement agreement (the Settlement Agreement) in August 2015 (as amended in September 2015) to compromise and settle, among other things (a) intercompany claims among the Debtors, (b) claims and causes of actions against holders of first lien claims against TCEH and the agents under the TCEH Senior Secured Facilities, (c) claims and causes of action against holders of interests in EFH Corp. and certain related entities and (d) claims and causes of action against each of the Debtors' current and former directors, the Sponsor Group, managers and officers and other related entities. The Settlement Agreement remains effective, notwithstanding the termination of the Terminated Plan. The Bankruptcy Court approved the Settlement Agreement in December 2015. Termination of Merger and Purchase Agreement In August 2015, EFH Corp. and EFIH entered into a Purchase Agreement and Agreement and Plan of Merger (Merger and Purchase Agreement) with two acquisition entities, Ovation Acquisition I, L.L.C. (OV1) and Ovation Acquisition II, L.L.C. (together with OV1, the Purchasers), which are controlled by a consortium (collectively, the Investor Group) consisting of certain TCEH creditors, an affiliate of Hunt Consolidated, Inc. and certain other investors designated by Hunt Consolidated, Inc., pursuant to which the Purchasers agreed to acquire Reorganized EFH. In May 2016, following receipt of the Plan Support Termination Notice described above, EFH Corp. and EFIH delivered a written notice to the Purchasers terminating the Merger and Purchase Agreement due to the occurrence of a Plan Support Termination Event under the Plan Support Agreement. EFH Corp. and EFIH are entitled to reimbursement by the Purchasers of certain fees and expenses incurred by EFH Corp. and EFIH or paid by EFH Corp. or EFIH to, or on behalf of, the Purchasers prior to, and as a result of, the termination of the Merger Agreement. As a result of the termination of the Merger and Purchase Agreement, each of the (i) equity commitment letter delivered by each member of the Investor Group in favor of EFH Corp., EFIH and the Purchasers in connection with the execution of the Merger and Purchase Agreement and (ii) Backstop Agreement (Backstop Agreement) between EFH Corp. and EFIH and certain investors named therein and their permitted assignees (Backstop Purchasers) and OV1, pursuant to which the Backstop Purchasers agreed to backstop approximately $5.087 billion of equity rights offered to certain holders of claims against the Debtors, automatically terminated. Texas Transmission Acquisition EFH Corp. instituted an adversary proceeding in the Bankruptcy Court to enforce certain rights against Texas Transmission under the Investor Rights Agreement, dated November 2008 among Oncor and certain of its direct and indirect equity holders, including EFH Corp. and Texas Transmission (Investor Rights Agreement), including with respect to Texas Transmission's obligations to participate in a sale of EFH Corp.'s interests in Oncor. In April 2016, the Bankruptcy Court ruled in favor of EFH Corp. in this proceeding. Regulatory Approvals In May 2016, the TCEH Debtors received approval from the NRC with respect to its change of control application contemplated by the Plan of Reorganization. Scheduling Matters The Debtors filed a proposed scheduling order with respect to the Disclosure Statement and the Plan of Reorganization in May 2016. The Bankruptcy Court is scheduled to hold a hearing later in May 2016 to consider the Debtors' scheduling request with respect to the timing of the hearing to consider approval of the Disclosure Statement, confirmation of the Plan of Reorganization and related discovery protocols. The timelines set forth in the proposed scheduling order are subject to revision by the Bankruptcy Court, and may change based on subsequent orders entered by the Bankruptcy Court (on its own, upon the motion of a party, or upon the Debtors' request). Tax Matters In June 2014, EFH Corp. filed a request with the IRS for a private letter ruling, which request has been supplemented from time to time in response to requests from the IRS for information or as required by changes in the contemplated transactions (as supplemented, the Private Letter Ruling). It is expected that, among other things, the Private Letter Ruling, if obtained, will provide for certain rulings regarding the qualification of (i) the transfer of certain assets and ordinary course operating liabilities to a newly-formed entity wholly-owned by TCEH (Reorganized TCEH) and (ii) the distribution of the equity of Reorganized TCEH, the cash proceeds from Reorganized TCEH debt, the cash proceeds from the sale of preferred stock in a newly-formed entity, and the right to receive payments under a tax receivables agreement (if any), to holders of TCEH first lien claims as a reorganization qualifying for tax-free treatment to the extent of the Reorganized TCEH stock received. The Debtors intend to continue to pursue the Private Letter Ruling to support the Plan of Reorganization. Implications of the Chapter 11 Cases Our ability to continue as a going concern is contingent upon, among other factors, our ability to comply with the financial and other covenants contained in the DIP Facility described in Note 9, our ability to obtain new debtor in possession financing in the event the DIP Facility were to expire during the pendency of the Chapter 11 Cases, our ability to complete a Chapter 11 plan of reorganization in a timely manner, including obtaining creditor and Bankruptcy Court approval of such plan, obtaining applicable regulatory approvals required for such plan and our ability to obtain any exit financing needed to implement such plan. These circumstances and uncertainties inherent in the bankruptcy proceedings raise substantial doubt about our ability to continue as a going concern. Pre-Petition Claims Holders of the substantial majority of pre-petition claims were required to file proofs of claims by the bar date established by the Bankruptcy Court. A bar date is the date by which certain claims against the Debtors must be filed if the claimants wish to receive any distribution in the Chapter 11 Cases. The Bankruptcy Court established a bar date of October 27, 2014 for the substantial majority of claims. In addition, in July 2015, the Bankruptcy Court entered an order establishing December 14, 2015 as the bar date for certain asbestos claims that arose or are deemed to have arisen before the Petition Date, except for certain specifically exempt claims. Since the Petition Date and prior to the applicable bar dates (which have expired), the Debtors have received approximately 41,300 filed pre-petition claims, including approximately 30,900 in filed asbestos claims. The Debtors have substantially completed the process of reconciling all non-asbestos claims that were filed and have recorded such claims at the expected allowed amount. As of May 9, 2016, approximately 5,700 of those claims have been settled, withdrawn or expunged. We continue to work with creditors regarding certain non-asbestos claims to determine the ultimate amount of the allowed claims. Differences between those final allowed claims and the liabilities recorded in the condensed consolidated balance sheets will be recognized as reorganization items in our condensed statements of consolidated loss as they are resolved. The resolution of such claims could result in material adjustments to our financial statements. Certain claims filed or reflected in the Debtors schedules of assets and liabilities will be resolved on the effective date of the Plan of Reorganization, including certain claims filed by holders of funded debt and contract counterparties. Claims that remain unresolved or unreconciled through the filing of this report have been estimated based upon management's best estimate of the likely claim amounts that the Bankruptcy Court will ultimately allow. PUCT Approval of Acquisition of Reorganized EFH In March 2016, the PUCT approved the acquisition of Reorganized EFH contemplated by the Merger and Purchase Agreement. The order approving the acquisition is subject to a number of material conditions and commitments. The PUCT issued the final order related to the acquisition in March 2016. In April 2016, prior to the termination of the Merger and Purchase Agreement, the Investor Group requested a rehearing by the PUCT with respect to certain conditions and commitments set forth in the PUCT's final order. The PUCT will consider the Investor Group's request for a rehearing later in May 2016. We cannot predict the outcome of this request.

Purchase of La Frontera Holding

Purchase of La Frontera Holdings, LLC (Notes)	3 Months Ended
	Mar. 31, 2016
Purchase of La Frontera Holdings, LLC [Abstract]
Business Combination Disclosure [Text Block]	PURCHASE OF LA FRONTERA HOLDINGS, LLC In April 2016, Luminant purchased all of the membership interests in La Frontera Holdings, LLC, the indirect owner of two natural gas fueled generation facilities representing nearly 3,000 MW of capacity located in ERCOT, from La Frontera Ventures, LLC, a subsidiary of NextEra Energy, Inc. The facility in Forney, Texas has a capacity of 1,912 MW and the facility in Paris, Texas has a capacity of 1,076 MW. The aggregate purchase price under the agreement was approximately $1.313 billion , which included the repayment of approximately $950 million of existing project financing indebtedness of La Frontera Holdings, LLC and its subsidiaries at the closing of the transaction, plus approximately $240 million for cash and net working capital subject to final settlement. The purchase price was funded by cash-on-hand and additional borrowings under the DIP Facility totaling $1.1 billion . The acquired entities are subsidiary guarantors under the DIP agreement. We are currently in the process of completing our purchase price allocation for the assets acquired and the liabilities assumed in the acquisition. We will provide the pro forma financial results in our quarterly report on Form 10-Q for the period ending June 30, 2016.

Goodwill And Identifiable Intan

Goodwill And Identifiable Intangible Assets	3 Months Ended
	Mar. 31, 2016
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 arose in connection with accounting for the Merger. None of the goodwill is being deducted for tax purposes. Goodwill before impairment charges $ 18,322 Accumulated noncash impairment charges (18,170 ) Balance at March 31, 2016 and December 31, 2015 $ 152 Goodwill Impairments Goodwill and intangible assets with indefinite useful lives are required to be tested for impairment at least annually (we have selected a December 1 test date) or whenever events or changes in circumstances indicate an impairment may exist. During the three months ended March 31, 2015, we experienced an impairment indicator related to decreases in forward wholesale electricity prices when compared to those prices reflected in our December 1, 2014 goodwill impairment testing analysis. As a result, the likelihood of a goodwill impairment had increased, and we initiated further testing of goodwill. Our testing of goodwill for impairment as of March 31, 2015 resulted in an impairment charge totaling $700 million . Identifiable Intangible Assets Identifiable intangible assets, including amounts that arose in connection with accounting for the Merger, are comprised of the following: March 31, 2016 December 31, 2015 Identifiable Intangible Asset Gross Carrying Amount Accumulated Amortization Net Gross Carrying Amount Accumulated Amortization Net Retail customer relationship $ 463 $ 445 $ 18 $ 463 $ 442 $ 21 Software and other technology-related assets 397 239 158 385 224 161 Other identifiable intangible assets (a) 58 24 34 72 35 37 Total identifiable intangible assets subject to amortization $ 918 $ 708 210 $ 920 $ 701 219 Retail trade name (not subject to amortization) 955 955 Mineral interests (not currently subject to amortization) 5 5 Total identifiable intangible assets $ 1,170 $ 1,179 ____________ (a) Includes favorable purchase and sales contracts, environmental allowances and credits and mining development costs. See discussion below regarding impairment charges recorded in the three months ended March 31, 2015 related to other identifiable intangible assets. At March 31, 2016 and December 31, 2015, amounts related to fully amortized assets that are expired or of no economic value, have been excluded from both the gross carrying and accumulated amortization amounts in the table above. Amortization expense related to finite-lived identifiable intangible assets (including the condensed statements of consolidated loss line item) consisted of: Identifiable Intangible Asset Condensed Statements of Consolidated Loss Line Three Months Ended March 31, 2016 2015 Retail customer relationship Depreciation and amortization $ 3 $ 4 Software and other technology-related assets Depreciation and amortization 15 14 Other identifiable intangible assets Operating revenues/fuel, purchased power costs and delivery fees/depreciation and amortization 3 5 Total amortization expense (a) $ 21 $ 23 _______________ (a) Amounts recorded in depreciation and amortization totaled $20 million and $18 million for the three months ended March 31, 2016 and 2015, respectively. I ntangible Impairments The impairments of our generation facilities in March 2015 (see Note 6) resulted in the impairment of the SO 2 allowances under the Clean Air Act's acid rain cap-and-trade program that are associated with those facilities to the extent they are not projected to be used at other sites. The fair market values of the SO 2 allowances were estimated to be de minimis based on Level 3 fair value estimates (see Note 13). Accordingly, in the three months ended March 31, 2015, we recorded noncash impairment charges of $51 million (before deferred income tax benefit) in other deductions (see Note 16) related to our existing environmental allowances and credits intangible asset. During the three months ended March 31, 2015, we determined that certain intangible assets related to favorable power purchase contracts should be evaluated for impairment. That conclusion was based on further declines in wholesale electricity prices in ERCOT experienced during the three months ended March 31, 2015. Our fair value measurement was based on a discounted cash flow analysis of the contracts that compared the contractual price and terms of the contract to forecasted wholesale electricity and renewable energy credit (REC) prices in ERCOT. As a result of the analysis, we recorded a noncash impairment charge of $8 million (before deferred income tax benefit) in other deductions (see Note 16). 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 2016 $ 84 2017 $ 61 2018 $ 38 2019 $ 18 2020 $ 10

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2016
Income Tax Disclosure [Abstract]
Income Taxes	INCOME TAXES EFH Corp. files a US federal income tax return that includes the results of EFCH, EFIH, Oncor Holdings and TCEH. EFH Corp. is the corporate member of the EFH Corp. consolidated group, while each of EFIH, Oncor Holdings, EFCH and TCEH is classified as a disregarded entity for US federal income tax purposes. Pursuant to applicable US Treasury regulations and published guidance of the IRS, corporations that are members of a consolidated group have joint and several liability for the taxes of such group. EFH Corp. and certain of its subsidiaries (including EFCH, EFIH, and TCEH, but not including Oncor Holdings and Oncor) are parties to a Federal and State Income Tax Allocation Agreement, which provides, among other things, that any corporate member or disregarded entity in the EFH Corp. group is required to make payments to EFH Corp. in an amount calculated to approximate the amount of tax liability such entity would have owed if it filed a separate corporate tax return. The Plan of Reorganization provides that upon the effective date of the plan the Debtors will reject this agreement. Additionally, under the terms of the Settlement Agreement, no further cash payments among the Debtors will be made in respect of federal income taxes. EFH Corp. has elected to continue to allocate federal income taxes among the entities that are parties to the Federal and State Income Tax Allocation Agreement. The Settlement Agreement did not alter the allocation and payment for state income taxes, which will continue to be settled. The calculation of our effective tax rate is as follows: Three Months Ended March 31, 2016 2015 Loss before income taxes $ (337 ) $ (1,630 ) Income tax (expense) benefit $ (4 ) $ 293 Effective tax rate (1.2 )% 18.0 % For the three months ended March 31, 2016, the effective tax rate of (1.2)% related to our income tax expense was lower than the US Federal statutory rate of 35% due primarily to a forecasted valuation allowance against deferred tax assets and Texas margin tax expense on pretax losses in 2016. For the three months ended March 31, 2015, the effective tax rate of 18.0% related to our income tax benefit was lower than the US Federal statutory rate of 35% due primarily to the nondeductible goodwill impairment charge (see Note 4) and nondeductible legal and other professional services costs related to the Chapter 11 Cases, offset by the difference in the forecasted effective tax rate and the statutory rate applied to long-lived and intangible asset impairment charges (see Notes 4 and 6).

Impairment of Long-Lived Assets

Impairment of Long-Lived Assets	3 Months Ended
	Mar. 31, 2016
Impairment of Long-Lived Assets [Abstract]
Impairment of Long-Lived Assets	IMPAIRMENT OF LONG-LIVED ASSETS Impairment of Lignite/Coal Fueled Generation and Mining Assets We evaluated our generation assets for impairment during March 2015 as a result of an impairment indicator related to the continued decline in forecasted wholesale electricity prices in ERCOT. Our evaluation concluded that an impairment existed, and the carrying value at our Big Brown generation facility and related mining facility was reduced by $676 million . Our fair value measurement for these assets was determined based on an income approach that utilized probability-weighted estimates of discounted future cash flows, which were Level 3 fair value measurements (see Note 13). Key inputs into the fair value measurement for these assets included current forecasted wholesale electricity prices in ERCOT, forecasted fuel prices, capital and operating expenditure forecasts and discount rates. Additional material impairments may occur in the future for our other generation facilities if forward wholesale electricity prices continue to decline or forecasted costs of producing electricity at our generation facilities increase

Interest Expense and Related Ch

Interest Expense and Related Charges	3 Months Ended
	Mar. 31, 2016
Interest Expense and Related Charges [Abstract]
Interest Expense and Related Charges	INTEREST EXPENSE AND RELATED CHARGES Three Months Ended March 31, 2016 2015 Interest paid/accrued on debtor-in-possession financing $ 16 $ 15 Adequate protection amounts paid/accrued 322 302 Interest paid/accrued on pre-petition debt 1 3 Capitalized interest (3 ) (3 ) Total interest expense and related charges $ 336 $ 317 Interest expense for the three months ended March 31, 2016 and 2015 reflects interest paid and accrued on debtor-in-possession financing (see Note 9), adequate protection amounts paid and accrued, as approved by the Bankruptcy Court in June 2014 for the benefit of secured creditors of (a) $22.616 billion principal amount of outstanding borrowings from the TCEH Senior Secured Facilities, (b) $1.750 billion principal amount of outstanding TCEH Senior Secured Notes and (c) the $1.243 billion net liability related to the TCEH first lien interest rate swaps and natural gas hedging positions terminated shortly after the Bankruptcy Filing (see Note 14), in exchange for their consent to the senior secured, super-priority liens contained in the DIP Facility and any diminution in value of their interests in the pre-petition collateral from the Petition Date. The interest rate applicable to the adequate protection amounts paid/accrued for the three months ended March 31, 2016 was 4.92% (one-month LIBOR plus 4.50% ). The amount of adequate protection payments may be adjusted to reflect the valuation of the TCEH Debtors determined in connection with confirmation of the Plan of Reorganization by the Bankruptcy Court. In addition, upon completion of the Plan of Reorganization, amounts of adequate protection payments may be re-characterized as payments of principal. The Bankruptcy Code generally restricts payment of interest on pre-petition debt, subject to certain exceptions. Additional interest payments may also be made upon approval by the Bankruptcy Court. Other than amounts ordered or approved by the Bankruptcy Court, effective on the Petition Date, we discontinued recording interest expense on outstanding pre-petition debt classified as LSTC. The table below shows contractual interest amounts, which are amounts due under the contractual terms of the outstanding debt, including debt subject to compromise during the Chapter 11 Cases. Interest expense reported in the condensed statements of consolidated loss for the three months ended March 31, 2016 and 2015 does not include $224 million and $227 million , respectively, in contractual interest on pre-petition debt classified as LSTC, which has been stayed by the Bankruptcy Court effective on the Petition Date. For the three months ended March 31, 2016 and 2015, adequate protection paid/accrued presented below excludes $15 million and $14 million , respectively, related to interest paid/accrued on the TCEH first-lien interest rate and commodity hedge claims (see Note 14), as such amounts are not included in contractual interest amounts below. Three Months Ended March 31, 2016 Three Months Ended March 31, 2015 Entity: Contractual Interest on Adequate Protection Contractual Interest on Contractual Interest on Adequate Protection Contractual Interest on EFCH $ — $ — $ — $ 2 $ — $ 2 TCEH 531 307 224 513 288 $ 225 Total $ 531 $ 307 $ 224 $ 515 $ 288 $ 227

Reorganization Items

Reorganization Items	3 Months Ended
	Mar. 31, 2016
Reorganization Items [Abstract]
Reorganization Items	REORGANIZATION ITEMS Expenses and income directly associated with the Chapter 11 Cases are reported separately in the condensed statements of consolidated loss as reorganization items as required by ASC 852, Reorganizations . Reorganization items also include adjustments to reflect the carrying value of LSTC at their estimated allowed claim amounts, as such adjustments are determined. The following table presents reorganization items incurred in the three months ended March 31, 2016 and 2015 as reported in the condensed statements of consolidated loss: Three Months Ended March 31, 2016 2015 Expenses related to legal advisory and representation services $ 13 $ 26 Expenses related to other professional consulting and advisory services 8 15 Contract claims adjustments 1 32 Total reorganization items $ 22 $ 73

Debtor-In-Possession Borrowing

Debtor-In-Possession Borrowing Facility and Long-Term Debt Not Subject to Compromise	3 Months Ended
	Mar. 31, 2016
Debtor-In-Possession Borrowing Facilities [Abstract]
Debtor-In-Possession Borrowing Facility and Long-Term Debt Not Subject to Compromise	DEBTOR-IN-POSSESSION BORROWING FACILITY AND LONG-TERM DEBT NOT SUBJECT TO COMPROMISE DIP Facility — The Bankruptcy Court approved the DIP Facility in June 2014. The DIP Facility currently provides for up to $3.375 billion in senior secured, super-priority financing consisting of a revolving credit facility of up to $1.950 billion (DIP Revolving Credit Facility) and a term loan facility of up to $1.425 billion (DIP Term Loan Facility). The DIP Facility is a Senior Secured, Super-Priority Credit Agreement by and among the TCEH Debtors, the lenders that are party thereto from time to time and an administrative and collateral agent. The DIP Facility and related available capacity at March 31, 2016 are presented below. In the March 31, 2016 condensed consolidated balance sheet, the borrowings under the DIP Facility are reported as current liabilities. The maturity date of the DIP Facility is the earlier of (a) November 2016 or (b) the effective date of any plan of reorganization of TCEH. TCEH's cash collateral order expires sixty days after the date of the Plan Support Termination Notice, provided that the TCEH Debtors do not otherwise cause an event of default under the cash collateral order. The TCEH Debtors are currently in discussions with TCEH first lien creditors regarding the terms of an extension of the cash collateral order. The DIP Facility must be repaid in full prior to the TCEH Debtors emergence from the Chapter 11 Cases. March 31, 2016 DIP Facility Facility Limit Available Cash Borrowing Capacity Available Letter of Credit Capacity DIP Revolving Credit Facility (a) $ 1,950 $ 1,950 $ — DIP Term Loan Facility (b) 1,425 — 139 Total DIP Facility $ 3,375 $ 1,950 $ 139 ___________ (a) Facility used for general corporate purposes. No amounts were borrowed at March 31, 2016. Pursuant to an order of the Bankruptcy Court, the TCEH Debtors may not have more than $1.650 billion of DIP Revolving Credit Facility cash borrowings outstanding without written consent of the TCEH committee of unsecured creditors and the ad hoc group of TCEH unsecured noteholders or further order of the Bankruptcy Court. (b) Facility used for general corporate purposes, including but not limited to, $800 million for issuing letters of credit. At both March 31, 2016 and December 31, 2015, all $1.425 billion of the DIP Term Loan Facility has been borrowed. Of this borrowing, $800 million represents amounts that support issuances of letters of credit and have been funded to a collateral account. Of the collateral account amount at March 31, 2016, $139 million is reported as cash and cash equivalents and $661 million is reported as restricted cash, which represents the amount of outstanding letters of credit. As discussed in Note 3, the acquisition of La Frontera Holdings, LLC in April 2016 was funded by cash-on-hand and $1.1 billion in additional cash borrowings under the DIP Revolving Credit Facility. After completing the acquisition, we repaid approximately $230 million of borrowings under the DIP Revolving Credit Facility utilizing cash acquired in the transaction. Amounts borrowed under the DIP Term Loan Facility bear interest based on applicable LIBOR rates, subject to a 0.75% floor, plus 3% . At both March 31, 2016 and December 31, 2015, the interest rate on outstanding borrowings was 3.75% . The 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 DIP Facility. The TCEH Debtors' obligations under the DIP Facility are secured by a lien covering substantially all of the TCEH Debtors' assets, rights and properties (including the assets acquired in the La Frontera acquisition), subject to certain exceptions set forth in the DIP Facility. The DIP Facility provides that all obligations thereunder constitute administrative expenses in the Chapter 11 Cases, with administrative priority and senior secured status under the Bankruptcy Code and, subject to certain exceptions set forth in the DIP Facility, have priority over any and all administrative expense claims, unsecured claims and costs and expenses in the Chapter 11 Cases. EFCH is a guarantor to the agreement governing the DIP Facility along with substantially all of TCEH’s subsidiaries, including all subsidiaries that are Debtors in the Chapter 11 Cases. The DIP Facility also permits certain hedging agreements to be secured on a pari-passu basis with the DIP Facility in the event those hedging agreements meet certain criteria set forth in the DIP Facility. In June 2014, the RCT agreed to accept a collateral bond from TCEH of up to $1.1 billion to secure mining land reclamation obligations. The collateral bond is a $1.1 billion carve-out from the super-priority liens under the DIP Facility that will enable the RCT to be paid before the DIP Facility lenders. The 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 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 DIP Facility. The TCEH Debtors' ability to borrow under the DIP Facility is subject to the satisfaction of certain customary conditions precedent set forth therein. The 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 DIP Facility or ancillary loan documents, cross-defaults under other agreements or instruments and the entry of material judgments against the TCEH Debtors. The agreement governing the DIP Facility includes a covenant that requires the Consolidated Superpriority Secured Net Debt to Consolidated EBITDA ratio not exceed 3.50 to 1.00. Consolidated Superpriority Secured Net Debt consists of outstanding term loans and revolving credit exposure under the DIP Facility less unrestricted cash. As of March 31, 2016, we are in compliance with this financial covenant. Upon the existence of an event of default, the 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. Long-Term Debt Not Subject to Compromise — Amounts presented in the table below represent pre-petition liabilities that are not subject to compromise due to the debt being fully collateralized or specific orders from the Bankruptcy Court approving repayment of the debt. March 31, December 31, EFCH 9.58% Fixed Notes due in annual installments through December 4, 2019 (a) $ 13 $ 13 8.254% Fixed Notes due in quarterly installments through December 31, 2021 (a) 23 24 Unamortized fair value discount (b) (2 ) (2 ) Total EFCH 34 35 TCEH 7.48% Fixed Secured Facility Bonds with amortizing payments through January 2017 (c) 10 13 Capital lease obligations 4 5 Other 2 2 Unamortized discount — (1 ) Total TCEH 16 19 Total EFCH consolidated 50 54 Less amounts due currently (29 ) (31 ) Total long-term debt not subject to compromise $ 21 $ 23 ____________ (a) Approved by the Bankruptcy Court for repayment. (b) Amount represents unamortized fair value adjustments recorded under purchase accounting. (c) Debt issued by trust and secured by assets held by the trust.

Liabilities Subject To Compromi

Liabilities Subject To Compromise	3 Months Ended
	Mar. 31, 2016
Debt and Capital Lease Obligations [Abstract]
Liabilities Subject To Compromise	LIABILITIES SUBJECT TO COMPROMISE (LSTC) The amounts classified as LSTC reflect the company's estimate of pre-petition liabilities and other expected allowed claims to be addressed in the Chapter 11 Cases and may be subject to future adjustment as the Chapter 11 Cases proceed. Amounts classified to LSTC do not include pre-petition liabilities that are fully collateralized by letters of credit or cash deposits. The following table presents LSTC as reported in the condensed consolidated balance sheets at March 31, 2016 and December 31, 2015: March 31, December 31, Notes, loans and other debt per the following table $ 31,707 $ 31,707 Accrued interest on notes, loans and other debt 648 648 Net liability under terminated TCEH interest rate swap and natural gas hedging agreements (Note 14) 1,243 1,243 Trade accounts payable and other expected allowed claims 177 177 Advances and other payables to affiliates 1 1 Total liabilities subject to compromise $ 33,776 $ 33,776 Pre-Petition Notes, Loans and Other Debt Reported as LSTC Amounts presented below represent principal amounts of pre-petition notes, loans and other debt reported as LSTC. March 31, December 31, 2015 TCEH Senior Secured Facilities: TCEH Floating Rate Term Loan Facilities due October 10, 2014 $ 3,809 $ 3,809 TCEH Floating Rate Letter of Credit Facility due October 10, 2014 42 42 TCEH Floating Rate Revolving Credit Facility due October 10, 2016 2,054 2,054 TCEH Floating Rate Term Loan Facilities due October 10, 2017 15,691 15,691 TCEH Floating Rate Letter of Credit Facility due October 10, 2017 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 1,833 1,833 10.25% Fixed Senior Notes due November 1, 2015, Series B 1,292 1,292 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 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 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 Other: Other 1 1 Total TCEH 31,668 31,668 EFCH (parent entity) Floating Rate Junior Subordinated Debentures, Series D due January 30, 2037 1 1 8.175% Fixed Junior Subordinated Debentures, Series E due January 30, 2037 8 8 Subtotal 9 9 March 31, 2016 December 31, 2015 EFH Corp. pre-petition debt pushed down (a) 10.875% Fixed Senior Notes due November 1, 2017 $ 16 $ 16 11.25%/12.00% Senior Toggle Notes due November 1, 2017 14 14 Subtotal — EFH Corp. debt pushed down 30 30 Total EFCH (parent entity) 39 39 Total EFCH consolidated notes, loans and other debt $ 31,707 $ 31,707 ____________ (a) Represents 50% of the amount of these EFH Corp. securities guaranteed by, and pushed down to (pushed-down debt), EFCH (parent entity) per the discussion below under "Guarantees and Push Down of EFH Corp. Pre-Petition Debt." Guarantees and Push Down of EFH Corp. Pre-Petition Debt Merger-related debt of EFH Corp. and its subsidiaries consists of debt issued or existing at the time of the Merger. Debt issued in exchange for Merger-related debt is considered Merger-related. Debt issuances for cash are considered Merger-related debt to the extent the proceeds are used to repurchase Merger-related debt. EFCH and EFIH (excluding their subsidiaries) fully and unconditionally guarantee on a joint and several basis the Merger-related debt of EFH Corp. (parent). Such debt is subject to push down in accordance with SEC Staff Accounting Bulletin Topic 5-J, and as a result, a portion of such debt and related interest expense is reflected in our financial statements. Merger-related debt of EFH Corp. held by its subsidiaries is not subject to push down. Debt guaranteed and subject to push down at March 31, 2016 totals $60 million and consists of $33 million principal amount of EFH Corp. 10.875% Senior Notes and $27 million principal amount of EFH Corp. 11.25%/12.00% Senior Toggle Notes. The amount reflected in our condensed consolidated balance sheets as pushed down pre-petition debt ( $30 million at both March 31, 2016 and December 31, 2015, as shown in the debt table above) represents 50% of the principal amount of the EFH Corp. Merger-related debt guaranteed. This percentage reflects the fact that at the time of the Merger, the equity investments of EFCH and EFIH in their respective operating subsidiaries were essentially equal amounts. Because payment of principal and interest on the debt is the responsibility of EFH Corp., we record the settlement of such amounts as noncash capital contributions from EFH Corp. There were no payments of interest by EFH Corp. on pre-petition debt pushed down for the three months ended March 31, 2016 or 2015. TCEH Letter of Credit Facility Activity Borrowings under the TCEH Letter of Credit Facility have been recorded by TCEH as restricted cash that supports issuances of letters of credit. At both March 31, 2016 and December 31, 2015, the restricted cash related to the pre-petition TCEH Letter of Credit Facility totaled $507 million and there were no outstanding letters of credit related to the pre-petition TCEH Letter of Credit Facility. Due to the default under the pre-petition TCEH Senior Secured Facilities, the letter of credit capacity is no longer available. Information Regarding Significant Pre-Petition Debt See Note 12 to the Financial Statements in our 2015 Form 10-K for information regarding our pre-petition debt. There have been no changes in pre-petition debt since December 31, 2015.

Commitments And Contingencies

Commitments And Contingencies	3 Months Ended
	Mar. 31, 2016
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. See Notes 9 and 10 for discussion of guarantees and security for certain of our post-petition and pre-petition debt. Letters of Credit At March 31, 2016, TCEH had outstanding letters of credit under the DIP Facility totaling $661 million as follows: • $377 million to support commodity risk management and trading margin requirements in the normal course of business, including over-the-counter and exchange-traded hedging transactions and collateral postings with ERCOT; • $66 million to support executory contracts and insurance agreements; • $55 million to support TCEH's REP financial requirements with the PUCT, and • $163 million for other credit support requirements, including $131 million to support our purchase and sale agreement with La Frontera Holdings, LLC. The automatic stay under the Bankruptcy Code does not apply to letters of credit issued under the pre-petition credit facility and third parties may draw if the terms of a particular letter of credit so provide. Litigation Aurelius Derivative Claim — 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. In January 2014, the district court granted EFCH's and the directors' motion to dismiss and in February 2014 dismissed the lawsuit. Aurelius has appealed the district court's judgment to the US Court of Appeals for the Fifth Circuit (Fifth Circuit Court). The appeal was automatically stayed as a result of the Bankruptcy Filing. We cannot predict the outcome of this proceeding, including the financial effects, if any. 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 Clean Air Act (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. 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 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, which the EPA said "superseded" its July 2012 notice. 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 August 2015, the district court issued its ruling on our motion to dismiss and granted the motion as to seven of the nine claims asserted by the EPA in the lawsuit. Two claims remain before the district court, and those are currently scheduled for trial in October 2017. We believe that we have complied with all requirements of the CAA and intend to vigorously defend against the remaining allegations. The lawsuit requests 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, 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. Greenhouse Gas Emissions In August 2015, the EPA finalized rules to address greenhouse gas (GHG) emissions from new, modified and reconstructed units, and existing electricity generation plants. The rule for existing facilities would establish state-specific emissions rate goals to reduce nationwide carbon dioxide emissions related to affected electricity generation units by over 30% from 2012 emission levels by 2030. A number of parties, including Luminant, filed petitions for review in the US Court of Appeals for the District of Columbia Circuit (D.C. Circuit Court) for the rule for new, modified and reconstructed plants. In addition, a number of petitions for review of the rule for existing plants were filed in the D.C. Circuit Court by various parties and groups, including challenges from twenty-seven different states opposed to the rule as well as those from, among others, certain power generating companies, various business groups and some labor unions. Luminant also filed its own petition for review. In addition, several parties have filed motions to stay the implementation of the rule while the court reviews the legality of the rule for existing units. In January 2016, the D.C. Circuit Court denied the motion to stay and ordered an expedited briefing on the merits. Oral argument is scheduled for June 2016. In January 2016, a coalition of states, industry (including Luminant) and other parties filed applications with the US Supreme Court asking that the court stay the rule. In February 2016, the US Supreme Court stayed the rule pending the conclusion of legal challenges on the rule before the D.C. Circuit Court and until the US Supreme Court disposes of any subsequent petition for review. While we cannot predict the outcome of this rulemaking and legal proceedings on our results of operations, liquidity or financial condition, the impacts could be material. In August 2015, the EPA proposed model rules and federal plan requirements for states to consider as they develop state plans to comply with the rules for GHG emissions. A federal plan would then be finalized for a state if a state fails to submit a state plan by the deadlines established in the CAA for existing plants or if the EPA disapproves a submitted state plan. We filed comments on the federal plan proposal in January 2016. The EPA is expected to finalize the model rule by the summer of 2016. While we cannot predict the outcome of this rulemaking and legal proceedings on our results of operations, liquidity or financial condition, the impacts could be material. 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 (SO 2 ) and nitrogen oxide (NO x ) emissions from our fossil fueled generation units. 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 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 SO 2 , 3% higher for annual NO x and 2% higher for seasonal NO x . The CSAPR became effective January 1, 2015. In July 2015, following a remand of the case from the US Supreme Court to consider further legal challenges, the D.C. Circuit Court unanimously ruled in favor of us and other petitioners, holding that the CSAPR emissions budgets over-controlled Texas and other states. The D.C. Circuit Court remanded those states' budgets to the EPA for prompt reconsideration. While we planned to participate in the EPA's reconsideration process to develop increased budgets that do not over-control Texas, the EPA instead responded to the remand by updating the NO X ozone season budget for the 2008 ozone standard with a new rulemaking without explicitly addressing the issues of over-control of the 1997 standard. Comments on the EPA's proposal were submitted by Luminant in February 2016. While we cannot predict the outcome of future proceedings related to the CSAPR, including the EPA's reconsideration of the CSAPR annual emissions budgets for affected states, based upon our current operating plans we do not believe that the CSAPR will cause any material operational, financial or compliance issues. Regional Haze The Regional Haze Program of the CAA establishes "as a national goal the prevention of any future, and the remedying of any existing, impairment of visibility in mandatory Class I federal areas, like national parks, which impairment results from man-made pollution." There are two components to the Regional Haze Program. First, states must establish goals for reasonable progress for Class I federal areas within the state and establish long-term strategies to reach those goals and to assist Class I federal areas in neighboring states to achieve reasonable progress set by those states towards a goal of natural visibility by 2064. Second, electricity generation units built between 1962 and 1977 are subject to best available retrofit technology (BART) standards designed to improve visibility. BART reductions of SO 2 and NO X are required either on a unit-by-unit basis or are deemed satisfied by state participation in an EPA-approved regional trading program such as the CSAPR. In February 2009, the TCEQ submitted a State Implementation Plan (SIP) concerning regional haze (Regional Haze SIP) to the EPA. In December 2011, the EPA proposed a limited disapproval of the Regional Haze SIP due to its reliance on the Clean Air Interstate Rule (CAIR) instead of the EPA's replacement CSAPR program. In August 2012, we filed a petition for review in the Fifth Circuit Court challenging the EPA's limited disapproval of the Regional Haze SIP on the grounds that the CAIR continued in effect pending the D.C. Circuit Court's decision in the CSAPR litigation. In September 2012, we filed a petition to intervene in a case filed by industry groups and other states and private parties in the D.C. Circuit Court challenging the EPA's limited disapproval and issuance of a Federal Implementation Plan (FIP) regarding the regional haze BART program. The Fifth Circuit Court case has since been transferred to the D.C. Circuit Court and consolidated with other pending BART program regional haze appeals. No schedule has been set in the consolidated cases now in the D.C. Circuit Court. In response to a lawsuit by environmental groups, the D.C. Circuit Court issued a consent decree in March 2012 that required the EPA to propose a decision on the Regional Haze SIP by May 2012 and finalize that decision by November 2012. The consent decree requires a FIP for any provisions that the EPA disapproves. The D.C. Circuit Court has amended the consent decree several times to extend the dates for the EPA to propose and finalize a decision on the Regional Haze SIP. The consent decree was modified in December 2015 to extend the deadline for the EPA to finalize action on the determination and adoption of requirements for BART for electricity generation. Under the amended consent decree the EPA has until December 2016 to finalize a FIP for BART for Texas electricity generation sources, if the EPA determines that BART requirements have not been met. In June 2014, the EPA issued requests for information under Section 114 of the CAA to Luminant and other generators in Texas. After releasing a proposed rule in November 2014 and receiving comments from a number of parties, including Luminant and the State of Texas in April 2015, the EPA released a final rule in January 2016 approving in part and disapproving in part Texas' SIP for Regional Haze and issuing a FIP for Regional Haze. In the rule, the EPA asserts that the Texas SIP does not show reasonable progress in improving visibility for two areas in Texas and that its long-term strategy fails to make emission reductions needed to achieve reasonable progress in improving visibility in the Wichita Mountains of Oklahoma. Unlike the proposed rule and inconsistent with how the EPA has applied Regional Haze rules to other states, the EPA's final rule does not treat Texas's compliance with the CSAPR as satisfying its obligations under the BART portion of the Regional Haze Program. The EPA concluded that it would not be appropriate to finalize that determination at this time given the remand of the CSAPR budgets. In our view, the EPA's proposed FIP for Texas goes beyond the requirements of the CSAPR and sets emission limits on a unit-by-unit basis for 15 electricity generation units in Texas. The EPA's proposed emission limits assume additional control equipment for specific coal fueled generation units across Texas, including new flue gas desulfurization systems (scrubbers) at seven generation units and upgrades to existing scrubbers at seven generation units. Specifically for Luminant, the EPA's emission limitations are based on new scrubbers at Big Brown Units 1 and 2 and Monticello Units 1 and 2 and scrubber upgrades at Martin Lake Units 1, 2 and 3, Monticello Unit 3 and Sandow Unit 4. Luminant is continuing to evaluate the requirements and potential financial and operational impacts of the rule, but new scrubbers at the Big Brown and Monticello units necessary to achieve the emission limits required by the FIP (if those limits are possible to attain), along with the existence of low wholesale power prices in ERCOT, would likely challenge the long-term economic viability of those units. The scrubber upgrades will be required by February 2019, and the new scrubbers will be required by February 2021. In March 2016, Luminant and a number of other parties, including the State of Texas, filed petitions for review in the US Fifth Circuit Court challenging the FIP on Texas. Luminant and other parties also filed motions to stay the FIP while the court reviews the legality of the EPA's action. While we cannot predict the outcome of the rulemaking and legal proceedings, the result may have a material impact on our results of operations, liquidity or financial condition. State Implementation Plan (SIP) In February 2013, in response to a petition for rulemaking filed by the Sierra Club, the EPA proposed a rule requiring certain states to replace SIP exemptions for excess emissions during malfunctions with an affirmative defense. Texas was not included in that original proposal since it already had an EPA-approved affirmative defense provision in its SIP. In 2014, as a result of a D.C. Circuit Court decision striking down an affirmative defense in another EPA rule, the EPA revised its 2013 proposal to extend the EPA's proposed findings of inadequacy to states that have affirmative defense provisions, including Texas. The EPA's revised proposal would require Texas to remove or replace its EPA-approved affirmative defense provisions for excess emissions during startup, shutdown and maintenance events. In May 2015, the EPA finalized the proposal. In June 2015, we filed a petition for review in the Fifth Circuit Court challenging certain aspects of the EPA's final rule as they apply to the Texas SIP. The State of Texas and other parties have also filed similar petitions in the Fifth Circuit Court. In August 2015, the Fifth Circuit Court transferred the petitions that Luminant and other parties filed to the D.C. Circuit Court, and in October 2015 the petitions were consolidated with the pending petitions challenging the EPA's action in the D.C. Circuit Court. Briefing in the D.C. Circuit Court on the challenges is scheduled to be completed by October 2016. We cannot predict the timing or outcome of this proceeding. In June 2014, the Sierra Club filed a petition in the D.C. Circuit Court seeking review of several EPA regulations containing affirmative defenses for malfunctions, including the Mercury and Air Toxics Standard (MATS) rule for power plants. In the petition, the Sierra Club contends this affirmative defense is no longer permissible in light of a D.C. Circuit Court decision regarding similar defenses applicable to the cement industry. Luminant filed a motion to intervene in this case. In July 2014, the D.C. Circuit Court ordered the case stayed pending the EPA's consideration of a petition for administrative reconsideration of the regulations at issue. In December 2014, the EPA signed a proposal to make technical corrections to the MATS rule. We filed comments on this proposal in April 2015. In March 2016, the EPA finalized the MATS technical corrections, including the removal of affirmative defense for malfunctions. Except as set forth above, we cannot predict the timing or outcome of future proceedings related to this petition, the petition for administrative reconsideration that is pending before the EPA or the financial effects of these proceedings, 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.

Membership Interests

Membership Interests	3 Months Ended
	Mar. 31, 2016
Stockholders' Equity Note [Abstract]
Membership Interests	MEMBERSHIP INTERESTS Under applicable law, we are prohibited from paying any distribution to the extent that immediately following payment of such distribution, we would be insolvent. In addition, due to the Chapter 11 Cases, no distributions are eligible to be paid without the approval of the Bankruptcy Court. The agreement governing the DIP Facility generally restricts TCEH's ability to make distributions or loans to any of its parent companies or their subsidiaries unless such distributions or loans are expressly permitted under the agreement governing such facility. Membership Interests The following tables present the changes to membership interests for the three months ended March 31, 2016 and 2015: Three Months Ended March 31, 2016 Capital Account Accumulated Other Comprehensive Loss Total Membership Interests Balance at December 31, 2015 $ (22,957 ) $ (33 ) $ (22,990 ) Net loss (341 ) — (341 ) Balance at March 31, 2016 $ (23,298 ) $ (33 ) $ (23,331 ) Three Months Ended March 31, 2015 Capital Account Accumulated Other Comprehensive Loss Total Membership Interests Balance at December 31, 2014 $ (18,439 ) $ (35 ) $ (18,474 ) Net loss (1,337 ) — (1,337 ) Net effect of cash flow hedges — 1 1 Effect of debt push-down from EFH Corp. (a) 5 — 5 Balance at March 31, 2015 $ (19,771 ) $ (34 ) $ (19,805 ) ____________ (a) Represents the interest and income tax effects of debt pushed down from EFH Corp. (Note 10).

Fair Value Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2016
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 willing 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 mathematical 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 with values 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 an EFH Corp. centralized risk management group that reports to the EFH Corp. 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. Probable loss from 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 14 for additional information regarding credit risk associated with our derivatives). We utilize published credit ratings and default rate factors 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 measurements 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: March 31, 2016 Level 1 Level 2 Level 3 (a) Reclassification (b) Total Assets: Commodity contracts $ 407 $ 51 $ 55 $ 4 $ 517 Nuclear decommissioning trust – equity securities (c) 385 — — — 385 Nuclear decommissioning trust – debt securities (c) — 332 — — 332 Subtotal $ 792 $ 383 $ 55 $ 4 $ 1,234 Assets measured at net asset value (d): Nuclear decommissioning trust - equity securities (c) 223 Total assets $ 1,457 Liabilities: Commodity contracts $ 118 $ 121 $ 30 $ 4 $ 273 Total liabilities $ 118 $ 121 $ 30 $ 4 $ 273 December 31, 2015 Level 1 Level 2 Level 3 (a) Reclassification (b) Total Assets: Commodity contracts $ 385 $ 41 $ 49 $ — $ 475 Nuclear decommissioning trust – equity securities (c) 380 219 — — 599 Nuclear decommissioning trust – debt securities (c) — 319 — — 319 Total assets $ 765 $ 579 $ 49 $ — $ 1,393 Liabilities: Commodity contracts $ 128 $ 64 $ 12 $ — $ 204 Total liabilities $ 128 $ 64 $ 12 $ — $ 204 _______________ (a) See table below for description of Level 3 assets and liabilities. (b) Fair values are determined on a contract basis, but certain contracts result in a current asset and a noncurrent liability, or vice versa, as presented in the condensed consolidated balance sheets. (c) The nuclear decommissioning trust investment is included in the investments line in the condensed consolidated balance sheets. See Note 16. (d) Certain investments measured at fair value using the net asset value per share (or its equivalent) have not been classified in the fair value hierarchy. This presentation is only allowed for periods beginning after December 15, 2015. The fair value amounts presented in this line are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the condensed consolidated balance sheets. 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 14 for further discussion regarding derivative instruments. Nuclear decommissioning trust assets represent securities held for the purpose of funding the future retirement and decommissioning of our nuclear generation facility. These investments include equity, debt and other fixed-income securities consistent with investment rules established by the NRC and the PUCT. 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, 2016 and December 31, 2015: March 31, 2016 Fair Value Contract Type (a) Assets Liabilities Total Valuation Technique Significant Unobservable Input Range (b) Electricity purchases and sales $ 1 $ (4 ) $ (3 ) Valuation Model Hourly price curve shape (d) $0 to $50/MWh Electricity spread options 13 (23 ) (10 ) Option Pricing Model Gas to power correlation (e) 15% to 45% Power volatility (f) 10% to 40% Electricity congestion revenue rights 36 (3 ) 33 Market Approach (g) Illiquid price differences between settlement points (h) $0 to $10/MWh Other (i) 5 — 5 Total $ 55 $ (30 ) $ 25 December 31, 2015 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) $15 to $35/MWh Hourly price curve shape (d) $15 to $45/MWh Electricity spread options 2 (7 ) (5 ) Option Pricing Model Gas to power correlation (e) 35% to 80% Power volatility (f) 10% to 35% Electricity congestion revenue rights 39 (4 ) 35 Market Approach (g) Illiquid price differences between settlement points (h) $0 to $10/MWh Other (i) 7 — 7 Total $ 49 $ (12 ) $ 37 ____________ (a) Electricity purchase and sales contracts include hedging positions in the ERCOT regions, as well as power contracts, the valuations of which include unobservable inputs related to the hourly shaping of the price curve. Electricity spread options 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. (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 hub and load zone 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 insufficient market data to consider the valuation liquid. (h) Based on the historical price differences between settlement points within the ERCOT hubs and load zones. (i) Other includes contracts for coal purchases, ancillary services, natural gas, power options and coal options. There were no significant transfers between Level 1 and Level 2 of the fair value hierarchy for the three months ended March 31, 2016 and 2015. 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, 2016 and 2015. The following table presents the changes in fair value of the Level 3 assets and liabilities for the three months ended March 31, 2016 and 2015. Three Months Ended March 31, 2016 2015 Net asset balance at beginning of period $ 37 $ 35 Total unrealized valuation gains (losses) (5 ) 16 Purchases, issuances and settlements (a): Purchases 14 19 Issuances (12 ) (3 ) Settlements (10 ) (8 ) Transfers into Level 3 (b) — — Transfers out of Level 3 (b) 1 1 Net change (c) (12 ) 25 Net asset balance at end of period $ 25 $ 60 Unrealized valuation gains (losses) relating to instruments held at end of period $ (4 ) $ 15 ____________ (a) Settlements reflect reversals of unrealized mark-to-market valuations previously recognized in net income. Purchases and issuances reflect option premiums paid or received. (b) Includes transfers due to changes in the observability of significant inputs. Transfers in and out occur at the end of each quarter, which is when the assessments are performed. All Level 3 transfers during the periods presented are in and out of Level 2. (c) Substantially all changes in values of commodity contracts are reported in the condensed statements of consolidated loss in net gain from commodity hedging and trading activities. 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 quarter.

Commodity And Other Derivative

Commodity And Other Derivative Contractual Assets And Liabilities	3 Months Ended
	Mar. 31, 2016
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, to manage commodity price risk. 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. Prior to the Petition Date, we had entered into interest rate swaps to manage our interest rate risk exposure. See Note 13 for a discussion of the fair value of derivatives. 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 2016 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. Consistent with existing Bankruptcy Court orders, 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 condensed statements of consolidated loss in net gain from commodity hedging and trading activities. Termination of Commodity Hedges and Interest Rate Swaps — Commodity hedges and interest rate swaps entered into prior to the Petition Date are deemed to be forward contracts under the Bankruptcy Code. The Bankruptcy Filing constituted an event of default under these arrangements, 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. 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. Additionally, certain counterparties to only our interest rate swaps hold the same first-lien security interest. The total net liability of $1.243 billion is subject to the terms of settlement of TCEH's first-lien claims ultimately approved by the Bankruptcy Court and is reported in the condensed consolidated balance sheets as a liability subject to compromise. Additionally, counterparties associated with the net liability are allowed, and have been receiving, adequate protection payments related to their claims as permitted by TCEH's cash collateral order approved by the Bankruptcy Court (see Note 7). 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 derivative contractual assets and liabilities as reported in the condensed consolidated balance sheets at March 31, 2016 and December 31, 2015 (noncurrent assets and liabilities are reported in other noncurrent assets and other noncurrent liabilities and deferred credits, respectively). Derivative asset and liability totals represent the net value of the contract, while the balance sheet totals represent the gross value of the contract. All amounts relate to commodity contracts. March 31, 2016 December 31, 2015 Derivative Assets Derivative Liabilities Total Derivative Assets Derivative Liabilities Total Current assets $ 496 $ 3 $ 499 $ 465 $ — $ 465 Noncurrent assets 18 — 18 10 — 10 Current liabilities — (261 ) (261 ) — (203 ) (203 ) Noncurrent liabilities (1 ) (11 ) (12 ) — (1 ) (1 ) Net assets (liabilities) $ 513 $ (269 ) $ 244 $ 475 $ (204 ) $ 271 At March 31, 2016 and December 31, 2015, there were no derivative positions accounted for as cash flow or fair value hedges. The pretax effect of derivatives on net income (loss), including realized and unrealized effects, totaled $56 million and $125 million in net gains in the three months ended March 31, 2016 and 2015, respectively, all of which related to commodity contracts reported in net gain from commodity and trading activities in the condensed statements of consolidated loss. Amounts represent 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. 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, 2016 and 2015. There were no amounts recognized in OCI for the three months ended March 31, 2016 and 2015. Accumulated other comprehensive income related to cash flow hedges at both March 31, 2016 and December 31, 2015 totaled $33 million in net losses (after-tax), substantially all of which relates to interest rate swaps previously accounted for as cash flow hedges. We expect that $2 million of net losses (after-tax) related to cash flow hedges included in accumulated other comprehensive income at March 31, 2016 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 condensed consolidated balance sheets 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 presented from period to period. Margin deposits that contractually offset these derivative instruments are reported separately in the condensed consolidated balance sheets. Margin deposits received from counterparties are either used for working capital or other general corporate purposes or, if there are restrictions on the use of cash, amounts are deposited in a separate restricted cash account. At March 31, 2016 and December 31, 2015, essentially all margin deposits held were unrestricted. We maintain standardized master netting agreements with certain counterparties that allow for the netting of positive and negative exposures. Generally, we utilize the International Swaps and Derivatives Association (ISDA) standardized contract for financial transactions, the Edison Electric Institute standardized contract for physical power transactions and the North American Energy Standards Board (NAESB) standardized contract for physical natural gas transactions. These contain credit enhancements that allow for the right to offset assets and liabilities 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 condensed consolidated balance sheets to net amounts after taking into consideration netting arrangements with counterparties and financial collateral: March 31, 2016 Amounts Presented in Balance Sheet Offsetting Instruments (a) Financial Collateral (Received) Pledged (b) Net Amounts Derivative assets: Commodity contracts $ 517 $ (160 ) $ (172 ) $ 185 Derivative liabilities: Commodity contracts (273 ) 160 12 (101 ) Net amounts $ 244 $ — $ (160 ) $ 84 December 31, 2015 Amounts Presented in Balance Sheet Offsetting Instruments (a) Financial Collateral (Received) Pledged (b) Net Amounts Derivative assets: Commodity contracts $ 475 $ (145 ) $ (147 ) $ 183 Derivative liabilities: Commodity contracts (204 ) 145 6 (53 ) Net amounts $ 271 $ — $ (141 ) $ 130 ____________ (a) Amounts presented 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, 2016 and December 31, 2015: March 31, 2016 December 31, 2015 Derivative type Notional Volume Unit of Measure Natural gas (a) 1,615 1,489 Million MMBtu Electricity 67,261 58,022 GWh Congestion Revenue Rights (b) 115,014 106,260 GWh Coal 8 10 Million US tons Fuel oil 32 35 Million gallons Uranium 455 75 Thousand pounds _______________ (a) Represents gross notional forward sales, purchases and options transactions, locational basis swaps and other natural gas transactions. (b) Represents gross forward purchases associated with instruments used to hedge electricity price differences between settlement points within ERCOT. Credit Risk-Related Contingent Features of Derivatives The agreements that govern our derivative instrument transactions may contain certain credit risk-related contingent features that could trigger liquidity requirements in the form of cash collateral, letters of credit or some other form of credit enhancement. Certain of these agreements require the posting of collateral if our credit rating is downgraded by one or more credit rating agencies; however, due to the Chapter 11 Cases, substantially all of such collateral posting requirements have already been effective. At March 31, 2016 and December 31, 2015, the fair value of liabilities related to derivative instruments under agreements with credit risk-related contingent features that were not fully collateralized totaled $111 million and $58 million , respectively. The liquidity exposure associated with these liabilities was reduced by cash and letter of credit postings with counterparties totaling $66 million and $31 million at March 31, 2016 and December 31, 2015, respectively. If all the credit risk-related contingent features related to these derivatives had been triggered, including cross-default provisions, the remaining liquidity requirements would be immaterial at both March 31, 2016 and December 31, 2015. In addition, certain derivative agreements include cross-default provisions that could result in the settlement of such contracts if there were a failure under other financing arrangements to meet payment terms or to comply with other covenants that could result in the acceleration of such indebtedness. At March 31, 2016 and December 31, 2015, the fair value of derivative liabilities subject to such cross-default provisions were immaterial. As discussed immediately above, the aggregate fair values of liabilities under derivative agreements with credit risk-related contingent features, including cross-default provisions, totaled $113 million and $59 million at March 31, 2016 and December 31, 2015, respectively. These amounts are before consideration of cash and letter of credit collateral posted, net accounts receivable and derivative assets under netting arrangements and assets subject to related liens. Some commodity derivative contracts contain credit risk-related contingent features that do not provide for specific amounts to be posted if the features are triggered. These provisions include material adverse change, performance assurance, and other clauses that generally provide counterparties with the right to request additional credit enhancements. The amounts disclosed above exclude credit risk-related contingent features that do not provide for specific amounts or exposure calculations. Concentrations of Credit Risk Related to Derivatives TCEH has concentrations of credit risk with the counterparties to its derivative contracts. At March 31, 2016, total credit risk exposure to all counterparties related to derivative contracts totaled $552 million (including associated accounts receivable). The net exposure to those counterparties totaled $187 million at March 31, 2016 after taking into effect netting arrangements, setoff provisions and collateral, with the largest net exposure to a single counterparty totaling $104 million . At March 31, 2016, the credit risk exposure to the banking and financial sector represented 80% of the total credit risk exposure and 62% of the net exposure. 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, 2016
Related Party Transactions [Abstract]
Related Party Transactions	RELATED-PARTY TRANSACTIONS The following represent our significant related-party transactions. • 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 $220 million and $236 million for the three months ended March 31, 2016 and 2015, respectively. The fees are based on rates regulated by the PUCT that apply to all REPs. The condensed consolidated balance sheets at March 31, 2016 and December 31, 2015 reflect amounts due currently to Oncor totaling $101 million and $118 million , respectively, (included in trade accounts and other payables to affiliates) largely related to these electricity delivery fees. • In the first quarter of 2014, a cash contribution totaling $84 million was made to the EFH Corp. retirement plan, of which $64 million was contributed by Oncor and $20 million was contributed by TCEH. In December 2015, an additional cash contribution totaling $67 million was made to the EFH Corp. retirement plan, of which $51 million was contributed by Oncor and $16 million was contributed by TCEH. These contributions resulted in the EFH Corp. retirement plan being fully funded as calculated under the provisions of the Employee Retirement Income Security Act of 1974, as amended. 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 was fully funded. The payments by TCEH were accounted for as an advance to EFH Corp. that will be settled as pension expense is allocated to TCEH in the normal course. The balance of the advance totaled $22 million at March 31, 2016, with $6 million recorded as a current asset and $16 million recorded as a noncurrent asset. The balance of the advance totaled $24 million at December 31, 2015, with $6 million recorded as a current asset and $18 million recorded as a noncurrent asset. Receivables from affiliates are measured at historical cost and primarily have consisted of notes receivable for cash loaned to EFH Corp. for debt principal and interest payments and other general corporate purposes of EFH Corp. as discussed above. EFCH reviews economic conditions, counterparty credit scores and historical payment activity to assess the overall collectability of its affiliated receivables. There were no credit loss allowances at March 31, 2016 and December 31, 2015. • A subsidiary of EFH Corp. bills our subsidiaries for information technology, financial, accounting and other administrative services at cost. These charges, which are largely settled in cash and primarily reported in SG&A expenses, totaled $60 million and $51 million for the three months ended March 31, 2016 and 2015, respectively. For the three months ended March 31, 2016, TCEH settled a $2 million payable related to information technology assets purchased from a subsidiary of EFH Corp. in December 2015. For the three months ended March 31, 2015, TCEH settled a $15 million payable related to information technology assets purchased from a subsidiary of EFH Corp. in 2014. The assets are substantially for the use of TCEH and its subsidiaries. • 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 investments in our condensed consolidated balance sheets, will ultimately be sufficient to fund the future decommissioning liability, reported in noncurrent liabilities in our condensed consolidated balance sheets. The delivery fee surcharges remitted to TCEH totaled $4 million for both the three months ended March 31, 2016 and 2015. 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, 2016 and December 31, 2015, the excess of the trust fund balance over the decommissioning liability resulted in a payable totaling $424 million and $409 million , respectively, and is reported in noncurrent liabilities. • EFH Corp. files consolidated federal income tax and Texas state margin tax returns that include our results; however, under a Federal and State Income Tax Allocation Agreement, our federal income tax and Texas margin tax expense and related balance sheet amounts, including income taxes payable to or receivable from EFH Corp., are recorded as if we file our own corporate income tax return. As of March 31, 2016 and December 31, 2015, we had current income tax liabilities of $14 million and $10 million , respectively. We made no tax payments to EFH Corp. for the three months ended March 31, 2016 or 2015. See Note 5 for discussion of cessation of payment of federal income taxes pursuant to the Settlement Agreement. • 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, 2016 and December 31, 2015, TCEH had posted letters of credit and/or cash in the amount of $6 million for the benefit of Oncor. • 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. • 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. See Notes 9 and 10 for discussion of guarantees and push down of certain EFH Corp. debt.

Supplementary Financial Informa

Supplementary Financial Information	3 Months Ended
	Mar. 31, 2016
Supplementary Financial Information [Abstract]
Supplementary Financial Information	SUPPLEMENTARY FINANCIAL INFORMATION Other Income and Deductions Three Months Ended March 31, 2016 2015 Other income: Mineral rights royalty income $ 1 $ 1 All other — 2 Total other income $ 1 $ 3 Other deductions: Write-off of generation equipment $ 20 $ — Impairment of favorable purchase contracts (Note 4) — 8 Impairment of emission allowances (Note 4) — 51 All other 1 1 Total other deductions $ 21 $ 60 Restricted Cash March 31, 2016 December 31, 2015 Current Noncurrent Assets Current Noncurrent Assets Amounts related to the DIP Facility (Note 9) $ 661 $ — $ 519 $ — Amounts related to TCEH's pre-petition Letter of Credit Facility (Note 10) — 507 — 507 Total restricted cash $ 661 $ 507 $ 519 $ 507 Trade Accounts Receivable March 31, 2016 December 31, 2015 Wholesale and retail trade accounts receivable $ 454 $ 542 Allowance for uncollectible accounts (7 ) (9 ) Trade accounts receivable — net $ 447 $ 533 Gross trade accounts receivable at March 31, 2016 and December 31, 2015 included unbilled revenues of $183 million and $231 million , respectively. Allowance for Uncollectible Accounts Receivable Three Months Ended March 31, 2016 2015 Allowance for uncollectible accounts receivable at beginning of period $ 9 $ 15 Increase for bad debt expense 5 9 Decrease for account write-offs (7 ) (9 ) Allowance for uncollectible accounts receivable at end of period $ 7 $ 15 Inventories by Major Category March 31, 2016 December 31, 2015 Materials and supplies $ 222 $ 226 Fuel stock 196 170 Natural gas in storage 30 32 Total inventories $ 448 $ 428 Investments March 31, 2016 December 31, 2015 Nuclear plant decommissioning trust $ 940 $ 918 Land 36 36 Miscellaneous other 8 8 Total investments $ 984 $ 962 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 15). The nuclear decommissioning trust fund is not a debtor under the Chapter 11 Cases. A summary of investments in the fund follows: March 31, 2016 Cost (a) Unrealized gain Unrealized loss Fair market value Debt securities (b) $ 315 $ 17 $ — $ 332 Equity securities (c) 296 320 (8 ) 608 Total $ 611 $ 337 $ (8 ) $ 940 December 31, 2015 Cost (a) Unrealized gain Unrealized loss Fair market value Debt securities (b) $ 310 $ 11 $ (2 ) $ 319 Equity securities (c) 291 315 (7 ) 599 Total $ 601 $ 326 $ (9 ) $ 918 ____________ (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 3.60% and 3.68% at March 31, 2016 and December 31, 2015, respectively, and an average maturity of 8 years at both March 31, 2016 and December 31, 2015. (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, 2016 mature as follows: $109 million in one to five years, $74 million in five to ten years and $149 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, 2016 2015 Realized gains $ 1 $ — Realized losses $ (1 ) $ (1 ) Proceeds from sales of securities $ 67 $ 23 Investments in securities $ (71 ) $ (27 ) Property, Plant and Equipment At March 31, 2016 and December 31, 2015, property, plant and equipment of $9.273 billion and $9.349 billion , respectively, is stated net of accumulated depreciation and amortization of $4.177 billion and $4.037 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 condensed consolidated balance sheets, for the three months ended March 31, 2016: Nuclear Plant Decommissioning Mining Land Reclamation Other Total Liability at December 31, 2015 $ 508 $ 215 $ 107 $ 830 Additions: Accretion 7 5 2 14 Incremental reclamation costs — 14 3 17 Reductions: Payments — (15 ) — (15 ) Liability at March 31, 2016 515 219 112 846 Less amounts due currently — (60 ) — (60 ) Noncurrent liability at March 31, 2016 $ 515 $ 159 $ 112 $ 786 Other Noncurrent Liabilities and Deferred Credits The balance of other noncurrent liabilities and deferred credits consists of the following: March 31, 2016 December 31, 2015 Uncertain tax positions, including accrued interest $ 41 $ 41 Asset retirement and mining reclamation obligations 786 764 Unfavorable purchase and sales contracts 537 543 Nuclear decommissioning fund excess over asset retirement obligation (Note 15) 424 409 Other, including retirement and other employee benefits 31 23 Total other noncurrent liabilities and deferred credits $ 1,819 $ 1,780 Unfavorable Purchase and Sales Contracts — The amortization of unfavorable purchase and sales contracts totaled $6 million for both the three months ended March 31, 2016 and 2015. 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 2016 $ 24 2017 $ 24 2018 $ 24 2019 $ 24 2020 $ 24 Fair Value of Debt March 31, 2016 December 31, 2015 Debt: Carrying Amount Fair Value Carrying Amount Fair Value Borrowings under debtor-in-possession credit facility (Note 9) $ 1,425 $ 1,418 $ 1,425 $ 1,411 Long-term debt not subject to compromise, excluding capital lease obligations (Note 9) $ 46 $ 48 $ 49 $ 53 We determine fair value in accordance with accounting standards as discussed in Note 13, and at March 31, 2016, our debt fair value represents Level 2 valuations. We obtain security pricing from an independent party 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. The fair value estimates of our pre-petition notes, loans and other debt reported as liabilities subject to compromise have been excluded from the table above. As a result of our ongoing Chapter 11 Cases, obtaining the fair value estimates of our pre-petition debt subject to compromise is impractical, and the fair values will ultimately be decided through the Chapter 11 Cases. Supplemental Cash Flow Information Three Months Ended March 31, 2016 2015 Cash payments related to: Interest paid (a) $ 336 $ 323 Capitalized interest (3 ) (3 ) Interest paid (net of capitalized interest) (a) $ 333 $ 320 Reorganization items (b) $ 41 $ 35 Noncash investing and financing activities: Construction expenditures (c) $ 82 $ 65 ____________ (a) This amount includes amounts paid for adequate protection. (b) Represents cash payments for legal and other consulting services. (c) Represents end-of-period accruals for ongoing construction projects.

Supplemental Guarantor Condense

Supplemental Guarantor Condensed Financial Information	3 Months Ended
	Mar. 31, 2016
Supplemental Guarantor Condensed Financial Information [Abstract]
Supplemental Guarantor Condensed Financial Information	SUPPLEMENTAL GUARANTOR CONDENSED FINANCIAL INFORMATION At March 31, 2016 TCEH and TCEH Finance, as Co-Issuers, had outstanding $4.874 billion aggregate principal amount of pre-petition 10.25% Senior Notes Due 2015, 10.25% Senior Notes due 2015 Series B and Toggle Notes (collectively, the TCEH Senior Notes) and $1.571 billion aggregate principal amount of pre-petition 15% Senior Secured Second Lien Notes due 2021 and 15% Senior Secured Second Lien Notes due 2021 (Series B) (collectively, the TCEH Senior Secured Second Lien Notes). The TCEH Senior Notes and the TCEH Senior Secured Second Lien Notes are unconditionally guaranteed by EFCH and by each subsidiary (all 100% owned by TCEH) that guarantees the TCEH Senior Secured Facilities (collectively, the Guarantors). The guarantees issued by the Guarantors are full and unconditional, joint and several guarantees of the TCEH Senior Notes and the TCEH Senior Secured Second Lien Notes. The guarantees of the TCEH Senior Notes rank equally with any senior unsecured indebtedness of the Guarantors and rank effectively junior to all of the secured indebtedness of the Guarantors to the extent of the assets securing that indebtedness. The guarantees of the TCEH Senior Secured Second Lien Notes 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 (see Note 12 to the Financial Statements in our 2015 Form 10-K). All other subsidiaries of EFCH, either direct or indirect, do not guarantee the TCEH Senior Notes or TCEH Senior Secured Second Lien Notes (collectively the Non-Guarantors). The indentures governing the TCEH Senior Notes and the TCEH Senior Secured Second Lien Notes contain certain restrictions, subject to certain exceptions, on EFCH's ability to pay dividends or make investments. See Note 12 to the Financial Statements in our 2015 Form 10-K. The following tables have been prepared in accordance with Regulation S-X Rule 3-10, "Financial Statements of Guarantors and Issuers of Guaranteed Securities Registered or Being Registered" in order to present the condensed consolidating statements of loss for the three months ended March 31, 2016 and 2015 and of cash flows for the three months ended March 31, 2016 and 2015 of EFCH (Parent), TCEH (Issuer), the Guarantors and the Non-Guarantors and the condensed consolidating balance sheets at March 31, 2016 and December 31, 2015 of the Parent, Issuer, the Guarantors and the Non-Guarantors. Investments in consolidated subsidiaries are accounted for under the equity method. The presentations reflect the application of SEC Staff Accounting Bulletin Topic 5J, "Push Down Basis of Accounting Required in Certain Limited Circumstances," including the effects of the push down of $30 million of the EFH Corp. pre-petition 10.875% Senior Notes and EFH Corp. pre-petition 11.25%/12.00% Senior Toggle Notes to the Parent at both March 31, 2016 and December 31, 2015 and the TCEH Senior Notes, TCEH Senior Secured Notes, TCEH Senior Secured Second Lien Notes and TCEH Senior Secured Facilities to the Other Guarantors at March 31, 2016 and December 31, 2015 (see Note 10 and Note 12 to the Financial Statements in our 2015 Form 10-K). TCEH Finance's sole function is to be the co-issuer of certain TCEH debt securities; therefore, it has no other independent assets, liabilities or operations. Amounts reported as advances to affiliates arise from recurring intercompany transactions among EFCH, TCEH and TCEH’s subsidiaries in the normal course of business. In consideration of the Bankruptcy Filing, the ultimate settlement of the advances is uncertain and is dependent on the Chapter 11 plan ultimately approved. Accordingly, as of March 31, 2016, the Other Guarantors' pre-petition advances from parent have been reclassified to membership interests as a noncash transaction. EFCH (parent entity) received no dividends/distributions from its consolidated subsidiaries for the three months ended March 31, 2016 and 2015. ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Condensed Consolidating Statements of Income (Loss) Three Months Ended March 31, 2016 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Operating revenues $ — $ — $ 1,049 $ — $ — $ 1,049 Fuel, purchased power costs and delivery fees — — (554 ) — — (554 ) Net gain from commodity hedging and trading activities — — 64 — — 64 Operating costs — — (219 ) — — (219 ) Depreciation and amortization — (2 ) (137 ) — — (139 ) Selling, general and administrative expenses — 2 (162 ) — — (160 ) Other income — — 1 — — 1 Other deductions — — (21 ) — — (21 ) Interest income — 15 53 — (68 ) — Interest expense and related charges (1 ) (390 ) (13 ) — 68 (336 ) Reorganization items — (21 ) (1 ) — — (22 ) Income (loss) before income taxes (1 ) (396 ) 60 — — (337 ) Income tax (expense) benefit 3 (3 ) (8 ) — 4 (4 ) Equity earnings (losses) of subsidiaries (343 ) 56 — — 287 — Net income (loss) $ (341 ) $ (343 ) $ 52 $ — $ 291 $ (341 ) Condensed Consolidating Statements of Comprehensive Income (Loss) Three Months Ended March 31, 2016 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Net income (loss) (341 ) (343 ) 52 — 291 (341 ) Other comprehensive income — — — — — — Comprehensive income (loss) $ (341 ) $ (343 ) $ 52 $ — $ 291 $ (341 ) ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Condensed Consolidating Statements of Loss Three Months Ended March 31, 2015 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Operating revenues $ — $ — $ 1,272 $ — $ — $ 1,272 Fuel, purchased power costs and delivery fees — — (613 ) — — (613 ) Net gain from commodity hedging and trading activities — — 103 — — 103 Operating costs — — (193 ) — — (193 ) Depreciation and amortization — (1 ) (214 ) — — (215 ) Selling, general and administrative expenses — — (161 ) — — (161 ) Impairment of goodwill — (700 ) — — — (700 ) Impairment of long-lived assets — — (676 ) — — (676 ) Other income — — 3 — — 3 Other deductions — — (60 ) — — (60 ) Interest income — 1 18 — (19 ) — Interest expense and related charges (1 ) (337 ) 2 — 19 (317 ) Reorganization items — (43 ) (30 ) — — (73 ) Loss before income taxes (1 ) (1,080 ) (549 ) — — (1,630 ) Income tax benefit — 112 176 — 5 293 Equity earnings (losses) of subsidiaries (1,336 ) (368 ) — — 1,704 — Net loss $ (1,337 ) $ (1,336 ) $ (373 ) $ — $ 1,709 $ (1,337 ) Condensed Consolidating Statements of Comprehensive Loss Three Months Ended March 31, 2015 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Net loss (1,337 ) (1,336 ) (373 ) — 1,709 (1,337 ) Other comprehensive income 1 1 — — (1 ) 1 Comprehensive loss $ (1,336 ) $ (1,335 ) $ (373 ) $ — $ 1,708 $ (1,336 ) ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Condensed Consolidating Statements of Cash Flows Three Months Ended March 31, 2016 (millions of dollars) Parent/ Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Cash provided by (used in) operating activities $ — $ (342 ) $ 151 $ — $ — $ (191 ) Cash flows – financing activities: Notes/advances due to affiliates 2 58 — — (60 ) — Repayments/repurchases of debt (2 ) — (3 ) — — (5 ) Cash provided by (used in) financing activities — 58 (3 ) — (60 ) (5 ) Cash flows – investing activities: Capital expenditures — — (83 ) — — (83 ) Nuclear fuel purchases — — (10 ) — — (10 ) Settlements of notes due from affiliates — — (60 ) — 60 — Changes in restricted cash — (142 ) — — — (142 ) Proceeds from sales of nuclear decommissioning trust fund securities — — 67 — — 67 Investments in nuclear decommissioning trust fund securities — — (71 ) — — (71 ) Other, net — — 3 — — 3 Cash used in investing activities — (142 ) (154 ) — 60 (236 ) Net change in cash and cash equivalents — (426 ) (6 ) — — (432 ) Cash and cash equivalents – beginning balance — 1,368 22 10 — 1,400 Cash and cash equivalents – ending balance $ — $ 942 $ 16 $ 10 $ — $ 968 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Condensed Consolidating Statements of Cash Flows Three Months Ended March 31, 2015 (millions of dollars) Parent/ Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Cash provided by (used in) operating activities $ (3 ) $ (415 ) $ 311 $ — $ — $ (107 ) Cash flows – financing activities: Notes/advances due to affiliates 4 169 — — (173 ) — Repayments/repurchases of debt (1 ) — (8 ) — — (9 ) Cash provided by (used in) financing activities 3 169 (8 ) — (173 ) (9 ) Cash flows – investing activities: Capital expenditures — — (115 ) — — (115 ) Nuclear fuel purchases — — (5 ) — — (5 ) Settlements of notes due from affiliates — — (173 ) — 173 — Changes in restricted cash — 28 — — — 28 Proceeds from sales of nuclear decommissioning trust fund securities — — 23 — — 23 Investments in nuclear decommissioning trust fund securities — — (27 ) — — (27 ) Other, net — (11 ) (3 ) — — (14 ) Cash provided by (used in) investing activities — 17 (300 ) — 173 (110 ) Net change in cash and cash equivalents — (229 ) 3 — — (226 ) Cash and cash equivalents – beginning balance — 1,826 16 1 — 1,843 Cash and cash equivalents – ending balance $ — $ 1,597 $ 19 $ 1 $ — $ 1,617 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Condensed Consolidating Balance Sheets March 31, 2016 (millions of dollars) Parent Issuer Other Non-guarantors Eliminations Consolidated ASSETS Current assets: Cash and cash equivalents $ — $ 942 $ 16 $ 10 $ — $ 968 Restricted cash — 661 — — — 661 Advance to parent — 6 — — — 6 Trade accounts receivable – net — — 447 — — 447 Accounts receivable from affiliates — 61 — — (61 ) — Inventories — — 448 — — 448 Commodity and other derivative contractual assets — — 499 — — 499 Other current assets — 2 91 — — 93 Total current assets — 1,672 1,501 10 (61 ) 3,122 Restricted cash — 507 — — — 507 Investments (33,164 ) 9,169 1,006 4 23,969 984 Property, plant and equipment – net — — 9,270 3 — 9,273 Advances to parent — 16 — — — 16 Goodwill — 152 — — — 152 Identifiable intangible assets – net — — 1,170 — — 1,170 Accumulated deferred income taxes 3 357 405 11 (776 ) — Other noncurrent assets — 3 47 — — 50 Total assets $ (33,161 ) $ 11,876 $ 13,399 $ 28 $ 23,132 $ 15,274 LIABILITIES AND MEMBERSHIP INTERESTS Borrowings under debtor-in-possession credit facility $ — $ 1,425 $ — $ — $ — $ 1,425 Long-term debt due currently 14 — 15 — — 29 Trade accounts payable — 8 343 — — 351 Trade accounts and other payables to affiliates — — 164 — (61 ) 103 Commodity and other derivative contractual liabilities — — 261 — — 261 Margin deposits related to commodity positions — — 176 — — 176 Accrued income taxes payable to parent — — 14 — — 14 Accrued taxes other than income $ — $ — $ 66 $ — $ — $ 66 Accrued interest — 122 1 — — 123 Other current liabilities — 20 208 — — 228 Total current liabilities 14 1,575 1,248 — (61 ) 2,776 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Condensed Consolidating Balance Sheets March 31, 2016 (millions of dollars) Parent Issuer Other Non-guarantors Eliminations Consolidated Accumulated deferred income taxes — — — — 213 213 Notes or other liabilities due affiliates — — — 2 (2 ) — Long-term debt, less amounts due currently 19 — 2 — — 21 Liabilities subject to compromise 44 43,468 31,601 — (41,337 ) 33,776 Other noncurrent liabilities and deferred credits — (3 ) 1,822 — — 1,819 Total liabilities 77 45,040 34,673 2 (41,187 ) 38,605 Total membership interests (33,238 ) (33,164 ) (21,274 ) 26 64,319 (23,331 ) Total liabilities and membership interests $ (33,161 ) $ 11,876 $ 13,399 $ 28 $ 23,132 $ 15,274 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Condensed Consolidating Balance Sheets December 31, 2015 (millions of dollars) Parent Issuer Other Non-guarantors Eliminations Consolidated ASSETS Current assets: Cash and cash equivalents $ — $ 1,368 $ 22 $ 10 $ — $ 1,400 Restricted cash — 519 — — — 519 Advances to parent — 6 — — — 6 Trade accounts receivable – net — — 533 — — 533 Accounts receivable from affiliates — 92 — — (92 ) — Inventories — — 428 — — 428 Commodity and other derivative contractual assets — — 465 — — 465 Other current assets — 3 68 — — 71 Total current assets — 1,988 1,516 10 (92 ) 3,422 Restricted cash — 507 — — — 507 Investments (32,818 ) 9,095 983 5 23,697 962 Property, plant and equipment – net — 12 9,334 3 — 9,349 Advances to parent — 18 — — — 18 Goodwill — 152 — — — 152 Identifiable intangible assets – net — 31 1,148 — — 1,179 Accumulated deferred income taxes — 438 393 11 (842 ) — Other noncurrent assets, principally unamortized debt amendment and issuance costs — 1 38 — — 39 Total assets $ (32,818 ) $ 12,242 $ 13,412 $ 29 $ 22,763 $ 15,628 LIABILITIES AND MEMBERSHIP INTERESTS Current liabilities: Borrowings under credit and other facilities $ — $ 1,425 $ — $ — $ — $ 1,425 Long-term debt due currently 15 — 16 — — 31 Trade accounts payable — 21 373 — — 394 Trade accounts and other payables to affiliates — — 211 — (92 ) 119 Commodity and other derivative contractual liabilities — — 203 — — 203 Margin deposits related to commodity positions — — 152 — — 152 Accrued income taxes payable to parent — — 10 — — 10 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Condensed Consolidating Balance Sheets December 31, 2015 (millions of dollars) Parent Issuer Other Non-guarantors Eliminations Consolidated Accrued taxes other than income $ — $ — $ 98 $ — $ — $ 98 Accrued interest — 119 1 — — 120 Other current liabilities — 32 242 — — 274 Total current liabilities 15 1,597 1,306 — (92 ) 2,826 Accumulated deferred income taxes — — — — 213 213 Notes or other liabilities due affiliates — — — 2 (2 ) — Long-term debt, less amounts due currently 20 — 3 — — 23 Liabilities subject to compromise 44 43,468 31,601 — (41,337 ) 33,776 Other noncurrent liabilities and deferred credits — (4 ) 1,784 — — 1,780 Total liabilities 79 45,061 34,694 2 (41,218 ) 38,618 Total membership interests (32,897 ) (32,819 ) (21,282 ) 27 63,981 (22,990 ) Total liabilities and membership interests $ (32,818 ) $ 12,242 $ 13,412 $ 29 $ 22,763 $ 15,628

Business And Significant Acco23

Business And Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2016
Accounting Policies [Abstract]
Basis of Presentation, Including Application of Bankruptcy Accounting	Basis of Presentation, Including Application of Bankruptcy Accounting The condensed consolidated financial statements have been prepared in accordance with US GAAP. The condensed consolidated financial statements have been prepared as if EFCH is a going concern and contemplate the realization of assets and liabilities in the normal course of business. The condensed consolidated financial statements reflect the application of Financial Accounting Standards Board Accounting Standards Codification 852, Reorganizations (ASC 852) . During the pendency of the Chapter 11 Cases, 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. ASC 852 applies to entities that have filed a petition for bankruptcy under Chapter 11 of the Bankruptcy Code. The guidance requires that transactions and events directly associated with the reorganization be distinguished from the ongoing operations of the business. In addition, the guidance provides for changes in the accounting and presentation of liabilities. See Notes 8 and 10 for discussion of these accounting and reporting changes. 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 2015 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	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 and estimates of expected allowed claims. 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.

Goodwill And Identifiable Int24

Goodwill And Identifiable Intangible Assets (Tables)	3 Months Ended
	Mar. 31, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Goodwill	The following table provides information regarding our goodwill balance, all of which arose in connection with accounting for the Merger. None of the goodwill is being deducted for tax purposes. Goodwill before impairment charges $ 18,322 Accumulated noncash impairment charges (18,170 ) Balance at March 31, 2016 and December 31, 2015 $ 152
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: March 31, 2016 December 31, 2015 Identifiable Intangible Asset Gross Carrying Amount Accumulated Amortization Net Gross Carrying Amount Accumulated Amortization Net Retail customer relationship $ 463 $ 445 $ 18 $ 463 $ 442 $ 21 Software and other technology-related assets 397 239 158 385 224 161 Other identifiable intangible assets (a) 58 24 34 72 35 37 Total identifiable intangible assets subject to amortization $ 918 $ 708 210 $ 920 $ 701 219 Retail trade name (not subject to amortization) 955 955 Mineral interests (not currently subject to amortization) 5 5 Total identifiable intangible assets $ 1,170 $ 1,179 ____________ (a) Includes favorable purchase and sales contracts, environmental allowances and credits and mining development costs. See discussion below regarding impairment charges recorded in the three months ended March 31, 2015 related to other identifiable intangible assets.
Schedule of amortization expense related to intangible assets (including income statement line item)	Amortization expense related to finite-lived identifiable intangible assets (including the condensed statements of consolidated loss line item) consisted of: Identifiable Intangible Asset Condensed Statements of Consolidated Loss Line Three Months Ended March 31, 2016 2015 Retail customer relationship Depreciation and amortization $ 3 $ 4 Software and other technology-related assets Depreciation and amortization 15 14 Other identifiable intangible assets Operating revenues/fuel, purchased power costs and delivery fees/depreciation and amortization 3 5 Total amortization expense (a) $ 21 $ 23 _______________ (a) Amounts recorded in depreciation and amortization totaled $20 million and $18 million for the three months ended March 31, 2016 and 2015, respectively.
Schedule of estimated aggregate amortization expense of intangible assets for each of the next five fiscal years	The estimated aggregate amortization expense of identifiable intangible assets for each of the next five fiscal years is as follows: Year Estimated Amortization Expense 2016 $ 84 2017 $ 61 2018 $ 38 2019 $ 18 2020 $ 10

Income Taxes (Tables)

Income Taxes (Tables)	3 Months Ended
	Mar. 31, 2016
Income Tax Disclosure [Abstract]
Schedule of Effective Income Tax Rate Reconciliation	The calculation of our effective tax rate is as follows: Three Months Ended March 31, 2016 2015 Loss before income taxes $ (337 ) $ (1,630 ) Income tax (expense) benefit $ (4 ) $ 293 Effective tax rate (1.2 )% 18.0 %

Interest Expense and Related 26

Interest Expense and Related Charges (Tables)	3 Months Ended
	Mar. 31, 2016
Interest Expense and Related Charges [Abstract]
Schedule of interest expense and related charges	Three Months Ended March 31, 2016 2015 Interest paid/accrued on debtor-in-possession financing $ 16 $ 15 Adequate protection amounts paid/accrued 322 302 Interest paid/accrued on pre-petition debt 1 3 Capitalized interest (3 ) (3 ) Total interest expense and related charges $ 336 $ 317
Contractual Interest Expense On Pre-Petition Liabilities	Three Months Ended March 31, 2016 Three Months Ended March 31, 2015 Entity: Contractual Interest on Adequate Protection Contractual Interest on Contractual Interest on Adequate Protection Contractual Interest on EFCH $ — $ — $ — $ 2 $ — $ 2 TCEH 531 307 224 513 288 $ 225 Total $ 531 $ 307 $ 224 $ 515 $ 288 $ 227

Reorganization Items (Tables)

Reorganization Items (Tables)	3 Months Ended
	Mar. 31, 2016
Reorganization Items [Abstract]
Reorganization Items	The following table presents reorganization items incurred in the three months ended March 31, 2016 and 2015 as reported in the condensed statements of consolidated loss: Three Months Ended March 31, 2016 2015 Expenses related to legal advisory and representation services $ 13 $ 26 Expenses related to other professional consulting and advisory services 8 15 Contract claims adjustments 1 32 Total reorganization items $ 22 $ 73

Debtor-In-Possession Borrowin28

Debtor-In-Possession Borrowing Facility and Long-Term Debt Not Subject to Compromise (Tables)	3 Months Ended
	Mar. 31, 2016
Debtor-In-Possession Borrowing Facilities [Abstract]
Schedule of Line of Credit Facilities	March 31, 2016 DIP Facility Facility Limit Available Cash Borrowing Capacity Available Letter of Credit Capacity DIP Revolving Credit Facility (a) $ 1,950 $ 1,950 $ — DIP Term Loan Facility (b) 1,425 — 139 Total DIP Facility $ 3,375 $ 1,950 $ 139 ___________ (a) Facility used for general corporate purposes. No amounts were borrowed at March 31, 2016. Pursuant to an order of the Bankruptcy Court, the TCEH Debtors may not have more than $1.650 billion of DIP Revolving Credit Facility cash borrowings outstanding without written consent of the TCEH committee of unsecured creditors and the ad hoc group of TCEH unsecured noteholders or further order of the Bankruptcy Court. (b) Facility used for general corporate purposes, including but not limited to, $800 million for issuing letters of credit.
Schedule of Long-term Debt Instruments	Long-Term Debt Not Subject to Compromise — Amounts presented in the table below represent pre-petition liabilities that are not subject to compromise due to the debt being fully collateralized or specific orders from the Bankruptcy Court approving repayment of the debt. March 31, December 31, EFCH 9.58% Fixed Notes due in annual installments through December 4, 2019 (a) $ 13 $ 13 8.254% Fixed Notes due in quarterly installments through December 31, 2021 (a) 23 24 Unamortized fair value discount (b) (2 ) (2 ) Total EFCH 34 35 TCEH 7.48% Fixed Secured Facility Bonds with amortizing payments through January 2017 (c) 10 13 Capital lease obligations 4 5 Other 2 2 Unamortized discount — (1 ) Total TCEH 16 19 Total EFCH consolidated 50 54 Less amounts due currently (29 ) (31 ) Total long-term debt not subject to compromise $ 21 $ 23 ____________ (a) Approved by the Bankruptcy Court for repayment. (b) Amount represents unamortized fair value adjustments recorded under purchase accounting. (c) Debt issued by trust and secured by assets held by the trust. March 31, December 31, 2015 TCEH Senior Secured Facilities: TCEH Floating Rate Term Loan Facilities due October 10, 2014 $ 3,809 $ 3,809 TCEH Floating Rate Letter of Credit Facility due October 10, 2014 42 42 TCEH Floating Rate Revolving Credit Facility due October 10, 2016 2,054 2,054 TCEH Floating Rate Term Loan Facilities due October 10, 2017 15,691 15,691 TCEH Floating Rate Letter of Credit Facility due October 10, 2017 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 1,833 1,833 10.25% Fixed Senior Notes due November 1, 2015, Series B 1,292 1,292 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 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 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 Other: Other 1 1 Total TCEH 31,668 31,668 EFCH (parent entity) Floating Rate Junior Subordinated Debentures, Series D due January 30, 2037 1 1 8.175% Fixed Junior Subordinated Debentures, Series E due January 30, 2037 8 8 Subtotal 9 9 March 31, 2016 December 31, 2015 EFH Corp. pre-petition debt pushed down (a) 10.875% Fixed Senior Notes due November 1, 2017 $ 16 $ 16 11.25%/12.00% Senior Toggle Notes due November 1, 2017 14 14 Subtotal — EFH Corp. debt pushed down 30 30 Total EFCH (parent entity) 39 39 Total EFCH consolidated notes, loans and other debt $ 31,707 $ 31,707 ____________ (a) Represents 50% of the amount of these EFH Corp. securities guaranteed by, and pushed down to (pushed-down debt), EFCH (parent entity) per the discussion below under "Guarantees and Push Down of EFH Corp. Pre-Petition Debt."

Liabilities Subject To Compro29

Liabilities Subject To Compromise (Tables)	3 Months Ended
	Mar. 31, 2016
Debt and Capital Lease Obligations [Abstract]
Liabilities Subject To Compromise	The amounts classified as LSTC reflect the company's estimate of pre-petition liabilities and other expected allowed claims to be addressed in the Chapter 11 Cases and may be subject to future adjustment as the Chapter 11 Cases proceed. Amounts classified to LSTC do not include pre-petition liabilities that are fully collateralized by letters of credit or cash deposits. The following table presents LSTC as reported in the condensed consolidated balance sheets at March 31, 2016 and December 31, 2015: March 31, December 31, Notes, loans and other debt per the following table $ 31,707 $ 31,707 Accrued interest on notes, loans and other debt 648 648 Net liability under terminated TCEH interest rate swap and natural gas hedging agreements (Note 14) 1,243 1,243 Trade accounts payable and other expected allowed claims 177 177 Advances and other payables to affiliates 1 1 Total liabilities subject to compromise $ 33,776 $ 33,776
Schedule of Long-term Debt Instruments	Long-Term Debt Not Subject to Compromise — Amounts presented in the table below represent pre-petition liabilities that are not subject to compromise due to the debt being fully collateralized or specific orders from the Bankruptcy Court approving repayment of the debt. March 31, December 31, EFCH 9.58% Fixed Notes due in annual installments through December 4, 2019 (a) $ 13 $ 13 8.254% Fixed Notes due in quarterly installments through December 31, 2021 (a) 23 24 Unamortized fair value discount (b) (2 ) (2 ) Total EFCH 34 35 TCEH 7.48% Fixed Secured Facility Bonds with amortizing payments through January 2017 (c) 10 13 Capital lease obligations 4 5 Other 2 2 Unamortized discount — (1 ) Total TCEH 16 19 Total EFCH consolidated 50 54 Less amounts due currently (29 ) (31 ) Total long-term debt not subject to compromise $ 21 $ 23 ____________ (a) Approved by the Bankruptcy Court for repayment. (b) Amount represents unamortized fair value adjustments recorded under purchase accounting. (c) Debt issued by trust and secured by assets held by the trust. March 31, December 31, 2015 TCEH Senior Secured Facilities: TCEH Floating Rate Term Loan Facilities due October 10, 2014 $ 3,809 $ 3,809 TCEH Floating Rate Letter of Credit Facility due October 10, 2014 42 42 TCEH Floating Rate Revolving Credit Facility due October 10, 2016 2,054 2,054 TCEH Floating Rate Term Loan Facilities due October 10, 2017 15,691 15,691 TCEH Floating Rate Letter of Credit Facility due October 10, 2017 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 1,833 1,833 10.25% Fixed Senior Notes due November 1, 2015, Series B 1,292 1,292 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 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 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 Other: Other 1 1 Total TCEH 31,668 31,668 EFCH (parent entity) Floating Rate Junior Subordinated Debentures, Series D due January 30, 2037 1 1 8.175% Fixed Junior Subordinated Debentures, Series E due January 30, 2037 8 8 Subtotal 9 9 March 31, 2016 December 31, 2015 EFH Corp. pre-petition debt pushed down (a) 10.875% Fixed Senior Notes due November 1, 2017 $ 16 $ 16 11.25%/12.00% Senior Toggle Notes due November 1, 2017 14 14 Subtotal — EFH Corp. debt pushed down 30 30 Total EFCH (parent entity) 39 39 Total EFCH consolidated notes, loans and other debt $ 31,707 $ 31,707 ____________ (a) Represents 50% of the amount of these EFH Corp. securities guaranteed by, and pushed down to (pushed-down debt), EFCH (parent entity) per the discussion below under "Guarantees and Push Down of EFH Corp. Pre-Petition Debt."

Membership Interests (Tables)

Membership Interests (Tables)	3 Months Ended
	Mar. 31, 2016
Stockholders' Equity Note [Abstract]
Schedule of Stockholders Equity	The following tables present the changes to membership interests for the three months ended March 31, 2016 and 2015: Three Months Ended March 31, 2016 Capital Account Accumulated Other Comprehensive Loss Total Membership Interests Balance at December 31, 2015 $ (22,957 ) $ (33 ) $ (22,990 ) Net loss (341 ) — (341 ) Balance at March 31, 2016 $ (23,298 ) $ (33 ) $ (23,331 ) Three Months Ended March 31, 2015 Capital Account Accumulated Other Comprehensive Loss Total Membership Interests Balance at December 31, 2014 $ (18,439 ) $ (35 ) $ (18,474 ) Net loss (1,337 ) — (1,337 ) Net effect of cash flow hedges — 1 1 Effect of debt push-down from EFH Corp. (a) 5 — 5 Balance at March 31, 2015 $ (19,771 ) $ (34 ) $ (19,805 ) ____________ (a) Represents the interest and income tax effects of debt pushed down from EFH Corp. (Note 10).

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2016
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: March 31, 2016 Level 1 Level 2 Level 3 (a) Reclassification (b) Total Assets: Commodity contracts $ 407 $ 51 $ 55 $ 4 $ 517 Nuclear decommissioning trust – equity securities (c) 385 — — — 385 Nuclear decommissioning trust – debt securities (c) — 332 — — 332 Subtotal $ 792 $ 383 $ 55 $ 4 $ 1,234 Assets measured at net asset value (d): Nuclear decommissioning trust - equity securities (c) 223 Total assets $ 1,457 Liabilities: Commodity contracts $ 118 $ 121 $ 30 $ 4 $ 273 Total liabilities $ 118 $ 121 $ 30 $ 4 $ 273 December 31, 2015 Level 1 Level 2 Level 3 (a) Reclassification (b) Total Assets: Commodity contracts $ 385 $ 41 $ 49 $ — $ 475 Nuclear decommissioning trust – equity securities (c) 380 219 — — 599 Nuclear decommissioning trust – debt securities (c) — 319 — — 319 Total assets $ 765 $ 579 $ 49 $ — $ 1,393 Liabilities: Commodity contracts $ 128 $ 64 $ 12 $ — $ 204 Total liabilities $ 128 $ 64 $ 12 $ — $ 204 _______________ (a) See table below for description of Level 3 assets and liabilities. (b) Fair values are determined on a contract basis, but certain contracts result in a current asset and a noncurrent liability, or vice versa, as presented in the condensed consolidated balance sheets. (c) The nuclear decommissioning trust investment is included in the investments line in the condensed consolidated balance sheets. See Note 16. (d) Certain investments measured at fair value using the net asset value per share (or its equivalent) have not been classified in the fair value hierarchy. This presentation is only allowed for periods beginning after December 15, 2015. The fair value amounts presented in this line are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the condensed consolidated balance sheets.
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, 2016 and December 31, 2015: March 31, 2016 Fair Value Contract Type (a) Assets Liabilities Total Valuation Technique Significant Unobservable Input Range (b) Electricity purchases and sales $ 1 $ (4 ) $ (3 ) Valuation Model Hourly price curve shape (d) $0 to $50/MWh Electricity spread options 13 (23 ) (10 ) Option Pricing Model Gas to power correlation (e) 15% to 45% Power volatility (f) 10% to 40% Electricity congestion revenue rights 36 (3 ) 33 Market Approach (g) Illiquid price differences between settlement points (h) $0 to $10/MWh Other (i) 5 — 5 Total $ 55 $ (30 ) $ 25 December 31, 2015 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) $15 to $35/MWh Hourly price curve shape (d) $15 to $45/MWh Electricity spread options 2 (7 ) (5 ) Option Pricing Model Gas to power correlation (e) 35% to 80% Power volatility (f) 10% to 35% Electricity congestion revenue rights 39 (4 ) 35 Market Approach (g) Illiquid price differences between settlement points (h) $0 to $10/MWh Other (i) 7 — 7 Total $ 49 $ (12 ) $ 37 ____________ (a) Electricity purchase and sales contracts include hedging positions in the ERCOT regions, as well as power contracts, the valuations of which include unobservable inputs related to the hourly shaping of the price curve. Electricity spread options 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. (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 hub and load zone 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 insufficient market data to consider the valuation liquid. (h) Based on the historical price differences between settlement points within the ERCOT hubs and load zones. (i) Other includes contracts for coal purchases, ancillary services, natural gas, power options and coal options. There were no significant transfers between Level 1 and Level 2 of the fair value hierarchy for the three months ended March 31, 2016 and 2015. 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, 2016 and 2015.
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, 2016 and 2015. Three Months Ended March 31, 2016 2015 Net asset balance at beginning of period $ 37 $ 35 Total unrealized valuation gains (losses) (5 ) 16 Purchases, issuances and settlements (a): Purchases 14 19 Issuances (12 ) (3 ) Settlements (10 ) (8 ) Transfers into Level 3 (b) — — Transfers out of Level 3 (b) 1 1 Net change (c) (12 ) 25 Net asset balance at end of period $ 25 $ 60 Unrealized valuation gains (losses) relating to instruments held at end of period $ (4 ) $ 15 ____________ (a) Settlements reflect reversals of unrealized mark-to-market valuations previously recognized in net income. Purchases and issuances reflect option premiums paid or received. (b) Includes transfers due to changes in the observability of significant inputs. Transfers in and out occur at the end of each quarter, which is when the assessments are performed. All Level 3 transfers during the periods presented are in and out of Level 2. (c) Substantially all changes in values of commodity contracts are reported in the condensed statements of consolidated loss in net gain from commodity hedging and trading activities. 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 quarter.

Commodity And Other Derivativ32

Commodity And Other Derivative Contractual Assets And Liabilities (Tables)	3 Months Ended
	Mar. 31, 2016
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 derivative contractual assets and liabilities as reported in the condensed consolidated balance sheets at March 31, 2016 and December 31, 2015 (noncurrent assets and liabilities are reported in other noncurrent assets and other noncurrent liabilities and deferred credits, respectively). Derivative asset and liability totals represent the net value of the contract, while the balance sheet totals represent the gross value of the contract. All amounts relate to commodity contracts. March 31, 2016 December 31, 2015 Derivative Assets Derivative Liabilities Total Derivative Assets Derivative Liabilities Total Current assets $ 496 $ 3 $ 499 $ 465 $ — $ 465 Noncurrent assets 18 — 18 10 — 10 Current liabilities — (261 ) (261 ) — (203 ) (203 ) Noncurrent liabilities (1 ) (11 ) (12 ) — (1 ) (1 ) Net assets (liabilities) $ 513 $ (269 ) $ 244 $ 475 $ (204 ) $ 271
Offsetting Assets and Liabilities	The following tables reconcile our derivative assets and liabilities as presented in the condensed consolidated balance sheets to net amounts after taking into consideration netting arrangements with counterparties and financial collateral: March 31, 2016 Amounts Presented in Balance Sheet Offsetting Instruments (a) Financial Collateral (Received) Pledged (b) Net Amounts Derivative assets: Commodity contracts $ 517 $ (160 ) $ (172 ) $ 185 Derivative liabilities: Commodity contracts (273 ) 160 12 (101 ) Net amounts $ 244 $ — $ (160 ) $ 84 December 31, 2015 Amounts Presented in Balance Sheet Offsetting Instruments (a) Financial Collateral (Received) Pledged (b) Net Amounts Derivative assets: Commodity contracts $ 475 $ (145 ) $ (147 ) $ 183 Derivative liabilities: Commodity contracts (204 ) 145 6 (53 ) Net amounts $ 271 $ — $ (141 ) $ 130 ____________ (a) Amounts presented 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, 2016 and December 31, 2015: March 31, 2016 December 31, 2015 Derivative type Notional Volume Unit of Measure Natural gas (a) 1,615 1,489 Million MMBtu Electricity 67,261 58,022 GWh Congestion Revenue Rights (b) 115,014 106,260 GWh Coal 8 10 Million US tons Fuel oil 32 35 Million gallons Uranium 455 75 Thousand pounds _______________ (a) Represents gross notional forward sales, purchases and options transactions, locational basis swaps and other natural gas transactions. (b) Represents gross forward purchases associated with instruments used to hedge electricity price differences between settlement points within ERCOT.

Supplementary Financial Infor33

Supplementary Financial Information (Tables)	3 Months Ended
	Mar. 31, 2016
Supplementary Financial Information [Abstract]
Schedule of Other Nonoperating Income (Expense)	Other Income and Deductions Three Months Ended March 31, 2016 2015 Other income: Mineral rights royalty income $ 1 $ 1 All other — 2 Total other income $ 1 $ 3 Other deductions: Write-off of generation equipment $ 20 $ — Impairment of favorable purchase contracts (Note 4) — 8 Impairment of emission allowances (Note 4) — 51 All other 1 1 Total other deductions $ 21 $ 60
Schedule of Restricted Cash and Cash Equivalents	Restricted Cash March 31, 2016 December 31, 2015 Current Noncurrent Assets Current Noncurrent Assets Amounts related to the DIP Facility (Note 9) $ 661 $ — $ 519 $ — Amounts related to TCEH's pre-petition Letter of Credit Facility (Note 10) — 507 — 507 Total restricted cash $ 661 $ 507 $ 519 $ 507
Schedule of Accounts, Notes, Loans and Financing Receivable	Allowance for Uncollectible Accounts Receivable Three Months Ended March 31, 2016 2015 Allowance for uncollectible accounts receivable at beginning of period $ 9 $ 15 Increase for bad debt expense 5 9 Decrease for account write-offs (7 ) (9 ) Allowance for uncollectible accounts receivable at end of period $ 7 $ 15 Trade Accounts Receivable March 31, 2016 December 31, 2015 Wholesale and retail trade accounts receivable $ 454 $ 542 Allowance for uncollectible accounts (7 ) (9 ) Trade accounts receivable — net $ 447 $ 533
Schedule of inventories by major category	Inventories by Major Category March 31, 2016 December 31, 2015 Materials and supplies $ 222 $ 226 Fuel stock 196 170 Natural gas in storage 30 32 Total inventories $ 448 $ 428
Summary of other investments	Investments March 31, 2016 December 31, 2015 Nuclear plant decommissioning trust $ 940 $ 918 Land 36 36 Miscellaneous other 8 8 Total investments $ 984 $ 962
Summary of investments in the fund	March 31, 2016 Cost (a) Unrealized gain Unrealized loss Fair market value Debt securities (b) $ 315 $ 17 $ — $ 332 Equity securities (c) 296 320 (8 ) 608 Total $ 611 $ 337 $ (8 ) $ 940 December 31, 2015 Cost (a) Unrealized gain Unrealized loss Fair market value Debt securities (b) $ 310 $ 11 $ (2 ) $ 319 Equity securities (c) 291 315 (7 ) 599 Total $ 601 $ 326 $ (9 ) $ 918 ____________ (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 3.60% and 3.68% at March 31, 2016 and December 31, 2015, respectively, and an average maturity of 8 years at both March 31, 2016 and December 31, 2015. (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, 2016 2015 Realized gains $ 1 $ — Realized losses $ (1 ) $ (1 ) Proceeds from sales of securities $ 67 $ 23 Investments in securities $ (71 ) $ (27 )
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 condensed consolidated balance sheets, for the three months ended March 31, 2016: Nuclear Plant Decommissioning Mining Land Reclamation Other Total Liability at December 31, 2015 $ 508 $ 215 $ 107 $ 830 Additions: Accretion 7 5 2 14 Incremental reclamation costs — 14 3 17 Reductions: Payments — (15 ) — (15 ) Liability at March 31, 2016 515 219 112 846 Less amounts due currently — (60 ) — (60 ) Noncurrent liability at March 31, 2016 $ 515 $ 159 $ 112 $ 786
Schedule of other noncurrent liabilities and deferred credits	The balance of other noncurrent liabilities and deferred credits consists of the following: March 31, 2016 December 31, 2015 Uncertain tax positions, including accrued interest $ 41 $ 41 Asset retirement and mining reclamation obligations 786 764 Unfavorable purchase and sales contracts 537 543 Nuclear decommissioning fund excess over asset retirement obligation (Note 15) 424 409 Other, including retirement and other employee benefits 31 23 Total other noncurrent liabilities and deferred credits $ 1,819 $ 1,780
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 2016 $ 24 2017 $ 24 2018 $ 24 2019 $ 24 2020 $ 24
Fair Value, by Balance Sheet Grouping	March 31, 2016 December 31, 2015 Debt: Carrying Amount Fair Value Carrying Amount Fair Value Borrowings under debtor-in-possession credit facility (Note 9) $ 1,425 $ 1,418 $ 1,425 $ 1,411 Long-term debt not subject to compromise, excluding capital lease obligations (Note 9) $ 46 $ 48 $ 49 $ 53
Schedule of supplemental cash flow information	Supplemental Cash Flow Information Three Months Ended March 31, 2016 2015 Cash payments related to: Interest paid (a) $ 336 $ 323 Capitalized interest (3 ) (3 ) Interest paid (net of capitalized interest) (a) $ 333 $ 320 Reorganization items (b) $ 41 $ 35 Noncash investing and financing activities: Construction expenditures (c) $ 82 $ 65 ____________ (a) This amount includes amounts paid for adequate protection. (b) Represents cash payments for legal and other consulting services. (c) Represents end-of-period accruals for ongoing construction projects.

Supplemental Guarantor Conden34

Supplemental Guarantor Condensed Financial Information (Tables)	3 Months Ended
	Mar. 31, 2016
Supplemental Guarantor Condensed Financial Information [Abstract]
Condensed Consolidating Statements of Income (Loss)	ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Condensed Consolidating Statements of Income (Loss) Three Months Ended March 31, 2016 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Operating revenues $ — $ — $ 1,049 $ — $ — $ 1,049 Fuel, purchased power costs and delivery fees — — (554 ) — — (554 ) Net gain from commodity hedging and trading activities — — 64 — — 64 Operating costs — — (219 ) — — (219 ) Depreciation and amortization — (2 ) (137 ) — — (139 ) Selling, general and administrative expenses — 2 (162 ) — — (160 ) Other income — — 1 — — 1 Other deductions — — (21 ) — — (21 ) Interest income — 15 53 — (68 ) — Interest expense and related charges (1 ) (390 ) (13 ) — 68 (336 ) Reorganization items — (21 ) (1 ) — — (22 ) Income (loss) before income taxes (1 ) (396 ) 60 — — (337 ) Income tax (expense) benefit 3 (3 ) (8 ) — 4 (4 ) Equity earnings (losses) of subsidiaries (343 ) 56 — — 287 — Net income (loss) $ (341 ) $ (343 ) $ 52 $ — $ 291 $ (341 ) Condensed Consolidating Statements of Comprehensive Income (Loss) Three Months Ended March 31, 2016 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Net income (loss) (341 ) (343 ) 52 — 291 (341 ) Other comprehensive income — — — — — — Comprehensive income (loss) $ (341 ) $ (343 ) $ 52 $ — $ 291 $ (341 ) ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Condensed Consolidating Statements of Loss Three Months Ended March 31, 2015 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Operating revenues $ — $ — $ 1,272 $ — $ — $ 1,272 Fuel, purchased power costs and delivery fees — — (613 ) — — (613 ) Net gain from commodity hedging and trading activities — — 103 — — 103 Operating costs — — (193 ) — — (193 ) Depreciation and amortization — (1 ) (214 ) — — (215 ) Selling, general and administrative expenses — — (161 ) — — (161 ) Impairment of goodwill — (700 ) — — — (700 ) Impairment of long-lived assets — — (676 ) — — (676 ) Other income — — 3 — — 3 Other deductions — — (60 ) — — (60 ) Interest income — 1 18 — (19 ) — Interest expense and related charges (1 ) (337 ) 2 — 19 (317 ) Reorganization items — (43 ) (30 ) — — (73 ) Loss before income taxes (1 ) (1,080 ) (549 ) — — (1,630 ) Income tax benefit — 112 176 — 5 293 Equity earnings (losses) of subsidiaries (1,336 ) (368 ) — — 1,704 — Net loss $ (1,337 ) $ (1,336 ) $ (373 ) $ — $ 1,709 $ (1,337 ) Condensed Consolidating Statements of Comprehensive Loss Three Months Ended March 31, 2015 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Net loss (1,337 ) (1,336 ) (373 ) — 1,709 (1,337 ) Other comprehensive income 1 1 — — (1 ) 1 Comprehensive loss $ (1,336 ) $ (1,335 ) $ (373 ) $ — $ 1,708 $ (1,336 )
Condensed Consolidating Statements of Cash Flows	ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Condensed Consolidating Statements of Cash Flows Three Months Ended March 31, 2016 (millions of dollars) Parent/ Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Cash provided by (used in) operating activities $ — $ (342 ) $ 151 $ — $ — $ (191 ) Cash flows – financing activities: Notes/advances due to affiliates 2 58 — — (60 ) — Repayments/repurchases of debt (2 ) — (3 ) — — (5 ) Cash provided by (used in) financing activities — 58 (3 ) — (60 ) (5 ) Cash flows – investing activities: Capital expenditures — — (83 ) — — (83 ) Nuclear fuel purchases — — (10 ) — — (10 ) Settlements of notes due from affiliates — — (60 ) — 60 — Changes in restricted cash — (142 ) — — — (142 ) Proceeds from sales of nuclear decommissioning trust fund securities — — 67 — — 67 Investments in nuclear decommissioning trust fund securities — — (71 ) — — (71 ) Other, net — — 3 — — 3 Cash used in investing activities — (142 ) (154 ) — 60 (236 ) Net change in cash and cash equivalents — (426 ) (6 ) — — (432 ) Cash and cash equivalents – beginning balance — 1,368 22 10 — 1,400 Cash and cash equivalents – ending balance $ — $ 942 $ 16 $ 10 $ — $ 968 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Condensed Consolidating Statements of Cash Flows Three Months Ended March 31, 2015 (millions of dollars) Parent/ Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Cash provided by (used in) operating activities $ (3 ) $ (415 ) $ 311 $ — $ — $ (107 ) Cash flows – financing activities: Notes/advances due to affiliates 4 169 — — (173 ) — Repayments/repurchases of debt (1 ) — (8 ) — — (9 ) Cash provided by (used in) financing activities 3 169 (8 ) — (173 ) (9 ) Cash flows – investing activities: Capital expenditures — — (115 ) — — (115 ) Nuclear fuel purchases — — (5 ) — — (5 ) Settlements of notes due from affiliates — — (173 ) — 173 — Changes in restricted cash — 28 — — — 28 Proceeds from sales of nuclear decommissioning trust fund securities — — 23 — — 23 Investments in nuclear decommissioning trust fund securities — — (27 ) — — (27 ) Other, net — (11 ) (3 ) — — (14 ) Cash provided by (used in) investing activities — 17 (300 ) — 173 (110 ) Net change in cash and cash equivalents — (229 ) 3 — — (226 ) Cash and cash equivalents – beginning balance — 1,826 16 1 — 1,843 Cash and cash equivalents – ending balance $ — $ 1,597 $ 19 $ 1 $ — $ 1,617 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Condensed Consolidating Balance Sheets March 31, 2016 (millions of dollars) Parent Issuer Other Non-guarantors Eliminations Consolidated ASSETS Current assets: Cash and cash equivalents $ — $ 942 $ 16 $ 10 $ — $ 968 Restricted cash — 661 — — — 661 Advance to parent — 6 — — — 6 Trade accounts receivable – net — — 447 — — 447 Accounts receivable from affiliates — 61 — — (61 ) — Inventories — — 448 — — 448 Commodity and other derivative contractual assets — — 499 — — 499 Other current assets — 2 91 — — 93 Total current assets — 1,672 1,501 10 (61 ) 3,122 Restricted cash — 507 — — — 507 Investments (33,164 ) 9,169 1,006 4 23,969 984 Property, plant and equipment – net — — 9,270 3 — 9,273 Advances to parent — 16 — — — 16 Goodwill — 152 — — — 152 Identifiable intangible assets – net — — 1,170 — — 1,170 Accumulated deferred income taxes 3 357 405 11 (776 ) — Other noncurrent assets — 3 47 — — 50 Total assets $ (33,161 ) $ 11,876 $ 13,399 $ 28 $ 23,132 $ 15,274 LIABILITIES AND MEMBERSHIP INTERESTS Borrowings under debtor-in-possession credit facility $ — $ 1,425 $ — $ — $ — $ 1,425 Long-term debt due currently 14 — 15 — — 29 Trade accounts payable — 8 343 — — 351 Trade accounts and other payables to affiliates — — 164 — (61 ) 103 Commodity and other derivative contractual liabilities — — 261 — — 261 Margin deposits related to commodity positions — — 176 — — 176 Accrued income taxes payable to parent — — 14 — — 14 Accrued taxes other than income $ — $ — $ 66 $ — $ — $ 66 Accrued interest — 122 1 — — 123 Other current liabilities — 20 208 — — 228 Total current liabilities 14 1,575 1,248 — (61 ) 2,776 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Condensed Consolidating Balance Sheets March 31, 2016 (millions of dollars) Parent Issuer Other Non-guarantors Eliminations Consolidated Accumulated deferred income taxes — — — — 213 213 Notes or other liabilities due affiliates — — — 2 (2 ) — Long-term debt, less amounts due currently 19 — 2 — — 21 Liabilities subject to compromise 44 43,468 31,601 — (41,337 ) 33,776 Other noncurrent liabilities and deferred credits — (3 ) 1,822 — — 1,819 Total liabilities 77 45,040 34,673 2 (41,187 ) 38,605 Total membership interests (33,238 ) (33,164 ) (21,274 ) 26 64,319 (23,331 ) Total liabilities and membership interests $ (33,161 ) $ 11,876 $ 13,399 $ 28 $ 23,132 $ 15,274
Condensed Consolidating Balance Sheet	ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Condensed Consolidating Balance Sheets March 31, 2016 (millions of dollars) Parent Issuer Other Non-guarantors Eliminations Consolidated ASSETS Current assets: Cash and cash equivalents $ — $ 942 $ 16 $ 10 $ — $ 968 Restricted cash — 661 — — — 661 Advance to parent — 6 — — — 6 Trade accounts receivable – net — — 447 — — 447 Accounts receivable from affiliates — 61 — — (61 ) — Inventories — — 448 — — 448 Commodity and other derivative contractual assets — — 499 — — 499 Other current assets — 2 91 — — 93 Total current assets — 1,672 1,501 10 (61 ) 3,122 Restricted cash — 507 — — — 507 Investments (33,164 ) 9,169 1,006 4 23,969 984 Property, plant and equipment – net — — 9,270 3 — 9,273 Advances to parent — 16 — — — 16 Goodwill — 152 — — — 152 Identifiable intangible assets – net — — 1,170 — — 1,170 Accumulated deferred income taxes 3 357 405 11 (776 ) — Other noncurrent assets — 3 47 — — 50 Total assets $ (33,161 ) $ 11,876 $ 13,399 $ 28 $ 23,132 $ 15,274 LIABILITIES AND MEMBERSHIP INTERESTS Borrowings under debtor-in-possession credit facility $ — $ 1,425 $ — $ — $ — $ 1,425 Long-term debt due currently 14 — 15 — — 29 Trade accounts payable — 8 343 — — 351 Trade accounts and other payables to affiliates — — 164 — (61 ) 103 Commodity and other derivative contractual liabilities — — 261 — — 261 Margin deposits related to commodity positions — — 176 — — 176 Accrued income taxes payable to parent — — 14 — — 14 Accrued taxes other than income $ — $ — $ 66 $ — $ — $ 66 Accrued interest — 122 1 — — 123 Other current liabilities — 20 208 — — 228 Total current liabilities 14 1,575 1,248 — (61 ) 2,776 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Condensed Consolidating Balance Sheets March 31, 2016 (millions of dollars) Parent Issuer Other Non-guarantors Eliminations Consolidated Accumulated deferred income taxes — — — — 213 213 Notes or other liabilities due affiliates — — — 2 (2 ) — Long-term debt, less amounts due currently 19 — 2 — — 21 Liabilities subject to compromise 44 43,468 31,601 — (41,337 ) 33,776 Other noncurrent liabilities and deferred credits — (3 ) 1,822 — — 1,819 Total liabilities 77 45,040 34,673 2 (41,187 ) 38,605 Total membership interests (33,238 ) (33,164 ) (21,274 ) 26 64,319 (23,331 ) Total liabilities and membership interests $ (33,161 ) $ 11,876 $ 13,399 $ 28 $ 23,132 $ 15,274 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Condensed Consolidating Balance Sheets December 31, 2015 (millions of dollars) Parent Issuer Other Non-guarantors Eliminations Consolidated ASSETS Current assets: Cash and cash equivalents $ — $ 1,368 $ 22 $ 10 $ — $ 1,400 Restricted cash — 519 — — — 519 Advances to parent — 6 — — — 6 Trade accounts receivable – net — — 533 — — 533 Accounts receivable from affiliates — 92 — — (92 ) — Inventories — — 428 — — 428 Commodity and other derivative contractual assets — — 465 — — 465 Other current assets — 3 68 — — 71 Total current assets — 1,988 1,516 10 (92 ) 3,422 Restricted cash — 507 — — — 507 Investments (32,818 ) 9,095 983 5 23,697 962 Property, plant and equipment – net — 12 9,334 3 — 9,349 Advances to parent — 18 — — — 18 Goodwill — 152 — — — 152 Identifiable intangible assets – net — 31 1,148 — — 1,179 Accumulated deferred income taxes — 438 393 11 (842 ) — Other noncurrent assets, principally unamortized debt amendment and issuance costs — 1 38 — — 39 Total assets $ (32,818 ) $ 12,242 $ 13,412 $ 29 $ 22,763 $ 15,628 LIABILITIES AND MEMBERSHIP INTERESTS Current liabilities: Borrowings under credit and other facilities $ — $ 1,425 $ — $ — $ — $ 1,425 Long-term debt due currently 15 — 16 — — 31 Trade accounts payable — 21 373 — — 394 Trade accounts and other payables to affiliates — — 211 — (92 ) 119 Commodity and other derivative contractual liabilities — — 203 — — 203 Margin deposits related to commodity positions — — 152 — — 152 Accrued income taxes payable to parent — — 10 — — 10 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Condensed Consolidating Balance Sheets December 31, 2015 (millions of dollars) Parent Issuer Other Non-guarantors Eliminations Consolidated Accrued taxes other than income $ — $ — $ 98 $ — $ — $ 98 Accrued interest — 119 1 — — 120 Other current liabilities — 32 242 — — 274 Total current liabilities 15 1,597 1,306 — (92 ) 2,826 Accumulated deferred income taxes — — — — 213 213 Notes or other liabilities due affiliates — — — 2 (2 ) — Long-term debt, less amounts due currently 20 — 3 — — 23 Liabilities subject to compromise 44 43,468 31,601 — (41,337 ) 33,776 Other noncurrent liabilities and deferred credits — (4 ) 1,784 — — 1,780 Total liabilities 79 45,061 34,694 2 (41,218 ) 38,618 Total membership interests (32,897 ) (32,819 ) (21,282 ) 27 63,981 (22,990 ) Total liabilities and membership interests $ (32,818 ) $ 12,242 $ 13,412 $ 29 $ 22,763 $ 15,628

Chapter 11 Cases (Details)

Chapter 11 Cases (Details) $ in Millions	May. 09, 2016	Sep. 22, 2015USD ($)
Subsequent Event [Member]
Schedule of Reorganization Costs [Line Items]
Bankruptcy Claims, Number of Claims under Review by Management	41,300
Bankruptcy Claims Number Of Claims Under Review By Management Related To Asbestos	30,900
Bankruptcy Claims, Number Of Claims Settled, Withdrawn or Expunged By Bankruptcy Court	5,700
Rights Offering Participants [Member] | Backstop Purchasers [Member]
Schedule of Reorganization Costs [Line Items]
Rights Offering, Backstop Agreement		$ 5,087

Purchase of La Frontera Holdi36

Purchase of La Frontera Holdings, LLC (Details) - Texas Competitive Electric Holdings Company LLC [Member] - La Frontera Holdings, LLC [Member] - Subsequent Event [Member] $ in Millions	1 Months Ended
	Apr. 30, 2016USD ($)	Apr. 04, 2016Megawatt-hour
La Frontera Ventures, LLC [Member]
Electricity Generation Facility Capacity | Megawatt-hour		3,000
Purchase And Sale Agreement, Aggregate Purchase Price	$ 1,313
Purchase And Sale Agreement, Repayment Of Existing Project Financing At Closing	950
Purchase And Sale Agreement, Cash And Net Working Capital	240
Forney Power Plant [Member] | La Frontera Ventures, LLC [Member]
Electricity Generation Facility Capacity | Megawatt-hour		1,912
Lamar Power Plant [Member] | La Frontera Ventures, LLC [Member]
Electricity Generation Facility Capacity | Megawatt-hour		1,076
Senior Secured Super-Priority Revolving Credit Facility [Member] | Debtor-In-Possession Facility [Member]
Proceeds from Lines of Credit	$ 1,100

Goodwill And Identifiable Int37

Goodwill And Identifiable Intangible Assets (Narrative) (Details) - USD ($)		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
Goodwill [Line Items]
Business Acquisition, Goodwill, Expected Tax Deductible Amount		$ 0
Impairment of goodwill (Note 4)		0	$ 700,000,000
Amortization of Intangible Assets	[1]	21,000,000	23,000,000
Environmental allowances and credits [Member]
Goodwill [Line Items]
Impairment of Intangible Assets (Excluding Goodwill)		0	51,000,000
Favorable purchase and sales contracts [Member]
Goodwill [Line Items]
Impairment of Intangible Assets (Excluding Goodwill)		0	8,000,000
Depreciation and amortization [Member]
Goodwill [Line Items]
Amortization of Intangible Assets		$ 20,000,000	$ 18,000,000
[1]	Amounts recorded in depreciation and amortization totaled $20 million and $18 million for the three months ended March 31, 2016 and 2015, respectively.

Goodwill And Identifiable Int38

Goodwill And Identifiable Intangible Assets (Goodwill) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Goodwill [Roll Forward]
Goodwill before impairment charges			$ 18,322
Accumulated noncash impairment charges			(18,170)
Balance at March 31, 2016 (a)	$ 152		$ 152
Additional noncash impairment charges in 2016	$ 0	$ (700)

Goodwill And Identifiable Int39

Goodwill And Identifiable Intangible Assets (Identifiable Intangible Assets Reported in the Balance Sheet) (Details) - USD ($) $ in Millions		Mar. 31, 2016	Dec. 31, 2015
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross Carrying Amount		$ 918	$ 920
Accumulated Amortization		708	701
Total intangible assets subject to amortization, net		210	219
Total identifiable intangible assets		1,170	1,179
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		5	5
Retail customer relationship [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross Carrying Amount		463	463
Accumulated Amortization		445	442
Total intangible assets subject to amortization, net		18	21
Software and other computer-related assets [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross Carrying Amount		397	385
Accumulated Amortization		239	224
Total intangible assets subject to amortization, net		158	161
Other Identifiable Intangible Assets [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross Carrying Amount	[1]	58	72
Accumulated Amortization	[1]	24	35
Total intangible assets subject to amortization, net	[1]	$ 34	$ 37
[1]	Includes favorable purchase and sales contracts, environmental allowances and credits and mining development costs. See discussion below regarding impairment charges recorded in the three months ended March 31, 2015 related to other identifiable intangible assets.

Goodwill And Identifiable Int40

Goodwill And Identifiable Intangible Assets (Amortization Expense Related to Intangible Assets (including income statement line item)) (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
Finite-Lived Intangible Assets [Line Items]
Amortization expense	[1]	$ 21	$ 23
Depreciation and amortization [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization expense		20	18
Retail customer relationship [Member] | Depreciation and amortization [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization expense		3	4
Software and other computer-related assets [Member] | Depreciation and amortization [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization expense		15	14
Other Identifiable Intangible Assets [Member] | Operating Revenues, Fuel, Purchased Power Costs And Delivery Fees, Depreciation And Amortization [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization expense		$ 3	$ 5
[1]	Amounts recorded in depreciation and amortization totaled $20 million and $18 million for the three months ended March 31, 2016 and 2015, respectively.

Goodwill And Identifiable Int41

Goodwill And Identifiable Intangible Assets (Estimated Amortization of Intangible Assets) (Details) $ in Millions	Mar. 31, 2016USD ($)
Future Amortization Expense
2,016	$ 84
2,017	61
2,018	38
2,019	18
2,020	$ 10

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Income Tax Contingency [Line Items]
Loss before income taxes	$ (337)	$ (1,630)
Income tax (expense) benefit	$ (4)	$ 293
Effective tax rate	(1.20%)	18.00%
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent	35.00%	35.00%

Impairment of Long-Lived Asse43

Impairment of Long-Lived Assets (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of Long-Lived Assets Held-for-use	$ 0	$ 676
Big Brown Steam Electric Station [Member]
Impaired Long-Lived Assets Held and Used [Line Items]
Impairment of Long-Lived Assets Held-for-use	$ 676

Interest Expense and Related 44

Interest Expense and Related Charges (Interest Expense and Related Charges) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Interest Expense and Related Charges [Line Items]
Interest paid/accrued on debtor-in-possession financing	$ 16	$ 15
Adequate protection amounts paid/accrued	322	302
Interest paid/accrued on pre-petition debt	1	3
Capitalized interest	(3)	(3)
Total interest expense and related charges	336	317
Liabilities Subject To Compromise, Debt	31,707		$ 31,707
Liabilities Subject To Compromise, Liability Under Terminated Agreements, Net	1,243		1,243
Adequate Protection Interest Paid-Accrued, Amount Excluded Related To Terminated Natural Gas Hedging Positions And Interest Rate Swaps	15	14
Contractual Interest on Debt Classified as LSTC	531	515
Adequate Protection Paid/Accrued	307	288
Contractual Interest on Debt Classified as LSTC Not Paid/Accrued	224	227
Energy Future Competitive Holdings Company [Member]
Interest Expense and Related Charges [Line Items]
Contractual Interest on Debt Classified as LSTC	0	2
Adequate Protection Paid/Accrued	0	0
Contractual Interest on Debt Classified as LSTC Not Paid/Accrued	0	2
Texas Competitive Electric Holdings Company LLC
Interest Expense and Related Charges [Line Items]
Liabilities Subject To Compromise, Debt	31,668		31,668
Contractual Interest on Debt Classified as LSTC	531	513
Adequate Protection Paid/Accrued	307	288
Contractual Interest on Debt Classified as LSTC Not Paid/Accrued	224	$ 225
Line of Credit [Member] | Texas Competitive Electric Holdings Company LLC
Interest Expense and Related Charges [Line Items]
Liabilities Subject To Compromise, Debt	22,616
11.5% Fixed Senior Secured Notes due October 1, 2020 [Member] | Secured Debt [Member] | Texas Competitive Electric Holdings Company LLC
Interest Expense and Related Charges [Line Items]
Liabilities Subject To Compromise, Debt	$ 1,750		$ 1,750
Adequate Protection Interest Expense [Member]
Interest Expense and Related Charges [Line Items]
Adequate Protection Paid Or Accrued, Weighted Average Interest Rate	4.92%
Adequate Protection Paid Or Accrued, Basis Spread on Variable Rate	4.50%

Reorganization Items (Details)

Reorganization Items (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Reorganization Items [Abstract]
Expenses related to legal advisory and representation services	$ 13	$ 26
Expenses related to other professional consulting and advisory services	8	15
Contract claims adjustments	1	32
Total reorganization items	$ 22	$ 73

Debtor-In-Possession Borrowin46

Debtor-In-Possession Borrowing Facility and Long-Term Debt Not Subject to Compromise - TCEH Debtor-In-Possession Facility (Details)		1 Months Ended	3 Months Ended
		Apr. 30, 2016USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Line of Credit Facility [Line Items]
Consolidated Superpriority Secured Net Debt to Consolidated EBITDA Covenant Threshold			3.50
Texas Competitive Electric Holdings Company LLC | Debtor-In-Possession Facility [Member]
Line of Credit Facility [Line Items]
Facility Limit			$ 3,375,000,000
Available Cash Borrowing Capacity			1,950,000,000
Available Letter of Credit Capacity			$ 139,000,000
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum			0.75%
Debt Instrument, Basis Spread on Variable Rate			3.00%
Debtor-in-Possession Financing, Interest Rate on Borrowings Outstanding			3.75%
Texas Competitive Electric Holdings Company LLC | Debtor-In-Possession Facility [Member] | Senior Secured Super-Priority Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Facility Limit	[1]		$ 1,950,000,000
Available Cash Borrowing Capacity	[1]		1,950,000,000
Available Letter of Credit Capacity	[1]		0
Borrowings under debtor-in-possession credit facility (Note 9)			0
Debtor-In-Possession Financing, Maximum Borrowings Allowed Without Consent Or Bankruptcy Court Order			1,650,000,000
Texas Competitive Electric Holdings Company LLC | Debtor-In-Possession Facility [Member] | Senior Secured Super-Priority Term Loan [Member]
Line of Credit Facility [Line Items]
Facility Limit	[2]		1,425,000,000
Available Cash Borrowing Capacity	[2]		0
Available Letter of Credit Capacity	[2]		139,000,000
Borrowings under debtor-in-possession credit facility (Note 9)			1,425,000,000	$ 1,425,000,000
Debtor-In-Possession Financing, Amount Arranged, Maximum Letter of Credit Capacity			800,000,000
Debtor-In-Possession Financing, Collateral Account, Total Amount Held To Support Letters Of Credit			800,000,000
Texas Competitive Electric Holdings Company LLC | Debtor-In-Possession Facility [Member] | Senior Secured Super-Priority Term Loan [Member] | Cash and Cash Equivalents [Member]
Line of Credit Facility [Line Items]
Debtor-In-Possession Financing, Collateral Account, Total Amount Held To Support Letters Of Credit			139,000,000
Texas Competitive Electric Holdings Company LLC | Debtor-In-Possession Facility [Member] | Senior Secured Super-Priority Term Loan [Member] | Restricted Cash [Member]
Line of Credit Facility [Line Items]
Debtor-In-Possession Financing, Collateral Account, Total Amount Held To Support Letters Of Credit			661,000,000
Railroad Commission of Texas [Member] | Texas Competitive Electric Holdings Company LLC
Line of Credit Facility [Line Items]
Collateral Bond, Securing Mining Land Reclamation Obligations, Secured By First Lien Interest In Assets			$ 1,100,000,000
Subsequent Event [Member] | La Frontera Holdings, LLC [Member] | Texas Competitive Electric Holdings Company LLC | Debtor-In-Possession Facility [Member] | Senior Secured Super-Priority Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Proceeds from Lines of Credit		$ 1,100,000,000
Repayments of Lines of Credit		$ 200,000,000
[1]	Facility used for general corporate purposes. No amounts were borrowed at March 31, 2016. Pursuant to an order of the Bankruptcy Court, the TCEH Debtors may not have more than $1.650 billion of DIP Revolving Credit Facility cash borrowings outstanding without written consent of the TCEH committee of unsecured creditors and the ad hoc group of TCEH unsecured noteholders or further order of the Bankruptcy Court.
[2]	Facility used for general corporate purposes, including but not limited to, $800 million for issuing letters of credit.

Debtor-In-Possession Borrowin47

Debtor-In-Possession Borrowing Facility and Long-Term Debt Not Subject to Compromise - Long-Term Debt Not Subject to Compromise (Details) - USD ($) $ in Millions		Mar. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Long-term Debt and Capital Lease Obligations, Including Current Maturities		$ 50	$ 54
Less amounts due currently		(29)	(31)
Long-term debt, less amounts due currently (Note 9)		21	23
Energy Future Competitive Holdings Company [Member]
Debt Instrument [Line Items]
Long-term Debt and Capital Lease Obligations, Including Current Maturities		34	35
Unamortized fair value discount (b)	[1]	$ (2)	(2)
Energy Future Competitive Holdings Company [Member] | Notes Payable to Banks [Member] | Fixed 9.58% Notes due in annual installments through December 4, 2019 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		9.58%
Long-term Debt and Capital Lease Obligations, Including Current Maturities	[2]	$ 13	13
Energy Future Competitive Holdings Company [Member] | Notes Payable to Banks [Member] | Fixed 8.254% Notes due in quarterly installments through December 31, 2021 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		8.254%
Long-term Debt and Capital Lease Obligations, Including Current Maturities	[2]	$ 23	24
Texas Competitive Electric Holdings Company LLC
Debt Instrument [Line Items]
Long-term Debt and Capital Lease Obligations, Including Current Maturities		16	19
Capital lease obligations		4	5
Other		2	2
Unamortized discount		$ 0	(1)
Texas Competitive Electric Holdings Company LLC | Fixed Secured Facility Bonds [Member] | Fixed 7.48% Secured Facility Bonds With Amortizing Payments Through January 2017 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		7.48%
Long-term Debt and Capital Lease Obligations, Including Current Maturities	[3]	$ 10	$ 13
Texas Competitive Electric Holdings Company LLC | Fixed Secured Facility Bonds [Member] | Fixed 7.46% Secured Facility Bonds with amortizing payments through January 2015 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		7.46%
[1]	Approved by the Bankruptcy Court for repayment.
[2]	Amount represents unamortized fair value adjustments recorded under purchase accounting.
[3]	Debt issued by trust and secured by assets held by the trust.

Liabilities Subject To Compro48

Liabilities Subject To Compromise (Liabilities Subject To Compromise) (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Liabilities Subject to Compromise [Abstract]
Notes, loans and other debt per the following table	$ 31,707	$ 31,707
Accrued interest on notes, loans and other debt	648	648
Net liability under terminated TCEH interest rate swap and natural gas hedging agreements (Note 14)	1,243	1,243
Trade accounts payable and other expected allowed claims	177	177
Advances and other payables to affiliates	1	1
Total liabilities subject to compromise	$ 33,776	$ 33,776

Liabilities Subject To Compro49

Liabilities Subject To Compromise (Schedule of Long-term Debt Instruments) (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 31,707	$ 31,707
Notes, loans and other debt		29	31
Consolidated Debt [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		31,707	31,707
Texas Competitive Electric Holdings Company LLC
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		31,668	31,668
Capital lease obligations		4	5
Other		2	2
Unamortized discount		0	(1)
Texas Competitive Electric Holdings Company LLC | Line of Credit [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		22,616
Texas Competitive Electric Holdings Company LLC | Line of Credit [Member] | TCEH Term Loan Facilities maturing October 10, 2014 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		3,809	3,809
Texas Competitive Electric Holdings Company LLC | Line of Credit [Member] | TCEH Term Loan Facilities maturing October 10, 2017 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		15,691	15,691
Texas Competitive Electric Holdings Company LLC | Letter of Credit [Member] | Letter of Credit Facility maturing October 10, 2014 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		42	42
Texas Competitive Electric Holdings Company LLC | Letter of Credit [Member] | TCEH Letter of Credit Facility maturing October 10, 2017 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		1,020	1,020
Texas Competitive Electric Holdings Company LLC | Revolving Credit Facility [Member] | Revolving Credit Facility maturing October 2016 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		2,054	2,054
Texas Competitive Electric Holdings Company LLC | Senior Secured Debt [Member] | 11.5% Fixed Senior Secured Notes due October 1, 2020 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 1,750	1,750
Stated interest rate (as a percent)		11.50%
Texas Competitive Electric Holdings Company LLC | Senior Secured Debt [Member] | 15% Fixed Senior Secured Second Lien Notes due April 1, 2021 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 336	336
Stated interest rate (as a percent)		15.00%
Texas Competitive Electric Holdings Company LLC | Senior Secured Debt [Member] | 15% Fixed Senior Secured Second Lien Notes due April 1, 2021, Series B [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 1,235	1,235
Stated interest rate (as a percent)		15.00%
Texas Competitive Electric Holdings Company LLC | Senior Notes [Member] | 10.25% Fixed Senior Notes due November 1, 2015 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 1,833	1,833
Stated interest rate (as a percent)		10.25%
Texas Competitive Electric Holdings Company LLC | Senior Notes [Member] | 10.25% Fixed Senior Notes due November 1, 2015, Series B [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 1,292	1,292
Stated interest rate (as a percent)		10.25%
Texas Competitive Electric Holdings Company LLC | Senior Notes [Member] | 10.50 / 11.25% Senior Toggle Notes due November 1, 2016 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 1,749	1,749
Texas Competitive Electric Holdings Company LLC | Other Debt Obligations [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		1	1
Energy Future Competitive Holdings Company [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		9	9
Notes, loans and other debt		14	15
Energy Future Competitive Holdings Company [Member] | Junior Subordinated Debt [Member] | Floating Rate Junior Subordinated Debentures, Series D due January 30, 2037 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		1	1
Energy Future Competitive Holdings Company [Member] | Junior Subordinated Debt [Member] | 8.175% Fixed Junior Subordinated Debentures, Series E due January 30, 2037 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 8	8
Stated interest rate (as a percent)		8.18%
Energy Future Holdings Corp. [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 39	39
Debt Instrument, Percentage of Securities Guaranteed by and Push Down Debt		50.00%
Energy Future Holdings Corp. [Member] | Senior Notes [Member] | 10.875% Fixed Senior Notes and 11.25%/12.00% Senior Toggle Notes [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	[1]	$ 30	30
Energy Future Holdings Corp. [Member] | Senior Notes [Member] | 10.875% Fixed Senior Notes due November 1, 2017 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	[1]	$ 16	16
Stated interest rate (as a percent)		10.88%
Energy Future Holdings Corp. [Member] | Senior Notes [Member] | 11.25 / 12.00% Senior Toggle Notes due November 1, 2017 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	[1]	$ 14	14
Brazos River Authority [Member] | Texas Competitive Electric Holdings Company LLC | US States and Political Subdivisions Debt Securities [Member] | 5.40% Fixed Series 1994A due May 1, 2029 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 39	39
Stated interest rate (as a percent)		5.40%
Brazos River Authority [Member] | Texas Competitive Electric Holdings Company LLC | US States and Political Subdivisions Debt Securities [Member] | 7.70% Fixed Series 1999A due April 1, 2033 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 111	111
Stated interest rate (as a percent)		7.70%
Brazos River Authority [Member] | Texas Competitive Electric Holdings Company LLC | US States and Political Subdivisions Debt Securities [Member] | 7.70% Fixed Series 1999C due March 1, 2032 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 50	50
Stated interest rate (as a percent)		7.70%
Brazos River Authority [Member] | Texas Competitive Electric Holdings Company LLC | US States and Political Subdivisions Debt Securities [Member] | 8.25% Fixed Series 2001A due October 1, 2030 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 71	71
Stated interest rate (as a percent)		8.25%
Brazos River Authority [Member] | Texas Competitive Electric Holdings Company LLC | US States and Political Subdivisions Debt Securities [Member] | 8.25% Fixed Series 2001D-1 due May 1, 2033 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 171	171
Stated interest rate (as a percent)		8.25%
Brazos River Authority [Member] | Texas Competitive Electric Holdings Company LLC | US States and Political Subdivisions Debt Securities [Member] | 6.30% Fixed Series 2003B due July 1, 2032 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 39	39
Stated interest rate (as a percent)		6.30%
Brazos River Authority [Member] | Texas Competitive Electric Holdings Company LLC | US States and Political Subdivisions Debt Securities [Member] | 6.75% Fixed Series 2003C due October 1, 2038 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 52	52
Stated interest rate (as a percent)		6.75%
Brazos River Authority [Member] | Texas Competitive Electric Holdings Company LLC | US States and Political Subdivisions Debt Securities [Member] | 5.40% Fixed Series 2003D due October 1, 2029, remarketing date October 1, 2014 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 31	31
Stated interest rate (as a percent)		5.40%
Brazos River Authority [Member] | Texas Competitive Electric Holdings Company LLC | US States and Political Subdivisions Debt Securities [Member] | 5.00% Fixed Series 2006 due March 1, 2041 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 100	100
Stated interest rate (as a percent)		5.00%
Sabine River Authority of Texas [Member] | Texas Competitive Electric Holdings Company LLC | US States and Political Subdivisions Debt Securities [Member] | 6.45% Fixed Series 2000A due June 1, 2021 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 51	51
Stated interest rate (as a percent)		6.45%
Sabine River Authority of Texas [Member] | Texas Competitive Electric Holdings Company LLC | US States and Political Subdivisions Debt Securities [Member] | 5.20% Fixed Series 2001C due May 1, 2028 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 70	70
Stated interest rate (as a percent)		5.20%
Sabine River Authority of Texas [Member] | Texas Competitive Electric Holdings Company LLC | US States and Political Subdivisions Debt Securities [Member] | 5.80% Fixed Series 2003A due July 1, 2022 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 12	12
Stated interest rate (as a percent)		5.80%
Sabine River Authority of Texas [Member] | Texas Competitive Electric Holdings Company LLC | US States and Political Subdivisions Debt Securities [Member] | 6.15% Fixed Series 2003B due August 1, 2022 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 45	45
Stated interest rate (as a percent)		6.15%
Trinity River Authority of Texas [Member] | Texas Competitive Electric Holdings Company LLC | US States and Political Subdivisions Debt Securities [Member] | 6.25% Fixed Series 200A due May 1, 2028 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 14	$ 14
Stated interest rate (as a percent)		6.25%
Minimum [Member] | Texas Competitive Electric Holdings Company LLC | 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%
Minimum [Member] | Energy Future Holdings Corp. [Member] | 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%
Maximum [Member] | Texas Competitive Electric Holdings Company LLC | 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%
Maximum [Member] | Energy Future Holdings Corp. [Member] | 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%
[1]	Represents 50% of the amount of these EFH Corp. securities guaranteed by, and pushed down to (pushed-down debt), EFCH (parent entity) per the discussion below under "Guarantees and Push Down of EFH Corp. Pre-Petition Debt."

Liabilities Subject To Compro50

Liabilities Subject To Compromise (Guarantees and Push Down of EFH Corp. Pre-Petition Debt) (Details) - USD ($)	3 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	$ 31,707,000,000	$ 31,707,000,000
Payment of Interest on Pushed-down Debt Accounted for as a Contribution of Capital (net of tax)	0
Push Down Debt [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		30,000,000
Energy Future Competitive Holdings Company [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	9,000,000	$ 9,000,000
Energy Future Competitive Holdings Company [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Debt Instrument Principal Amount Guarantee Obligations Of Subsidiaries	60,000,000
Subject to Push Down [Member] | Financial guarantee [Member] | Energy Future Competitive Holdings Company [Member] | Senior Notes [Member] | 10.875% Fixed Senior Notes due November 1, 2017 [Member]
Debt Instrument [Line Items]
Debt Instrument Principal Amount Guarantee Obligations Of Subsidiaries	33,000,000
Subject to Push Down [Member] | Financial guarantee [Member] | Energy Future Competitive Holdings Company [Member] | Senior Notes [Member] | 11.25 / 12.00% Senior Toggle Notes due November 1, 2017 [Member]
Debt Instrument [Line Items]
Debt Instrument Principal Amount Guarantee Obligations Of Subsidiaries	$ 27,000,000
Energy Future Holdings Corp. [Member] | Push Down Debt [Member]
Debt Instrument [Line Items]
Debt Instrument, Percentage of principal plus unamortized premium of Parent Merger-related debt guaranteed by subsidiary	50.00%	50.00%

Liabilities Subject To Compro51

Liabilities Subject To Compromise (Information Regarding Significant Pre-Petition Debt) (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Noncurrent Assets	$ 507	$ 507
Texas Competitive Electric Holdings Company LLC | Letter of Credit [Member] | Letter of Credit Facility maturing October 10, 2017 [Member]
Debt Instrument [Line Items]
Noncurrent Assets	$ 507

Liabilities Subject To Compro52

Liabilities Subject To Compromise (Senior Notes and Other) (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	$ 31,707	$ 31,707
Texas Competitive Electric Holdings Company LLC
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	31,668	31,668
Texas Competitive Electric Holdings Company LLC | Line of Credit [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	22,616
Texas Competitive Electric Holdings Company LLC | Line of Credit [Member] | TCEH Term Loan Facilities maturing October 10, 2014 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	3,809	3,809
Texas Competitive Electric Holdings Company LLC | Line of Credit [Member] | Term Loan Facilities maturing October 10, 2017 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	15,691	15,691
Texas Competitive Electric Holdings Company LLC | Letter of Credit [Member] | Letter of Credit Facility maturing October 10, 2017 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	1,020	1,020
Texas Competitive Electric Holdings Company LLC | Letter of Credit [Member] | Letter of Credit Facility maturing October 10, 2014 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	42	42
Texas Competitive Electric Holdings Company LLC | Senior Secured Debt [Member] | 11.5% Fixed Senior Secured Notes due October 1, 2020 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	$ 1,750	$ 1,750

Commitments And Contingencies (

Commitments And Contingencies (Narrative) (Details) - USD ($)	1 Months Ended		3 Months Ended
	Aug. 31, 2015	Feb. 29, 2012	Mar. 31, 2016
Commitments and Contingencies [Line Items]
EPA Rule Addressing Greenhouse Gas Emissions From Existing Electricity Generation Plants, State-Specific Emission Rate Goals, Percent Reduction From 2012 Levels To 2030 Levels	30.00%
CSAPR [Member]
Commitments and Contingencies [Line Items]
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%
EPA Versus Luminant and Big Brown Power Company (Big Brown and Martin Lake Generation Facilities) [Member] | Pending Litigation [Member] | Minimum [Member]
Commitments and Contingencies [Line Items]
Loss Contingency Damages Sought Value Per Day			$ 32,500
EPA Versus Luminant and Big Brown Power Company (Big Brown and Martin Lake Generation Facilities) [Member] | Pending Litigation [Member] | Maximum [Member]
Commitments and Contingencies [Line Items]
Loss Contingency Damages Sought Value Per Day			37,500
Texas Competitive Electric Holdings Company LLC | Financial Standby Letter of Credit [Member]
Commitments and Contingencies [Line Items]
Letters of Credit			661,000,000
Texas Competitive Electric Holdings Company LLC | Financial Standby Letter of Credit [Member] | Support risk management and trading margin requirements, including over-the-counter hedging transactions and collateral postings with ERCOT [Member]
Commitments and Contingencies [Line Items]
Letters of Credit			377,000,000
Texas Competitive Electric Holdings Company LLC | Financial Standby Letter of Credit [Member] | Support Executory Contracts And Insurance Agreements [Member]
Commitments and Contingencies [Line Items]
Letters of Credit			66,000,000
Texas Competitive Electric Holdings Company LLC | Financial Standby Letter of Credit [Member] | Support Retail Electric Provider's financial requirements with the PUCT [Member]
Commitments and Contingencies [Line Items]
Letters of Credit			55,000,000
Texas Competitive Electric Holdings Company LLC | Financial Standby Letter of Credit [Member] | Miscellaneous credit support requirements [Member]
Commitments and Contingencies [Line Items]
Letters of Credit			163,000,000
Texas Competitive Electric Holdings Company LLC | Financial Standby Letter of Credit [Member] | Purchase And Sale Agreement With La Holdings LLC [Member]
Commitments and Contingencies [Line Items]
Letters of Credit			$ 131,000,000

Membership Interests (Equity) (

Membership Interests (Equity) (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning Balance		$ (22,990)	$ (18,474)
Net loss		(341)	(1,337)
Net effect of cash flow hedges		0	1
Effect of debt push-down from EFH Corp. (a)	[1]		5
Ending Balance		(23,331)	(19,805)
Membership Interests [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning Balance		(22,957)	(18,439)
Net loss		(341)	(1,337)
Net effect of cash flow hedges			0
Effect of debt push-down from EFH Corp. (a)	[1]		5
Ending Balance		(23,298)	(19,771)
Accumulated Other Comprehensive Income (Loss) [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning Balance		(33)	(35)
Net loss		0	0
Net effect of cash flow hedges			1
Effect of debt push-down from EFH Corp. (a)	[1]		0
Ending Balance		$ (33)	$ (34)
[1]	Represents the interest and income tax effects of debt pushed down from EFH Corp. (Note 10).

Fair Value Measurements (Schedu

Fair Value Measurements (Schedule of Assets and Liabilities Measured at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions		Mar. 31, 2016	Dec. 31, 2015
Assets:
Nuclear decommissioning trust		$ 940	$ 918
Assets, Fair Value Disclosure, Including Assets Measured At Net Asset Value		1,457
Commodity contracts [Member]
Assets:
Gross commodity contracts		517	475
Liabilities:
Gross commodity contracts		273	204
Fair Value, Measurements, Recurring [Member]
Assets:
Commodity contracts reclassification	[1]	4
Liabilities:
Commodity contracts reclassification	[1]	4
Fair Value, Measurements, Recurring [Member] | Commodity contracts [Member]
Assets:
Commodity contracts reclassification	[1]	4
Liabilities:
Commodity contracts reclassification	[1]	4
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Assets:
Total assets		792	765
Liabilities:
Total liabilities		118	128
Fair Value, Measurements, Recurring [Member] | Level 1 [Member] | Commodity contracts [Member]
Assets:
Gross commodity contracts		407	385
Liabilities:
Gross commodity contracts		118	128
Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Assets:
Total assets		383	579
Liabilities:
Total liabilities		121	64
Fair Value, Measurements, Recurring [Member] | Level 2 [Member] | Commodity contracts [Member]
Assets:
Gross commodity contracts		51	41
Liabilities:
Gross commodity contracts		121	64
Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Assets:
Total assets	[2]	55	49
Liabilities:
Total liabilities	[2]	30	12
Fair Value, Measurements, Recurring [Member] | Level 3 [Member] | Commodity contracts [Member]
Assets:
Gross commodity contracts	[2]	55	49
Liabilities:
Gross commodity contracts	[2]	30	12
Total [Member] | Fair Value, Measurements, Recurring [Member]
Assets:
Total assets		1,234	1,393
Liabilities:
Total liabilities		273	204
Total [Member] | Fair Value, Measurements, Recurring [Member] | Commodity contracts [Member]
Assets:
Commodity contracts		517	475
Liabilities:
Commodity contracts		273	204
Equity Securities [Member]
Assets:
Nuclear decommissioning trust	[3]	608	599
Equity Securities [Member] | Fair Value, Measurements, Recurring [Member]
Assets:
Assets, Measured at Net Asset Value		223
Equity Securities [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Assets:
Nuclear decommissioning trust		385	380	[1]
Equity Securities [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Assets:
Nuclear decommissioning trust	[1]		219
Equity Securities [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Assets:
Nuclear decommissioning trust	[2]	0	0	[1]
Equity Securities [Member] | Total [Member] | Fair Value, Measurements, Recurring [Member]
Assets:
Nuclear decommissioning trust		385	599	[1]
Debt Securities [Member]
Assets:
Nuclear decommissioning trust	[4]	332	319
Debt Securities [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Assets:
Nuclear decommissioning trust	[1]		0
Debt Securities [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Assets:
Nuclear decommissioning trust		332	319	[1]
Debt Securities [Member] | Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Assets:
Nuclear decommissioning trust	[2]	0	0	[1]
Debt Securities [Member] | Total [Member] | Fair Value, Measurements, Recurring [Member]
Assets:
Nuclear decommissioning trust		$ 332	$ 319	[1]
[1]	Fair values are determined on a contract basis, but certain contracts result in a current asset and a noncurrent liability, or vice versa, as presented in the condensed consolidated balance sheets.
[2]	See table below for description of Level 3 assets and liabilities.
[3]	The investment objective for equity securities is to invest tax efficiently and to match the performance of the S&P 500 Index.
[4]	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 3.60% and 3.68% at March 31, 2016 and December 31, 2015, respectively, and an average maturity of 8 years at both March 31, 2016 and December 31, 2015.

Fair Value Measurements (Sche56

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] $ in Millions		3 Months Ended		12 Months Ended
		Mar. 31, 2016USD ($)$ / Megawatt-hour		Dec. 31, 2014$ / Megawatt-hour	Dec. 31, 2015USD ($)
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets	[1]	$ 55			$ 49
Liabilities	[1]	(30)			(12)
Total	[1]	25			37
Electricity purchases and sales [Member] | Valuation Model [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets	[1]	1			1
Liabilities	[1]	(4)			(1)
Total	[1]	(3)			0
Electricity spread options [Member] | Option Pricing Model Valuation Technique [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets		13			2
Liabilities		(23)			(7)
Assets (Liabilities), Fair Value Disclosure		(10)			(5)
Electricity congestion revenue rights [Member] | Market Approach [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets	[1],[2],[3]	36			39
Liabilities	[1],[2],[3]	(3)			(4)
Total	[1],[2],[3]	33			35
Other [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets		5	[1],[4]		7
Liabilities	[1],[4]	0			0	[3]
Total	[1],[4]	$ 5			$ 7	[3]
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) | $ / Megawatt-hour	[1],[5],[6]	0		15
Hourly price curve shape (in usd per MWh) | $ / Megawatt-hour	[1],[6],[7]	0		15
Minimum [Member] | Electricity spread options [Member] | Option Pricing Model Valuation Technique [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair Value Inputs, Gas to power correlation	[1],[2],[6]	15.00%		35.00%
Fair Value Inputs, Power volatility	[1],[6],[8]	10.00%		10.00%
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 | $ / Megawatt-hour	[1],[2],[6],[8]	0		0
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) | $ / Megawatt-hour	[1],[5],[6]	0		35
Hourly price curve shape (in usd per MWh) | $ / Megawatt-hour	[1],[6],[7]	50		45
Maximum [Member] | Electricity spread options [Member] | Option Pricing Model Valuation Technique [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair Value Inputs, Gas to power correlation	[1],[2],[6]	45.00%		80.00%
Fair Value Inputs, Power volatility	[1],[6],[8]	40.00%		35.00%
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 | $ / Megawatt-hour	[1],[2],[6],[8]	10		10
[1]	Electricity purchase and sales contracts include hedging positions in the ERCOT regions, as well as power contracts, the valuations of which include unobservable inputs related to the hourly shaping of the price curve. Electricity spread options 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.
[2]	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.
[3]	While we use the market approach, there is insufficient market data to consider the valuation liquid.
[4]	Other includes contracts for coal purchases, ancillary services, natural gas, power options and coal options.
[5]	Based on the historical range of forward average monthly ERCOT hub and load zone prices.
[6]	The range of the inputs may be influenced by factors such as time of day, delivery period, season and location.
[7]	Based on the historical range of forward average hourly ERCOT North Hub prices.
[8]	Based on historical forward price changes.

Fair Value Measurements (Sche57

Fair Value Measurements (Schedule of Changes in Fair Value of the Level 3 Assets and Liabilities (All Related to Commodity Contracts)) (Details) - Level 3 [Member] - Commodity contracts [Member] - Derivative financial instruments, assets and liabilities [Member] - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Net asset balance at beginning of period		$ 37	$ 35
Total unrealized valuation gains (losses)		(5)	16
Purchases, issuances and settlements:
Purchases	[1]	14	19
Issuances	[1]	(12)	(3)
Settlements	[1]	(10)	(8)
Transfers into Level 3	[2]	0	0
Transfers out of Level 3	[2]	1	1
Net change	[3]	(12)	25
Net asset balance at end of period		25	60
Unrealized valuation gains (losses) relating to instruments held at end of period		$ (4)	$ 15
[1]	Settlements reflect reversals of unrealized mark-to-market valuations previously recognized in net income. Purchases and issuances reflect option premiums paid or received.
[2]	Includes transfers due to changes in the observability of significant inputs. Transfers in and out occur at the end of each quarter, which is when the assessments are performed. All Level 3 transfers during the periods presented are in and out of Level 2.
[3]	Substantially all changes in values of commodity contracts are reported in the condensed statements of consolidated loss in net gain from commodity hedging and trading activities. 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 quarter.

Commodity And Other Derivativ58

Commodity And Other Derivative Contractual Assets And Liabilities (Financial Statement Effects of Derivatives) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Liabilities Subject To Compromise, Liability Under Terminated Agreements, Net	$ 1,243		$ 1,243
Derivative, Fair Value, Net	244		271
Commodity contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative assets: Amounts Presented in Balance Sheet	517		475
Derivative liabilities, Fair Value, Gross Liability	(273)		(204)
Derivative asset, Fair Value, Net	513		475
Derivative liabilities, Fair Value, Net	(269)		(204)
Derivative, Fair Value, Net	244		271
Commodity contracts [Member] | Current assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets: Amounts Presented in Balance Sheet	496		465
Derivative liabilities, Fair Value, Gross Asset	3		0
Derivative Assets And Liability, Fair Value, Gross Assets	499		465
Commodity contracts [Member] | Noncurrent assets [Member]
Derivatives, Fair Value [Line Items]
Derivative assets: Amounts Presented in Balance Sheet	18		10
Derivative liabilities, Fair Value, Gross Asset	0		0
Derivative Assets And Liability, Fair Value, Gross Assets	18		10
Commodity contracts [Member] | Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative asset, Fair Value, Gross Liability	0		0
Derivative liabilities, Fair Value, Gross Liability	(261)		(203)
Derivative Assets And Liability, Fair Value, Gross Liability	(261)		(203)
Commodity contracts [Member] | Noncurrent Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative asset, Fair Value, Gross Liability	(1)		0
Derivative liabilities, Fair Value, Gross Liability	(11)		(1)
Derivative Assets And Liability, Fair Value, Gross Liability	(12)		$ (1)
Net gain from commodity hedging and trading activities [Member] | Commodity contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative, Gain (Loss) on Derivative, Net	$ 56	$ 125

Commodity And Other Derivativ59

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) - Interest rate swaps [Member] - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss), Cumulative Changes in Net Gain (Loss) from Cash Flow Hedges, Effect Net of Tax		$ (33)
Interest Rate Cash Flow Hedge Gain (Loss) to be Reclassified During Next 12 Months, Net	$ (2)

Commodity And Other Derivativ60

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 ($) $ in Millions		Mar. 31, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net		$ 244	$ 271
Derivative Asset (Liabilit), Collateral, Obligation to Return Cash		0	0
Derivative (Assets) Liability, Fair Value of Collateral, Net	[1]	(160)	(141)
Derivative Assets (Liability), Fair Value, Amount Offset Against Collateral		84	130
Commodity contracts [Member]
Derivatives, Fair Value [Line Items]
Derivative assets: Amounts Presented in Balance Sheet		517	475
Derivative assets: Offsetting Financial Instruments	[2]	(160)	(145)
Derivative assets: Financial Collateral (Received) Pledged	[1]	(172)	(147)
Derivative assets: Net Amounts		185	183
Derivative liabilities: Amounts Presented in Balance Sheet		(273)	(204)
Derivative liabilities: Offsetting Financial Instruments	[2]	160	145
Derivative liabilities: Financial Collateral (Received) Pledged	[1]	12	6
Derivative liabilities: Net Amounts		(101)	(53)
Derivative, Fair Value, Net		$ 244	$ 271
[1]	Financial collateral consists entirely of cash margin deposits.
[2]	Amounts presented exclude trade accounts receivable and payable related to settled financial instruments.

Commodity And Other Derivativ61

Commodity And Other Derivative Contractual Assets And Liabilities (Derivative Volumes) (Details) lb in Thousands, gal in Millions, T in Millions, MMBTU in Millions		Mar. 31, 2016TMMBTUgallbGWh	Dec. 31, 2015TMMBTUgallbGWh
Natural Gas Derivative [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | MMBTU	[1]	1,615	1,489
Electricity (in GWh) [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume		67,261	58,022
Congestion Revenue RIghts (in GWh) [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume	[1]	115,014	106,260
Coal (in tons) [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | T		8	10
Fuel oil (in gallons) [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | gal		32	35
Uranium (in pounds) [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | lb		455	75
[1]	Represents gross forward purchases associated with instruments used to hedge electricity price differences between settlement points within ERCOT.

Commodity And Other Derivativ62

Commodity And Other Derivative Contractual Assets And Liabilities (Credit Risk-Related Contingent Features of Derivatives) (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Credit Derivatives [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 113	$ 59
Credit risk derivative with contingent feature [Member]
Credit Derivatives [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	111	58
Collateral Already Posted, Aggregate Fair Value	$ 66	$ 31

Commodity And Other Derivativ63

Commodity And Other Derivative Contractual Assets And Liabilities (Concentrations of Credit Risk Related to Derivatives) (Details) - Texas Competitive Electric Holdings Company LLC - Credit Risk Contract [Member] $ in Millions	3 Months Ended
	Mar. 31, 2016USD ($)
Derivative [Line Items]
Total credit risk exposure to all counterparties related to derivative contracts	$ 552
Net exposure to those counterparties after taking into effect master netting arrangements, setoff provisions and collateral	187
Largest net Exposure to single counterparty	$ 104
Credit risk exposure to banking and financial sector percentage	80.00%
Net exposure to banking and financial sector percentage	62.00%

Related Party Transactions (Nar

Related Party Transactions (Narrative) (Details) $ in Millions	1 Months Ended	3 Months Ended				12 Months Ended
	Feb. 28, 2014USD ($)	Mar. 31, 2016USD ($)Rating-Agencies-Downgrades	Dec. 31, 2015USD ($)	Mar. 31, 2015USD ($)	Mar. 31, 2014USD ($)	Dec. 31, 2014USD ($)
Related Party Transaction [Line Items]
Advance to parent (Note 15)		$ 6	$ 6
Advance to parent (Note 15)		16	18
Contractual Interest on Debt Classified as LSTC		531		$ 515
Due from Affiliates		22	24
Texas Competitive Electric Holdings [Member]
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction		2		15
Energy Future Holdings Corp. [Member]
Related Party Transaction [Line Items]
Related Party Tax Expense, Due to Affiliates, Current		14				$ 10
Oncor [Member]
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction		220		236
Due to Affiliate		101	118
Pension Plan [Member]
Related Party Transaction [Line Items]
Defined Benefit Plan Contributions By Employer Excluding Affiliated Supplemental Plan	$ 84		67
Majority-Owned Subsidiary, Unconsolidated [Member] | Oncor [Member] | Pension Plan [Member]
Related Party Transaction [Line Items]
Defined Benefit Plan, Contributions by Employer	$ 64		51
Energy Future Holdings Corp. [Member] | Texas Competitive Electric Holdings [Member]
Related Party Transaction [Line Items]
Selling, general and administrative expenses from transactions with related party		60		51
Texas Competitive Electric Holdings Company LLC
Related Party Transaction [Line Items]
Contractual Interest on Debt Classified as LSTC		531		$ 513
Texas Competitive Electric Holdings Company LLC | Oncor [Member]
Related Party Transaction [Line Items]
Delivery fee surcharge remitted to related party		4
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) | Rating-Agencies-Downgrades		2
Texas Competitive Electric Holdings Company LLC | Senior Notes [Member]
Related Party Transaction [Line Items]
Long-term Debt Held by Affiliates			382
Texas Competitive Electric Holdings Company LLC | Decommisioning liablity [Member] | Oncor [Member]
Related Party Transaction [Line Items]
Due to Affiliate, Noncurrent		$ 424	409
Texas Competitive Electric Holdings Company LLC | Collateral posted [Member] | Oncor [Member]
Related Party Transaction [Line Items]
Letter of credit posted as collateral		$ 6	6
Texas Competitive Electric Holdings Company LLC | Pension Plan [Member]
Related Party Transaction [Line Items]
Defined Benefit Plan, Contributions by Employer			$ 16		$ 20

Related-Party Transactions (Ene

Related-Party Transactions (Energy Future Competitive Holdings CO Related Party Information) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Related Party Transaction [Line Items]
Contractual Interest on Debt Classified as LSTC	$ 531	$ 515
Texas Competitive Electric Holdings Company LLC
Related Party Transaction [Line Items]
Contractual Interest on Debt Classified as LSTC	$ 531	$ 513

Supplementary Financial Infor66

Supplementary Financial Information (Other Income and Deductions) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Finite-Lived Intangible Assets [Line Items]
Mineral rights royalty income	$ 1	$ 1
All other	0	2
Total other income	1	3
All other	1	1
Total other deductions	21	60
Favorable purchase and sales contracts [Member]
Finite-Lived Intangible Assets [Line Items]
Write-off of generation equipment	20	0
Impairment of Intangible Assets (Excluding Goodwill)	0	8
Environmental allowances and credits [Member]
Finite-Lived Intangible Assets [Line Items]
Impairment of Intangible Assets (Excluding Goodwill)	$ 0	$ 51

Supplementary Financial Infor67

Supplementary Financial Information - (Restricted Cash) (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Current Assets	$ 661	$ 519
Noncurrent Assets	507	507
Texas Competitive Electric Holdings Company LLC | Amount Related To Texas Competitive Electric Company LLC Debtor-In-Possession Facility [Member]
Current Assets	661	519
Noncurrent Assets	0	0
Texas Competitive Electric Holdings Company LLC | Amount Related To Texas Competitive Electric Holdings Company LLC Letter Of Credit Facility [Member]
Current Assets	0	0
Noncurrent Assets	$ 507	$ 507

Supplementary Financial Infor68

Supplementary Financial Information (Trade Accounts Receivable and Allowance for Uncollectible Accounts Receivable) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Mar. 31, 2016	Dec. 31, 2015
Trade Accounts Receivable [Abstract]
Wholesale and retail trade accounts receivable			$ 454	$ 542
Allowance for uncollectible accounts	$ (9)	$ (15)	(7)	(9)
Trade accounts receivable — net			447	533
Unbilled Receivables, Current			$ 183	$ 231
Allowance for Doubtful Accounts Receivable [Roll Forward]
Allowance for uncollectible accounts receivable at beginning of period	9	15
Increase for bad debt expense	5	9
Decrease for account write-offs	(7)	(9)
Allowance for uncollectible accounts receivable at end of period	$ 7	$ 15

Supplementary Financial Infor69

Supplementary Financial Information (Inventories by Major Category and Other Investments) (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Inventories by Major Category
Materials and supplies	$ 222	$ 226
Fuel stock	196	170
Natural gas in storage	30	32
Total inventories	448	428
Other Investments
Nuclear plant decommissioning trust	940	918
Land	36	36
Miscellaneous other	8	8
Total investments	$ 984	$ 962

Supplementary Financial Infor70

Supplementary Financial Information (Nuclear Decommissioning Trust) (Details) - USD ($) $ in Millions		3 Months Ended		12 Months Ended
		Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2014	Dec. 31, 2015
Schedule of Schedule of Decommissioning Fund Investments [Line Items]
Cost	[1]	$ 611			$ 601
Unrealized gain		337			326
Unrealized loss		(8)			(9)
Fair market value		940			918
Realized gains		1	$ 0
Realized losses		(1)	(1)
Proceeds from sales of securities		67	23
Investments in securities		(71)	$ (27)
Debt Securities [Member]
Schedule of Schedule of Decommissioning Fund Investments [Line Items]
Cost	[1],[2]	315			310
Unrealized gain	[2]	17			11
Unrealized loss	[2]	0			(2)
Fair market value	[2]	$ 332			$ 319
Debt securities, average coupon rate (as a percent)		3.60%			3.68%
Decommissioning Fund Investments, Debt securities, average maturity				8 years
Decommissioning Fund Investments, debt maturities, one through five years, fair value		$ 109
Decommissioning Fund Investments, debt maturities, five through ten years, fair value		74
Decommissioning Fund Investments, debt maturities, after ten years, fair value		149
Equity Securities [Member]
Schedule of Schedule of Decommissioning Fund Investments [Line Items]
Cost	[1],[3]	296			$ 291
Unrealized gain	[3]	320			315
Unrealized loss	[3]	(8)			(7)
Fair market value	[3]	$ 608			$ 599
[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 3.60% and 3.68% at March 31, 2016 and December 31, 2015, respectively, and an average maturity of 8 years at both March 31, 2016 and December 31, 2015.
[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 Infor71

Supplementary Financial Information (Property, Plant and Equipment) (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Supplementary Financial Information [Abstract]
Property, plant and equipment — net (Note 16)	$ 9,273	$ 9,349
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	$ 4,177	$ 4,037

Supplementary Financial Infor72

Supplementary Financial Information (Asset Retirement and Mining Reclamation Obligations) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Asset Retirement Obligations [Line Items]
Liability at December 31, 2015	$ 830
Accretion	14
Incremental reclamation costs	17
Payments	15
Liability at March 31, 2016	846
Less amounts due currently	60
Noncurrent liability at March 31, 2016	786	$ 764
Nuclear Plant Decommissioning [Member]
Asset Retirement Obligations [Line Items]
Liability at December 31, 2015	508
Accretion	7
Incremental reclamation costs	0
Payments	0
Liability at March 31, 2016	515
Less amounts due currently	0
Noncurrent liability at March 31, 2016	515
Mining Land Reclamation [Member]
Asset Retirement Obligations [Line Items]
Liability at December 31, 2015	215
Accretion	5
Incremental reclamation costs	14
Payments	15
Liability at March 31, 2016	219
Less amounts due currently	60
Noncurrent liability at March 31, 2016	159
Other
Asset Retirement Obligations [Line Items]
Liability at December 31, 2015	107
Accretion	2
Incremental reclamation costs	3
Payments	0
Liability at March 31, 2016	112
Less amounts due currently	0
Noncurrent liability at March 31, 2016	$ 112

Supplementary Financial Infor73

Supplementary Financial Information (Other Noncurrent Liabilities and Deferred Credits) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Supplementary Financial Information [Abstract]
Uncertain tax positions, including accrued interest	$ 41		$ 41
Asset retirement and mining reclamation obligations	786		764
Unfavorable purchase and sales contracts	537		543
Nuclear decommissioning fund excess over asset retirement obligation (Note 15)	424		409
Other, including retirement and other employee benefits	31		23
Total other noncurrent liabilities and deferred credits	1,819		$ 1,780
Amortization of Deferred Charges
Amortization of Unfavorable Purchase and Sales Contracts	6	$ 6
Future Amortization Expense
2,016	24
2,017	24
2,018	24
2,019	24
2,020	$ 24

Supplementary Financial Infor74

Supplementary Financial Information Supplementary Financial Information - (Fair Value) (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Debtor-In-Possession Facility [Member] | Reported Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Instrument, Fair Value Disclosure	$ 1,425	$ 1,425
Long-Term Debt, Including Amounts Due Currently [Member] | Reported Value Measurement [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Instrument, Fair Value Disclosure	46	49
Level 2 [Member] | Debtor-In-Possession Facility [Member] | Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Instrument, Fair Value Disclosure	1,418	1,411
Level 2 [Member] | Long-Term Debt, Including Amounts Due Currently [Member] | Fair Value [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Instrument, Fair Value Disclosure	$ 48	$ 53

Supplementary Financial Infor75

Supplementary Financial Information (Supplemental Cash Flow Information) (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
Cash payments related to:
Interest paid (a)	[1]	$ 336	$ 323
Capitalized interest		(3)	(3)
Interest paid (net of capitalized interest) (a)	[1]	333	320
Reorganization items (b)	[2]	41	35
Noncash investing and financing activities:
Construction expenditures (c)	[3]	$ 82	$ 65
[1]	This amount includes amounts paid for adequate protection.
[2]	Represents cash payments for legal and other consulting services
[3]	Represents end-of-period accruals for ongoing construction projects.

Supplemental Guarantor Conden76

Supplemental Guarantor Condensed Financial Information (Narrative) (Details) $ in Millions	Dec. 31, 2015USD ($)
Energy Future Holdings Senior Notes [Member] | Push Down Debt [Member]
Condensed Financial Statements, Captions [Line Items]
Debt and Capital Lease Obligations	$ 30

Supplemental Guarantor Conden77

Supplemental Guarantor Condensed Financial Information (Condensed Consolidating Statements of Income (Loss)) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Condensed Financial Statements, Captions [Line Items]
Other Comprehensive Income (Loss), Net of Tax	$ 0	$ 1
Operating revenues	1,049	1,272
Fuel, purchased power costs and delivery fees	(554)	(613)
Net gain from commodity hedging and trading activities	64	103
Operating costs	(219)	(193)
Depreciation and amortization	(139)	(215)
Selling, general and administrative expenses	(160)	(161)
Impairment of goodwill	0	(700)
Impairment of long-lived assets	0	(676)
Other income	1	3
Other deductions	(21)	(60)
Interest income	0	0
Interest expense and related charges	(336)	(317)
Reorganization items	(22)	(73)
Loss before income taxes	(337)	(1,630)
Income tax (expense) benefit	(4)	293
Equity earnings of subsidiaries	0	0
Net loss	(341)	(1,337)
Comprehensive income (loss)	(341)	(1,336)
Parent Guarantor [Member]
Condensed Financial Statements, Captions [Line Items]
Other Comprehensive Income (Loss), Net of Tax	0	1
Operating revenues	0	0
Fuel, purchased power costs and delivery fees	0	0
Net gain from commodity hedging and trading activities	0	0
Operating costs	0	0
Depreciation and amortization	0	0
Selling, general and administrative expenses	0	0
Impairment of goodwill		0
Impairment of long-lived assets		0
Other income	0	0
Other deductions	0	0
Interest income	0	0
Interest expense and related charges	(1)	(1)
Reorganization items	0	0
Loss before income taxes	(1)	(1)
Income tax (expense) benefit	3	0
Equity earnings of subsidiaries	(343)	(1,336)
Net loss	(341)	(1,337)
Comprehensive income (loss)	(341)	(1,336)
Issuer [Member]
Condensed Financial Statements, Captions [Line Items]
Other Comprehensive Income (Loss), Net of Tax	0	1
Operating revenues	0	0
Fuel, purchased power costs and delivery fees	0	0
Net gain from commodity hedging and trading activities	0	0
Operating costs	0	0
Depreciation and amortization	(2)	(1)
Selling, general and administrative expenses	2	0
Impairment of goodwill		(700)
Impairment of long-lived assets		0
Other income	0	0
Other deductions	0	0
Interest income	15	1
Interest expense and related charges	(390)	(337)
Reorganization items	(21)	(43)
Loss before income taxes	(396)	(1,080)
Income tax (expense) benefit	(3)	112
Equity earnings of subsidiaries	56	(368)
Net loss	(343)	(1,336)
Comprehensive income (loss)	(343)	(1,335)
Other Guarantors [Member]
Condensed Financial Statements, Captions [Line Items]
Other Comprehensive Income (Loss), Net of Tax	0	0
Operating revenues	1,049	1,272
Fuel, purchased power costs and delivery fees	(554)	(613)
Net gain from commodity hedging and trading activities	64	103
Operating costs	(219)	(193)
Depreciation and amortization	(137)	(214)
Selling, general and administrative expenses	(162)	(161)
Impairment of goodwill		0
Impairment of long-lived assets		(676)
Other income	1	3
Other deductions	(21)	(60)
Interest income	53	18
Interest expense and related charges	(13)	2
Reorganization items	(1)	(30)
Loss before income taxes	60	(549)
Income tax (expense) benefit	(8)	176
Equity earnings of subsidiaries	0	0
Net loss	52	(373)
Comprehensive income (loss)	52	(373)
Non-guarantors [Member]
Condensed Financial Statements, Captions [Line Items]
Other Comprehensive Income (Loss), Net of Tax	0	0
Operating revenues	0	0
Fuel, purchased power costs and delivery fees	0	0
Net gain from commodity hedging and trading activities	0	0
Operating costs	0	0
Depreciation and amortization	0	0
Selling, general and administrative expenses	0	0
Impairment of goodwill		0
Impairment of long-lived assets		0
Other income	0	0
Other deductions	0	0
Interest income	0	0
Interest expense and related charges	0	0
Reorganization items	0	0
Loss before income taxes	0	0
Income tax (expense) benefit	0	0
Equity earnings of subsidiaries	0	0
Net loss	0	0
Comprehensive income (loss)	0	0
Eliminations [Member]
Condensed Financial Statements, Captions [Line Items]
Other Comprehensive Income (Loss), Net of Tax	0	(1)
Operating revenues	0	0
Fuel, purchased power costs and delivery fees	0	0
Net gain from commodity hedging and trading activities	0	0
Operating costs	0	0
Depreciation and amortization	0	0
Selling, general and administrative expenses	0	0
Impairment of goodwill		0
Impairment of long-lived assets		0
Other income	0	0
Other deductions	0	0
Interest income	(68)	(19)
Interest expense and related charges	68	19
Reorganization items	0	0
Loss before income taxes	0	0
Income tax (expense) benefit	4	5
Equity earnings of subsidiaries	287	1,704
Net loss	291	1,709
Comprehensive income (loss)	$ 291	$ 1,708

Supplemental Guarantor Conden78

Supplemental Guarantor Condensed Financial Information (Condensed Consolidating Statements of Cash Flows) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Condensed Financial Statements, Captions [Line Items]
Cash provided by (used in) operating activities	$ (191)	$ (107)
Cash flows – financing activities:
Notes/advances due to affiliates	0	0
Repayments/repurchases of debt	(5)	(9)
Cash used in financing activities	(5)	(9)
Cash flows – investing activities:
Capital expenditures	(83)	(115)
Nuclear fuel purchases	(10)	(5)
Settlements of notes/advances due from affiliates	0	0
Changes in restricted cash	(142)	28
Proceeds from sales of nuclear decommissioning trust fund securities (Note 16)	67	23
Investments in nuclear decommissioning trust fund securities (Note 16)	(71)	(27)
Other, net	3	(14)
Cash used in investing activities	(236)	(110)
Net change in cash and cash equivalents	(432)	(226)
Cash and cash equivalents – beginning balance	1,400	1,843
Cash and cash equivalents – ending balance	968	1,617
Parent Guarantor [Member]
Condensed Financial Statements, Captions [Line Items]
Cash provided by (used in) operating activities	0	(3)
Cash flows – financing activities:
Notes/advances due to affiliates	2	4
Repayments/repurchases of debt	(2)	(1)
Cash used in financing activities	0	3
Cash flows – investing activities:
Capital expenditures	0	0
Nuclear fuel purchases	0	0
Settlements of notes/advances due from affiliates	0	0
Changes in restricted cash	0	0
Proceeds from sales of nuclear decommissioning trust fund securities (Note 16)	0	0
Investments in nuclear decommissioning trust fund securities (Note 16)	0	0
Other, net	0	0
Cash used in investing activities	0	0
Net change in cash and cash equivalents	0	0
Cash and cash equivalents – beginning balance	0	0
Cash and cash equivalents – ending balance	0	0
Issuer [Member]
Condensed Financial Statements, Captions [Line Items]
Cash provided by (used in) operating activities	(342)	(415)
Cash flows – financing activities:
Notes/advances due to affiliates	58	169
Repayments/repurchases of debt	0	0
Cash used in financing activities	58	169
Cash flows – investing activities:
Capital expenditures	0	0
Nuclear fuel purchases	0	0
Settlements of notes/advances due from affiliates	0	0
Changes in restricted cash	(142)	28
Proceeds from sales of nuclear decommissioning trust fund securities (Note 16)	0	0
Investments in nuclear decommissioning trust fund securities (Note 16)	0	0
Other, net	0	(11)
Cash used in investing activities	(142)	17
Net change in cash and cash equivalents	(426)	(229)
Cash and cash equivalents – beginning balance	1,368	1,826
Cash and cash equivalents – ending balance	942	1,597
Other Guarantors [Member]
Condensed Financial Statements, Captions [Line Items]
Cash provided by (used in) operating activities	151	311
Cash flows – financing activities:
Notes/advances due to affiliates	0	0
Repayments/repurchases of debt	(3)	(8)
Cash used in financing activities	(3)	(8)
Cash flows – investing activities:
Capital expenditures	(83)	(115)
Nuclear fuel purchases	(10)	(5)
Settlements of notes/advances due from affiliates	(60)	(173)
Changes in restricted cash	0	0
Proceeds from sales of nuclear decommissioning trust fund securities (Note 16)	67	23
Investments in nuclear decommissioning trust fund securities (Note 16)	(71)	(27)
Other, net	3	(3)
Cash used in investing activities	(154)	(300)
Net change in cash and cash equivalents	(6)	3
Cash and cash equivalents – beginning balance	22	16
Cash and cash equivalents – ending balance	16	19
Non-guarantors [Member]
Condensed Financial Statements, Captions [Line Items]
Cash provided by (used in) operating activities	0	0
Cash flows – financing activities:
Notes/advances due to affiliates	0	0
Repayments/repurchases of debt	0	0
Cash used in financing activities	0	0
Cash flows – investing activities:
Capital expenditures	0	0
Nuclear fuel purchases	0	0
Settlements of notes/advances due from affiliates	0	0
Changes in restricted cash	0	0
Proceeds from sales of nuclear decommissioning trust fund securities (Note 16)	0	0
Investments in nuclear decommissioning trust fund securities (Note 16)	0	0
Other, net	0	0
Cash used in investing activities	0	0
Net change in cash and cash equivalents	0	0
Cash and cash equivalents – beginning balance	10	1
Cash and cash equivalents – ending balance	10	1
Eliminations [Member]
Condensed Financial Statements, Captions [Line Items]
Cash provided by (used in) operating activities	0	0
Cash flows – financing activities:
Notes/advances due to affiliates	(60)	(173)
Repayments/repurchases of debt	0	0
Cash used in financing activities	(60)	(173)
Cash flows – investing activities:
Capital expenditures	0	0
Nuclear fuel purchases	0	0
Settlements of notes/advances due from affiliates	60	173
Changes in restricted cash	0	0
Proceeds from sales of nuclear decommissioning trust fund securities (Note 16)	0	0
Investments in nuclear decommissioning trust fund securities (Note 16)	0	0
Other, net	0	0
Cash used in investing activities	60	173
Net change in cash and cash equivalents	0	0
Cash and cash equivalents – beginning balance	0	0
Cash and cash equivalents – ending balance	$ 0	$ 0

Supplemental Guarantor Conden79

Supplemental Guarantor Condensed Financial Information (Condensed Consolidating Balance Sheets) (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015	Mar. 31, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 968	$ 1,400	$ 1,617	$ 1,843
Current Assets	661	519
Advance to parent (Note 15)	6	6
Trade accounts receivable – net	447	533
Accounts receivable from affiliates	0	0
Inventories	448	428
Commodity and other derivative contractual assets	499	465
Other current assets	93	71
Total current assets	3,122	3,422
Noncurrent Assets	507	507
Investments	984	962
Property, plant and equipment – net	9,273	9,349
Advances to parent	16	18
Goodwill	152	152
Identifiable intangible assets – net	1,170	1,179
Accumulated deferred income taxes	0	0
Other noncurrent assets	50	39
Total assets	15,274	15,628
Current liabilities:
Borrowings under debtor-in-possession credit facility (Note 9)	1,425	1,425
Long-term debt due currently	29	31
Trade accounts payable	351	394
Trade accounts and other payables to affiliates	103	119
Commodity and other derivative contractual liabilities	261	203
Margin deposits related to commodity positions	176	152
Accrued income taxes payable to parent	14	10
Accrued taxes other than income	66	98
Accrued interest	123	120
Other current liabilities	228	274
Total current liabilities	2,776	2,826
Accumulated deferred income taxes	213	213
Notes or other liabilities due affiliates	0	0
Long-term debt, less amounts due currently (Note 9)	21	23
Liabilities subject to compromise (Note 10)	33,776	33,776
Other noncurrent liabilities and deferred credits	1,819	1,780
Total liabilities	38,605	38,618
Total membership interests	(23,331)	(22,990)	(19,805)	(18,474)
Total liabilities and membership interests	15,274	15,628
Parent Guarantor [Member]
Current assets:
Cash and cash equivalents	0	0	0	0
Current Assets	0	0
Advance to parent (Note 15)	0	0
Trade accounts receivable – net	0	0
Accounts receivable from affiliates	0	0
Inventories	0	0
Commodity and other derivative contractual assets	0	0
Other current assets	0	0
Total current assets	0	0
Noncurrent Assets	0	0
Investments	(33,164)	(32,818)
Property, plant and equipment – net	0	0
Advances to parent	0	0
Goodwill	0	0
Identifiable intangible assets – net	0	0
Accumulated deferred income taxes	3	0
Other noncurrent assets	0	0
Total assets	(33,161)	(32,818)
Current liabilities:
Borrowings under debtor-in-possession credit facility (Note 9)	0	0
Long-term debt due currently	14	15
Trade accounts payable	0	0
Trade accounts and other payables to affiliates	0	0
Commodity and other derivative contractual liabilities	0	0
Margin deposits related to commodity positions	0	0
Accrued income taxes payable to parent	0	0
Accrued taxes other than income	0	0
Accrued interest	0	0
Other current liabilities	0	0
Total current liabilities	14	15
Accumulated deferred income taxes	0	0
Notes or other liabilities due affiliates	0	0
Long-term debt, less amounts due currently (Note 9)	19	20
Liabilities subject to compromise (Note 10)	44	44
Other noncurrent liabilities and deferred credits	0	0
Total liabilities	77	79
Total membership interests	(33,238)	(32,897)
Total liabilities and membership interests	(33,161)	(32,818)
Issuer [Member]
Current assets:
Cash and cash equivalents	942	1,368	1,597	1,826
Current Assets	661	519
Advance to parent (Note 15)	6	6
Trade accounts receivable – net	0	0
Accounts receivable from affiliates	61	92
Inventories	0	0
Commodity and other derivative contractual assets	0	0
Other current assets	2	3
Total current assets	1,672	1,988
Noncurrent Assets	507	507
Investments	9,169	9,095
Property, plant and equipment – net	0	12
Advances to parent	16	18
Goodwill	152	152
Identifiable intangible assets – net	0	31
Accumulated deferred income taxes	357	438
Other noncurrent assets	3	1
Total assets	11,876	12,242
Current liabilities:
Borrowings under debtor-in-possession credit facility (Note 9)	1,425	1,425
Long-term debt due currently	0	0
Trade accounts payable	8	21
Trade accounts and other payables to affiliates	0	0
Commodity and other derivative contractual liabilities	0	0
Margin deposits related to commodity positions	0	0
Accrued income taxes payable to parent	0	0
Accrued taxes other than income	0	0
Accrued interest	122	119
Other current liabilities	20	32
Total current liabilities	1,575	1,597
Accumulated deferred income taxes	0	0
Notes or other liabilities due affiliates	0	0
Long-term debt, less amounts due currently (Note 9)	0	0
Liabilities subject to compromise (Note 10)	43,468	43,468
Other noncurrent liabilities and deferred credits	(3)	(4)
Total liabilities	45,040	45,061
Total membership interests	(33,164)	(32,819)
Total liabilities and membership interests	11,876	12,242
Other Guarantors [Member]
Current assets:
Cash and cash equivalents	16	22	19	16
Current Assets	0	0
Advance to parent (Note 15)	0	0
Trade accounts receivable – net	447	533
Accounts receivable from affiliates	0	0
Inventories	448	428
Commodity and other derivative contractual assets	499	465
Other current assets	91	68
Total current assets	1,501	1,516
Noncurrent Assets	0	0
Investments	1,006	983
Property, plant and equipment – net	9,270	9,334
Advances to parent	0	0
Goodwill	0	0
Identifiable intangible assets – net	1,170	1,148
Accumulated deferred income taxes	405	393
Other noncurrent assets	47	38
Total assets	13,399	13,412
Current liabilities:
Borrowings under debtor-in-possession credit facility (Note 9)	0	0
Long-term debt due currently	15	16
Trade accounts payable	343	373
Trade accounts and other payables to affiliates	164	211
Commodity and other derivative contractual liabilities	261	203
Margin deposits related to commodity positions	176	152
Accrued income taxes payable to parent	14	10
Accrued taxes other than income	66	98
Accrued interest	1	1
Other current liabilities	208	242
Total current liabilities	1,248	1,306
Accumulated deferred income taxes	0	0
Notes or other liabilities due affiliates	0	0
Long-term debt, less amounts due currently (Note 9)	2	3
Liabilities subject to compromise (Note 10)	31,601	31,601
Other noncurrent liabilities and deferred credits	1,822	1,784
Total liabilities	34,673	34,694
Total membership interests	(21,274)	(21,282)
Total liabilities and membership interests	13,399	13,412
Non-guarantors [Member]
Current assets:
Cash and cash equivalents	10	10	1	1
Current Assets	0	0
Advance to parent (Note 15)	0	0
Trade accounts receivable – net	0	0
Accounts receivable from affiliates	0	0
Inventories	0	0
Commodity and other derivative contractual assets	0	0
Other current assets	0	0
Total current assets	10	10
Noncurrent Assets	0	0
Investments	4	5
Property, plant and equipment – net	3	3
Advances to parent	0	0
Goodwill	0	0
Identifiable intangible assets – net	0	0
Accumulated deferred income taxes	11	11
Other noncurrent assets	0	0
Total assets	28	29
Current liabilities:
Borrowings under debtor-in-possession credit facility (Note 9)	0	0
Long-term debt due currently	0	0
Trade accounts payable	0	0
Trade accounts and other payables to affiliates	0	0
Commodity and other derivative contractual liabilities	0	0
Margin deposits related to commodity positions	0	0
Accrued income taxes payable to parent	0	0
Accrued taxes other than income	0	0
Accrued interest	0	0
Other current liabilities	0	0
Total current liabilities	0	0
Accumulated deferred income taxes	0	0
Notes or other liabilities due affiliates	2	2
Long-term debt, less amounts due currently (Note 9)	0	0
Liabilities subject to compromise (Note 10)	0	0
Other noncurrent liabilities and deferred credits	0	0
Total liabilities	2	2
Total membership interests	26	27
Total liabilities and membership interests	28	29
Eliminations [Member]
Current assets:
Cash and cash equivalents	0	0	$ 0	$ 0
Current Assets	0	0
Advance to parent (Note 15)	0	0
Trade accounts receivable – net	0	0
Accounts receivable from affiliates	(61)	(92)
Inventories	0	0
Commodity and other derivative contractual assets	0	0
Other current assets	0	0
Total current assets	(61)	(92)
Noncurrent Assets	0	0
Investments	23,969	23,697
Property, plant and equipment – net	0	0
Advances to parent	0	0
Goodwill	0	0
Identifiable intangible assets – net	0	0
Accumulated deferred income taxes	(776)	(842)
Other noncurrent assets	0	0
Total assets	23,132	22,763
Current liabilities:
Borrowings under debtor-in-possession credit facility (Note 9)	0	0
Long-term debt due currently	0	0
Trade accounts payable	0	0
Trade accounts and other payables to affiliates	(61)	(92)
Commodity and other derivative contractual liabilities	0	0
Margin deposits related to commodity positions	0	0
Accrued income taxes payable to parent	0	0
Accrued taxes other than income	0	0
Accrued interest	0	0
Other current liabilities	0	0
Total current liabilities	(61)	(92)
Accumulated deferred income taxes	213	213
Notes or other liabilities due affiliates	(2)	(2)
Long-term debt, less amounts due currently (Note 9)	0	0
Liabilities subject to compromise (Note 10)	(41,337)	(41,337)
Other noncurrent liabilities and deferred credits	0	0
Total liabilities	(41,187)	(41,218)
Total membership interests	64,319	63,981
Total liabilities and membership interests	$ 23,132	$ 22,763