Energy Future Competitive 10-K 1 Mar 16 2015 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2015	Jun. 30, 2014
Entity Information [Line Items]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
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 Outstanding Membership Interests	At February 29, 2016, the outstanding membership interest in Energy Future Competitive Holding Company LLC was directly held by Energy Future Holdings Corp.
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float		$ 0
Common Class A [Member]
Entity Information [Line Items]
Entity Common Stock, Shares Outstanding A	0
Common Class B [Member]
Entity Information [Line Items]
Entity Common Stock, Shares Outstanding A	0

Statements Of Consolidated Inco

Statements Of Consolidated Income (Loss) - USD ($) $ in Millions	1 Months Ended	8 Months Ended	12 Months Ended
	Sep. 30, 2014	Dec. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating revenues			$ 5,370	$ 5,978	$ 5,899
Fuel, purchased power costs and delivery fees			(2,692)	(2,842)	(2,848)
Net gain (loss) from commodity hedging and trading activities			334	11	(54)
Operating costs			(834)	(914)	(881)
Depreciation and amortization			(852)	(1,270)	(1,333)
Selling, general and administrative expenses			(676)	(708)	(756)
Impairment of goodwill (Note 4)	$ (1,600)		(2,200)	(1,600)	(1,000)
Impairment of long-lived assets (Note 8)			(2,541)	(4,670)	(140)
Other income (Note 7)			17	16	9
Other deductions (Note 7)			(93)	(281)	(22)
Interest income			0	0	5
Interest expense and related charges (Note 9)			(1,293)	(1,758)	(1,933)
Reorganization items (Note 10)		$ (521)	(1)	(521)	0
Loss before income taxes			(5,461)	(8,559)	(3,054)
Income tax benefit (Note 6)			858	2,330	737
Net loss			(4,603)	(6,229)	(2,317)
Net loss attributable to noncontrolling interests			0	0	107
Net loss attributable to EFCH			$ (4,603)	$ (6,229)	$ (2,210)

Statements Of Consolidated Comp

Statements Of Consolidated Comprehensive Income (Loss) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Net loss	$ (4,603)	$ (6,229)	$ (2,317)
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 $—, $1 and $3)	2	1	6
Comprehensive loss	(4,601)	(6,228)	(2,311)
Comprehensive loss attributable to noncontrolling interests	0	0	107
Comprehensive loss attributable to EFCH	$ (4,601)	$ (6,228)	$ (2,204)

Statements Of Consolidated Com4

Statements Of Consolidated Comprehensive Income (Loss) (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Other comprehensive income, net of tax effects – cash flow hedges derivative value net loss related to hedged transactions recognized during the period and reported in net loss	$ 0	$ 1	$ 3

Statements Of Consolidated Cash

Statements Of Consolidated Cash Flows - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Cash flows - operating activities:
Net loss		$ (4,603)	$ (6,229)	$ (2,317)
Adjustments to reconcile net loss to cash provided by (used in) operating activities:
Depreciation and amortization		995	1,440	1,499
Deferred income tax benefit, net		(947)	(2,430)	(677)
Income tax benefit due to IRS audit resolutions (Note 5)		0	46	(80)
Fees paid for DIP Facility (Note 11) (reported as financing activities)		9	92	0
Impairment of goodwill (Note 4)		2,200	1,600	1,000
Impairment of long-lived assets and nuclear generation joint venture (Note 8)		2,541	4,670	140
Noncash adjustment for estimated allowed claims related to debt (Note 10)		897	0	0
Adjustment to intercompany claims pursuant to settlement agreement (Note 10)		(1,137)	0	0
Contract claims adjustments (Note 10)		54	20	0
Sponsor management agreement settlement (Notes 2 and 18)		(19)	0	0
Unrealized net (gain) loss from mark-to-market of commodity positions		(119)	370	1,091
Unrealized net gain from mark-to-market of interest rate swaps (Note 9)		0	(1,290)	(1,053)
Liability adjustment arising from termination of interest rate swaps (Note 16)		0	277	0
Noncash realized net loss on termination of interest rate swaps (offset in unrealized net gain) (c)	[1]	0	1,225	0
Noncash realized gain on termination of natural gas positions (Note 16)		0	(117)	0
Amortization of debt related costs, discounts, fair value discounts and losses on dedesignated cash flow hedges (Note 9)		0	88	281
Impairment of intangible and other assets (Note 7)		84	263	0
Bad debt expense (Note 20)		34	38	33
Other, net		67	62	94
Changes in operating assets and liabilities:
Affiliate accounts receivable/payable, net		(7)	16	16
Accounts receivable — trade		16	72	(33)
Inventories		34	(67)	(6)
Accounts payable — trade		40	94	(8)
Commodity and other derivative contractual assets and liabilities		27	(27)	47
Margin deposits, net		129	(192)	(320)
Accrued interest		2	493	28
Other — net assets		(22)	(66)	81
Other — net liabilities		(12)	27	(54)
Cash provided by (used in) operating activities		229	437	(271)
Cash flows — financing activities:
Proceeds from the DIP Facility before fees paid (Note 11)		0	1,425	0
Fees paid for the DIP Facility (Note 10)		(9)	(92)	0
Repayments/repurchases of debt (Notes 11 and 12)		(34)	(235)	(105)
Net repayments under accounts receivable securitization program		0	0	(82)
Notes/advances due to affiliates		0	0
Other, net		0	1	13
Cash provided by (used in) financing activities		(43)	1,099	(174)
Cash flows — investing activities:
Capital expenditures		(337)	(336)	(472)
Nuclear fuel purchases		(123)	(77)	(116)
Settlements of notes/advances due from affiliates		(16)	(15)	698
Purchase of right to use certain computer-related assets from parent (Note 18)		0	(4)	(29)
Acquisition of combustion turbine trust interest		0	0	(40)
Changes in restricted cash		(123)	42	2
Proceeds from sales of nuclear decommissioning trust fund securities (Note 19)		401	314	175
Investments in nuclear decommissioning trust fund securities (Note 19)		(418)	(331)	(191)
Other, net		(13)	(32)	(11)
Cash provided by (used in) investing activities		(629)	(439)	16
Net change in cash and cash equivalents		(443)	1,097	(429)
Cash and cash equivalents — beginning balance		1,843	746	1,175
Cash and cash equivalents — ending balance		$ 1,400	$ 1,843	$ 746
[1]	See Note 16.

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 1,400	$ 1,843
Restricted cash (Note 19)	519	2
Trade accounts receivable — net (Note 19)	533	588
Advance to parent (Note 18)	6	8
Inventories (Note 19)	428	468
Commodity and other derivative contractual assets (Note 16)	465	492
Other current assets	71	68
Total current assets	3,422	3,469
Restricted cash (Note 19)	507	901
Advance to parent (Note 18)	18	7
Investments (Note 19)	962	941
Property, plant and equipment — net (Note 19)	9,349	12,288
Goodwill (Note 4)	152	2,352
Identifiable intangible assets — net (Note 4)	1,179	1,336
Other noncurrent assets	39	39
Total assets	15,628	21,333
Current liabilities:
Borrowings under debtor-in-possession credit facility (Note 11)	1,425	0
Long-term debt due currently (Note 11)	31	35
Trade accounts payable	394	382
Trade accounts and other payables to affiliates	119	165
Commodity and other derivative contractual liabilities (Note 16)	203	316
Margin deposits related to commodity contracts	152	26
Accumulated deferred income taxes	0	114
Accrued income taxes payable to parent (Note 18)	10	16
Accrued taxes other than income	98	107
Accrued interest (Notes 9 and 12)	120	117
Other current liabilities	274	264
Total current liabilities	2,826	1,542
Borrowings under debtor-in-possession credit facility (Note 11)	0	1,425
Long-term debt, less amounts due currently (Note 11)	23	85
Liabilities subject to compromise (Note 12)	33,776	34,033
Accumulated deferred income taxes	213	1,022
Other noncurrent liabilities and deferred credits (Note 19)	1,780	1,700
Total liabilities	$ 38,618	$ 39,807
Commitments and Contingencies (Note 13)
Membership interests (Note 14):
Capital account	$ (22,957)	$ (18,439)
Accumulated other comprehensive loss	(33)	(35)
Total membership interests	(22,990)	(18,474)
Total liabilities and membership interests	$ 15,628	$ 21,333

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Long-term debt due currently (Note 11)	$ 31	$ 35
Texas Competitive Electric Holdings Co LLC [Member] | Revolving Credit Facility [Member] | Revolving Credit Facility maturing October 2016 [Member]
Long-term debt due currently (Note 11)		$ 2,054

Statements of Consolidated Equi

Statements of Consolidated Equity - USD ($) $ in Millions		Total	Retained deficit [Member]	Accumulated other comprehensive loss, net of tax effects [Member]	[1]	Stockholders' Equity, Total [Member]	Noncontrolling Interest [Member]	Class A common stock without par value [Member]	Class B common stock without par value [Member]
Balance at beginning of period at Dec. 31, 2012			$ (18,129)	$ (42)			$ 112	$ 383	$ 7,282
Balance at beginning of period at Dec. 31, 2013		$ (12,233)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Change during the period		6		6
Investment in subsidiary by noncontrolling interests							6
Cash distribution to EFH Corp. from predecessor receivables company (Note 19)							(10)
Net loss attributable to noncontrolling interests (Note 8)		107					(107)
Net loss attributable to EFCH		(2,210)	(526)
Effects of stock-based incentive compensation plans		2
Other		1
Net loss attributable to EFCH		(1,684)
Effects of debt push-down from EFH Corp. (Note 12)		4						22	412
Other							0
Capital structure conversion (a)	[2]	(10,556)	18,655					(405)	(7,694)
Balance at end of period at Dec. 31, 2013		(12,268)	0	(36)		$ (12,269)	1	0	0
Balance at end of period at Dec. 31, 2012		0
Balance at beginning of period at Dec. 31, 2014		(18,439)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Change during the period		1		1
Investment in subsidiary by noncontrolling interests							1
Cash distribution to EFH Corp. from predecessor receivables company (Note 19)							0
Net loss attributable to noncontrolling interests (Note 8)		0					0
Net loss attributable to EFCH		(6,229)	0
Effects of stock-based incentive compensation plans		2
Other		0
Net loss attributable to EFCH		(6,229)
Effects of debt push-down from EFH Corp. (Note 12)		21						0	0
Other							(2)
Capital structure conversion (a)	[2]	0	0					0	0
Balance at end of period at Dec. 31, 2014		(18,474)	0	(35)		(18,474)	0	0	0
Balance at end of period at Dec. 31, 2013		(12,233)
Balance at beginning of period at Dec. 31, 2015		(22,957)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Change during the period		2		2
Investment in subsidiary by noncontrolling interests							0
Cash distribution to EFH Corp. from predecessor receivables company (Note 19)							0
Net loss attributable to noncontrolling interests (Note 8)		0					0
Net loss attributable to EFCH		(4,603)	0
Effects of stock-based incentive compensation plans		0
Other		0
Net loss attributable to EFCH		(4,603)
Effects of debt push-down from EFH Corp. (Note 12)		85						0	0
Other							0
Capital structure conversion (a)	[2]	0	0					0	0
Balance at end of period at Dec. 31, 2015		(22,990)	$ 0	$ (33)		$ (22,990)	$ 0	$ 0	$ 0
Balance at end of period at Dec. 31, 2014		$ (18,439)
[1]	All amounts relate to cash flow hedges.
[2]	In 2013, EFCH was converted from a Texas corporation into a Delaware limited liability company in accordance with an IRS private letter ruling.

Business And Significant Accoun

Business And Significant Accounting Policies	12 Months Ended
	Dec. 31, 2015
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 wholly owned subsidiary of EFH Corp., is a Dallas, Texas-based holding company. In April 2013, EFCH was converted from a Texas corporation to a Delaware limited liability company. The conversion did not result in a change in the management, assets, businesses or operations of EFCH. 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 trading activities 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. Chapter 11 Cases 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). In September 2015, the Debtors filed the Fifth Plan of Reorganization (which was amended by the Sixth Plan of Reorganization in November 2015) and the Disclosure Statement. The Disclosure Statement was approved by the Bankruptcy Court in September 2015. Following the approval of the Disclosure Statement by the Bankruptcy Court, the Debtors solicited the vote of their required creditors for approval of the Plan of Reorganization. In October 2015, the required creditors voted to approve the Plan of Reorganization. The Bankruptcy Court confirmed the Plan of Reorganization in December 2015. 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 consolidated financial statements have been prepared in accordance with US GAAP. The 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 consolidated financial statements reflect the application of Financial Accounting Standards Board Accounting Standards Codification (ASC) 852, Reorganizations . 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 10 and 12 for discussion of these accounting and reporting changes. All intercompany items and transactions have been eliminated in consolidation. 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. Derivative Instruments and Mark-to-Market Accounting We enter into contracts for the purchase and sale of electricity, natural gas, coal, uranium and other commodities and also enter into other derivative instruments such as options, swaps, futures and forwards primarily to manage our commodity price and interest rate risks. If the instrument meets the definition of a derivative under accounting standards related to derivative instruments and hedging activities, changes in the fair value of the derivative are recognized in net income as unrealized gains and losses, unless the criteria for certain exceptions are met, and an offsetting derivative asset or liability is recorded in the consolidated balance sheets. This recognition is referred to as mark-to-market accounting. The fair values of our unsettled derivative instruments under mark-to-market accounting are reported in the consolidated balance sheets as commodity and other derivative contractual assets or liabilities. We report derivative assets and liabilities in the consolidated balance sheets without taking into consideration netting arrangements we have with counterparties. Margin deposits that contractually offset these assets and liabilities are reported separately in the consolidated balance sheets. When derivative instruments are settled and realized gains and losses are recorded, the previously recorded unrealized gains and losses and derivative assets and liabilities are reversed. See Notes 15 and 16 for additional information regarding fair value measurement and commodity and other derivative contractual assets and liabilities. Under the election criteria of accounting standards related to derivative instruments and hedging activities, we may elect the normal purchase and sale exemption. A commodity-related derivative contract may be designated as a normal purchase or sale if the commodity is to be physically received or delivered for use or sale in the normal course of business. If designated as normal, the derivative contract is accounted for under the accrual method of accounting (not marked-to-market) with no balance sheet or income statement recognition of the contract until settlement. Because derivative instruments are frequently used as economic hedges, accounting standards related to derivative instruments and hedging activities allow for hedge accounting, which provides for the designation of such instruments as cash flow or fair value hedges if certain conditions are met. At December 31, 2015 and 2014, there were no derivative positions accounted for as cash flow or fair value hedges. Accumulated other comprehensive loss includes amounts related to interest rate swaps previously designated as cash flow hedges that are being reclassified to net loss as the hedged transactions impact net loss (see Note 16). Realized and unrealized gains and losses from transacting in energy-related derivative instruments are primarily reported in the statements of consolidated income (loss) in net gain (loss) from commodity hedging and trading activities. Revenue Recognition We record revenue from electricity sales under the accrual method of accounting. Revenues are recognized when electricity is provided to customers on the basis of periodic cycle meter readings and include an estimated accrual for the revenues earned from the meter reading date to the end of the period (unbilled revenue). We report physically delivered commodity sales and purchases in the statements of consolidated income (loss) on a gross basis in revenues and fuel, purchased power and delivery fees, respectively, and we report all other commodity related contracts and financial instruments (primarily derivatives) in the statements of consolidated income (loss) on a net basis in net gain (loss) from commodity hedging and trading activities. Volumes under bilateral purchase and sales contracts, including contracts intended as hedges, are not scheduled as physical power with ERCOT. Accordingly, unless the volumes represent physical deliveries to customers or purchases from counterparties, such contracts are reported net in the statements of consolidated income (loss) in net gain (loss) from commodity hedging and trading activities instead of reported gross as wholesale revenues or purchased power costs. If volumes delivered to our retail and wholesale customers are less than our generation volumes (as determined on a daily settlement basis), we record additional wholesale revenues, and if volumes delivered to our retail and wholesale customers exceed our generation volumes, we record additional purchased power costs. The additional wholesale revenues or purchased power costs are offset in net gain (loss) from commodity hedging and trading activities. Impairment of Long-Lived Assets We evaluate long-lived assets (including intangible assets with finite lives) for impairment whenever indications of impairment exist. The carrying value of such assets is deemed to be impaired if the projected undiscounted cash flows are less than the carrying value. If there is such impairment, a loss would be recognized based on the amount by which the carrying value exceeds the fair value. Fair value is determined primarily by discounted cash flows, supported by available market valuations, if applicable. See Note 8 for discussion of impairments of certain long-lived assets. Finite-lived intangibles identified as a result of purchase accounting are amortized over their estimated useful lives based on the expected realization of economic effects. See Note 4 for additional information. Goodwill and Intangible Assets with Indefinite Lives We evaluate goodwill and intangible assets with indefinite lives for impairment at least annually (at December 1), or when indications of impairment exist. See Note 4 for details of goodwill and intangible assets with indefinite lives, including discussion of fair value determinations and goodwill impairments. Amortization of Nuclear Fuel Amortization of nuclear fuel is calculated on the units-of-production method and is reported as fuel costs. Major Maintenance Major maintenance costs incurred during generation plant outages and the costs of other maintenance activities are charged to expense as incurred and reported as operating costs. Defined Benefit Pension Plans and OPEB Plans We bear a portion of the costs of the EFH Corp. sponsored pension and OPEB plans offering certain health care and life insurance benefits to eligible employees and their eligible dependents upon the retirement of such employees from the company and also offer pension benefits to eligible employees under collective bargaining agreements based on either a traditional defined benefit formula or a cash balance formula. Costs of pension and OPEB plans are dependent upon numerous factors, assumptions and estimates. Under multiemployer plan accounting, EFH Corp. has elected to not allocate retirement plan assets and liabilities to us. See Note 17 for additional information regarding pension and OPEB plans. Sales and Excise Taxes Sales and excise taxes are accounted for as a "pass through" item on the consolidated balance sheets with no effect on the statements of consolidated income (loss); i.e., the tax is billed to customers and recorded as trade accounts receivable with an offsetting amount recorded as a liability to the taxing jurisdiction. Franchise and Revenue-Based Taxes Unlike sales and excise taxes, franchise and gross receipt taxes are not a "pass through" item. These taxes are assessed to us by state and local government bodies, based on revenues or kWh delivered, as a cost of doing business and are recorded as an expense. Rates we charge to customers are intended to recover our costs, including the franchise and gross receipt taxes, but we are not acting as an agent to collect the taxes from customers. We report franchise and revenue-based taxes in SG&A expense in our statements of consolidated income (loss). Income Taxes EFH Corp. files a consolidated US federal income tax return that includes the results of EFCH and TCEH; however, our income tax expense and related balance sheet amounts are recorded as if we file separate corporate income tax returns. Deferred income taxes are provided for temporary differences between the book and tax basis of assets and liabilities as required under accounting rules. See Note 6. We report interest and penalties related to uncertain tax positions as current income tax expense. See Note 5. Accounting for Contingencies Our financial results may be affected by judgments and estimates related to loss contingencies. Accruals for loss contingencies are recorded when management determines that it is probable that an asset has been impaired or a liability has been incurred and that such economic loss can be reasonably estimated. Such determinations are subject to interpretations of current facts and circumstances, forecasts of future events and estimates of the financial impacts of such events. As part of our Chapter 11 Cases we have received numerous pre-petition claims, many of which are unsubstantiated or irrelevant to our business operations. Further, at this time, some of those claims might be relevant but are not reasonably estimable. See Notes 2 and 13 for a discussion of contingencies. Restricted Cash The terms of certain agreements require the restriction of cash for specific purposes. See Notes 11, 12 and 19 for more details regarding restricted cash. Property, Plant and Equipment As a result of purchase accounting, carrying amounts of property, plant and equipment were adjusted to estimated fair values at the Merger date. Subsequent additions have been recorded at cost. The cost of self-constructed property additions includes materials and both direct and indirect labor and applicable overhead, including payroll-related costs. Interest related to qualifying construction projects and qualifying software projects is capitalized in accordance with accounting guidance related to capitalization of interest cost. See Note 9. Depreciation of our property, plant and equipment is calculated on a straight-line basis over the estimated service lives of the properties. Depreciation expense is calculated on a component asset-by-asset basis. Estimated depreciable lives are based on management's estimates of the assets' economic useful lives. See Note 19. Asset Retirement Obligations A liability is initially recorded at fair value for an asset retirement obligation associated with the retirement of tangible long-lived assets in the period in which it is incurred if a fair value is reasonably estimable. 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. Over time, the liability is accreted for the change in present value and the initial capitalized costs are depreciated over the remaining useful lives of the assets. See Note 19. Inventories Inventories are reported at the lower of cost (on a weighted average basis) or market unless expected to be used in the generation of electricity. Investments Investments in a nuclear decommissioning trust fund are carried at current market value in the consolidated balance sheets. Assets related to employee benefit plans represent investments held to satisfy deferred compensation liabilities and are recorded at current market value. See Note 19 for discussion of these and other investments. Noncontrolling Interests See Notes 8 and 14 for discussion of accounting for noncontrolling interests in subsidiaries. Push-Down of EFH Corp. Debt In accordance with SEC Staff Accounting Bulletin (SAB) Topic 5-J, we reflect amounts of certain EFH Corp. senior notes on our balance sheets and the related interest expense in our income statement. The amount reflected on our balance sheet was calculated based upon the relative equity investment of EFCH and EFIH in their respective operating subsidiaries at the time of the Merger (see Note 12). Changes in Accounting Standards In April 2014, the FASB issued Accounting Standards Update No. 2014-08 (ASU 2014-08), Presentation of Financial Statements (Topic 205) and Property Plant, and Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity , which changes the requirements for reporting discontinued operations. The ASU states that a disposal of a component of an entity or a group of components of an entity is required to be reported in discontinued operations if the disposal represents a strategic shift that has or will have a major effect on an entity's operations and financial results when the component of an entity or group of components of an entity meets the criteria to be classified as held for sale, is disposed of by sale, or is disposed of other than by sale. The amendments in this ASU also require additional disclosures about discontinued operations. ASU 2014-08 is effective for the Company for the first quarter of 2015. This new requirement is relevant to our presentation of TCEH. Based on our analysis, ASU 2014-08 will not materially affect our results of operations, financial position, or cash flows, unless a spin-off of TCEH is approved by each of the Bankruptcy Court and all of the other regulatory entities with approval authority (see Note 2), at which time presentation as discontinued operations may be appropriate. In April 2015, the FASB issued Accounting Standards Update 2015-03 (ASU 2015-03), Simplifying Balance Sheet Presentation by Presenting Debt Issuance Costs as a Deduction from Recognized Debt Liability. The ASU is effective for annual reporting periods, including interim reporting periods, beginning after December 15, 2015. The new standard requires debt issuance costs to be classified as reductions to the face value of the related debt. We do not expect ASU 2015-03 to materially affect our financial position until we issue new debt. In August 2015, the FASB issued Accounting Standards Update 2015-15 (ASU 2015-15), Interest-Imputation of Interest (Topic 835-30) Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line of Credit Arrangements . ASU 2015-15 provides guidance on the presentation of debt issuance costs associated with line-of-credit arrangements and allows an entity to defer and present debt issuance costs as an asset and subsequently amortize the deferred debt issuance costs ratably over the term of the line-of-credit. In November 2015, the FASB issued Accounting Standards Update 2015-17 (ASU 2015-17), Balance Sheet Classification of Deferred Taxes . The ASU simplifies the presentation of deferred income taxes by requiring that deferred tax assets and liabilities be classified as noncurrent in a statement of financial position. We early adopted ASU 2015-17 effective December 31, 2015 on a prospective basis. Adoption of this ASU resulted in a reclassification of our net current deferred tax asset and liability to the net noncurrent deferred tax asset and liability in our consolidated balance sheet as of December 31, 2015. No prior periods were retrospectively adjusted. In February 2016, the FASB issued Accounting Standards Update 2016-2 (ASU 2016-2), 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. We are currently evaluating the impact of this ASU on our financial statements.

Chapter 11 Cases

Chapter 11 Cases	12 Months Ended
	Dec. 31, 2015
Reorganizations [Abstract]
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. The Bankruptcy Filing resulted primarily from the adverse effects on EFH Corp.'s competitive businesses of lower wholesale electricity prices in ERCOT driven by the sustained decline in natural gas prices since mid-2008. Further, the natural gas hedges that TCEH entered into when forward market prices of natural gas were significantly higher than current prices had largely matured before the remaining positions were terminated shortly after the Bankruptcy Filing. These market conditions challenged the profitability and operating cash flows of EFH Corp.'s competitive businesses and resulted in the inability to support their significant interest payments and debt maturities, including the remaining debt obligations due in 2014, and the inability to refinance and/or extend the maturities of their outstanding debt. Plan of Reorganization A Chapter 11 plan of reorganization, among other things, determines the rights and satisfaction of claims of various creditors and security holders of an entity operating under the protection of the Bankruptcy Court. In order for the Debtors to emerge successfully from the Chapter 11 Cases as reorganized companies, they must obtain approval from the Bankruptcy Court and certain of their respective creditors for a Chapter 11 plan of reorganization. In September 2015, the Debtors filed the Plan of Reorganization and the Disclosure Statement. The Disclosure Statement was approved by the Bankruptcy Court in September 2015. In October 2015, the Debtors filed the Plan Supplement. In October 2015, the Plan of Reorganization was approved by the required creditors, and in December 2015, the Plan of Reorganization was confirmed by the Bankruptcy Court. In general, the Plan of Reorganization contemplates a structure that involves a tax-free deconsolidation or tax-free spin-off of TCEH from EFH Corp. (Reorganized TCEH Spin-Off), immediately followed by the acquisition of reorganized EFH Corp. financed by existing TCEH creditors and third-party investors. Pursuant to the Plan of Reorganization and subject to certain conditions and required regulatory approvals, among other things: • TCEH will execute a transaction that will result in a partial step-up in the tax basis of certain TCEH assets; • the Reorganized TCEH Spin-Off will occur; • a consortium (collectively, the Investor Group) consisting of certain TCEH creditors, an affiliate of Hunt Consolidated, Inc. (Hunt) and certain other investors designated by Hunt will acquire (the EFH Acquisition) reorganized EFH Corp. (Reorganized EFH); • in connection with the EFH Acquisition, (i) the Investor Group will raise up to approximately $12.6 billion of equity and debt financing to invest in Reorganized EFH, (ii) a successor to Reorganized EFH will be converted to a real estate investment trust (REIT) under the Internal Revenue Code and (iii) all allowed claims against the EFH Corp. Debtors and the EFIH Debtors will receive treatment rendering them unimpaired (excluding any claims derived from or based upon make-whole, applicable premium, redemption premium or other similar payment provisions, or any other alleged premiums, fees, or claims relating to the repayment of claims and certain unsecured claims for post-petition interest in excess of the federal judgment rate of interest, each of which will be disallowed under the Plan of Reorganization), and • the Debtors, the Sponsor Group, certain settling TCEH first lien creditors, certain settling TCEH second lien creditors, certain settling TCEH unsecured creditors and the official committee of unsecured creditors of the TCEH Debtors (collectively, the Settling Parties) agreed to settle certain disputes, claims and causes of action pursuant to the Settlement Agreement (described below). Plan Support Agreement In August 2015 (as amended in September 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 unsecured creditors of the TCEH Debtors and the Investor Group in order to effect an agreed upon restructuring of the Debtors pursuant to the Plan of Reorganization. Pursuant to the Plan Support Agreement, the parties agreed, subject to the terms and conditions contained in the Plan Support Agreement, to support the Debtors' Plan of Reorganization. The Bankruptcy Court approved the Debtors' entry into the Plan Support Agreement in September 2015. Pursuant to the Plan Support Agreement, certain of the parties to the Plan Support Agreement are required to not object to or interfere with an alternative plan of reorganization even if the EFH Acquisition is not completed so long as such plan meets certain minimum conditions. All or part of the Plan Support Agreement 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 an alternative 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 is expected to remain effective regardless of whether the EFH Acquisition is completed. The Bankruptcy Court approved the Settlement Agreement in December 2015. In December 2015, pursuant to the approved Settlement Agreement, Backstop Agreement, Merger Agreement and Plan of Reorganization, EFH Corp. recorded legal and representation service fees, financial advisory fees and other professional fees of $144 million , along with a gain for an adjustment related to the Sponsor Group's agreement to forego claims related to a management agreement of $86 million . Additionally, we recorded an adjustment to intercompany claims among the Debtors to adjust for a TCEH unsecured claim against EFH Corp. of $700 million as contemplated by the Plan of Reorganization. See Notes 12 and 18 for discussion of additional transactions resulting from the Settlement Agreement. 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. (collectively, the Purchasers), which are controlled by the Investor Group. Pursuant to the Merger and Purchase Agreement, at the effective time of the Plan of Reorganization and immediately after consummation of the Reorganized TCEH Spin-Off, the Investor Group will acquire Reorganized EFH. The Merger and Purchase Agreement contemplates that funds received by the Purchasers pursuant to the Equity Commitment Letter, the Debt Commitment Letter and the Rights Offering and Backstop (each as defined below) will be used to facilitate the acquisition of Reorganized EFH and, as applicable, repay the allowed claims of holders of claims and interests in EFH Corp. and EFIH in full in cash (or otherwise render such claims unimpaired) pursuant to the Plan of Reorganization and, if applicable, to complete the Texas Transmission Acquisition (as defined below). The Merger and Purchase Agreement includes various conditions precedent to consummation of the transactions contemplated thereby, including a condition that certain approvals and rulings be obtained, including from the PUCT and the IRS, that are necessary to consummate the EFH Acquisition and convert Reorganized EFH into a REIT. The Merger and Purchase Agreement may be terminated upon certain events, including, among other things, (a) by either party, if certain termination events occur under the Plan Support Agreement, including if the EFH Acquisition is not completed by April 30, 2016, subject to extension to June 30, 2016 or August 31, 2016 under certain conditions, (b) by EFH Corp. or EFIH, if their respective board of directors or managers determines in good faith that proceeding with the transactions contemplated by the Merger and Purchase Agreement would be inconsistent with its applicable fiduciary duties or (c) by the Purchasers, if EFH Corp. or EFIH fails to meet various milestones related to the Debtors' Chapter 11 Cases or otherwise materially breaches the Merger and Purchase Agreement. The Bankruptcy Court approved the Merger and Purchase Agreement in connection with confirmation of the Plan of Reorganization in December 2015. Rights Offering As contemplated by the Plan of Reorganization, OV1 intends to conduct an offering of equity rights (each, a Right, and such offering, the Rights Offering) to holders of unsecured debt claims, second lien debt claims, general unsecured claims and first lien secured claims against TCEH (Rights Offering Participants) enabling the Rights Offering Participants to purchase an aggregate of $5.787 billion of common stock of OV1 (as the successor by merger of Reorganized EFH). This annual report on Form 10-K does not constitute an offer to sell, or a solicitation of an offer to purchase, the Rights. Pursuant to a Backstop Agreement (Backstop Agreement), among certain investors named therein and their permitted assignees (Backstop Purchasers), EFH Corp., EFIH and OV1, the Backstop Purchasers have agreed to backstop $5.087 billion of Rights offered to certain of the Rights Offering Participants (Backstop). In connection with the execution of the Merger and Purchase Agreement, each member of the Investor Group (collectively, the Equity Commitment Parties) delivered (a) an equity commitment letter (Equity Commitment Letter) in favor of EFH Corp. (including Reorganized EFH), EFIH and the Purchasers pursuant to which the Equity Commitment Parties committed to invest in one or more of the Purchasers an aggregate amount of approximately $2.513 billion (assuming the Texas Transmission Acquisition (as described below) is completed) and (b) a limited guarantee (Guarantee) in favor of EFH Corp. (including Reorganized EFH) and EFIH pursuant to which each such Equity Commitment Party committed to pay its pro rata share of all fees, costs or expenses payable by the Purchasers under the Merger and Purchase Agreement or under the Plan of Reorganization if such fees, costs or expenses become payable pursuant thereto. The aggregate liability of the Equity Commitment Parties under the Guarantee for fees and expenses is capped at $35 million . If the Merger and Purchase Agreement, the Backstop Agreement or the Equity Commitment Letter are terminated for any reason, EFH Corp. and EFIH have waived their rights to seek any legal or equitable remedies, except in connection with the reimbursement of certain fees and expenses capped at $35 million , against the Purchasers or the Investor Group, the Backstop Purchasers or the Equity Commitment Parties, respectively. In December 2015, pursuant to the court approved Merger and Purchase Agreement and the Backstop Agreement, EFH Corp. incurred approximately $49 million in fees to the Purchasers for expenses incurred in connection with those agreements. Debt Funding Arrangements In August 2015, in connection with the execution of the Merger and Purchase Agreement, the Investor Group entered into a commitment letter (Debt Commitment Letter) with Morgan Stanley Senior Funding, Inc. (Debt Commitment Lender) pursuant to which the Debt Commitment Lender committed to fund up to $5.5 billion under a senior secured term loan facility and $250 million under a senior secured bridge loan facility to reorganized EFIH and its subsidiaries at the closing of the EFH Acquisition. Texas Transmission Acquisition In connection with the EFH Acquisition and the Rights Offering, the Purchasers, EFH Corp. and EFIH have formulated a plan to create and implement an IPO Conversion (as such term is defined in the Investor Rights Agreement (Investor Rights Agreement), dated November 2008 among Oncor and certain of its direct and indirect equity holders, including EFH Corp. and Texas Transmission, pursuant to which one of the Purchasers, as the successor to Reorganized EFH as a result of the EFH Acquisition, would serve as an IPO corporation (as defined in the Investor Rights Agreement). In connection with the execution of the Merger and Purchase Agreement, the Purchasers have delivered to EFH Corp. an offer to purchase substantially all of the outstanding IPO Units (as defined in the Investor Rights Agreement) in the IPO corporation and all of the LLC Units (as defined in the Investor Rights Agreement) in Oncor held by Texas Transmission (the Texas Transmission Acquisition). EFH Corp. has instituted an adversary proceeding in the Bankruptcy Court to enforce certain rights against Texas Transmission under the Investor Rights Agreement. Other Although the Plan of Reorganization has been confirmed by the Bankruptcy Court, the effective date of the Plan of Reorganization has not occurred and there are no assurances that the transactions contemplated thereby will occur because they are subject to completion of various conditions including, but not limited to, receipt of regulatory approval from the PUCT, NRC and FERC, receipt of the Private Letter Ruling from the IRS and the repayment of the DIP Facility. 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 (A) 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 and (B) certain rulings regarding the eligibility of EFH Corp. to qualify as a REIT for federal income tax purposes. 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 11, our ability to obtain new debtor in possession financing in the event the DIP Facility was to expire during the pendency of the Chapter 11 Cases as well as our ability to obtain applicable regulatory approvals required for the effectiveness of the Plan of Reorganization and our ability to obtain any exit financing needed to implement the Plan of Reorganization. These circumstances and uncertainties inherent in the bankruptcy proceedings raise substantial doubt about our ability to continue as a going concern. Operations During the Chapter 11 Cases In general, the Debtors have received final bankruptcy court orders with respect to first day motions and other operating motions that allow the Debtors to operate their businesses in the ordinary course, including, among others, providing for the payment of certain pre-petition employee and retiree expenses and benefits, the use of the Debtors' existing cash management system, the segregation of certain cash balances which require further order of the Bankruptcy Court for distribution, the continuation of customer contracts and programs at our retail electricity operations, the payment of certain pre-petition amounts to certain critical vendors, the ability to perform under certain pre-petition hedging and trading arrangements and the ability to pay certain pre-petition taxes and regulatory fees. In addition, the Bankruptcy Court has issued orders approving the DIP Facility discussed in Note 11. Pursuant to the Bankruptcy Code, the Debtors intend to comply with all applicable regulatory requirements, including all requirements related to environmental and safety law compliance, during the pendency of the Chapter 11 Cases. Further, the Debtors have been complying, and intend to continue to comply, with the various reporting obligations that are required by the Bankruptcy Court during the pendency of the Chapter 11 Cases. Moreover, to the extent the Debtors either maintain insurance policies or self-insure their regulatory compliance obligations, the Debtors intend to continue such insurance policies or self-insurance in the ordinary course of business. 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. The Debtors have received approximately 41,300 filed claims since the Petition Date, including approximately 30,900 in filed asbestos claims. Most of the asbestos claims were received at or near the bar date and we are actively validating, reconciling and reviewing those claims. For all of the claims, the Debtors are in the process of reconciling those claims to the amounts listed in our schedules of assets and liabilities, which includes communications with claimants to acquire additional information required for reconciliation. As of February 29, 2016, approximately 5,500 of those claims have been settled, withdrawn or expunged. To the extent claims are reconciled and resolved, we have recorded them at the expected allowed amount. Certain claims filed or reflected in our 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. In November 2014, we began the process to request the Bankruptcy Court to disallow claims that we believe are duplicative, have been later amended or superseded, are without merit, are overstated or should be disallowed for other reasons. Given the substantial number of claims filed, the claims resolution process will take considerable time to complete. Differences between liability amounts recorded by the Debtors as liabilities subject to compromise and claims filed by creditors will be investigated and, if necessary, the Bankruptcy Court will make a final determination of the allowable claim. Differences between those final allowed claims and the liabilities recorded in the consolidated balance sheets will be recognized as reorganization items in our statements of consolidated income (loss) as they are resolved. The determination of how liabilities will ultimately be resolved cannot be made until a plan of reorganization or a court approved order related to settlement of specific liabilities becomes effective. Accordingly, the ultimate amount or resolution of such liabilities is not determinable at this time. The resolution of such claims could result in material adjustments to our financial statements. Executory Contracts and Unexpired Leases Under the Bankruptcy Code, we have the right to assume, assign, or reject certain executory contracts and unexpired leases, subject to the approval of the Bankruptcy Court and certain other conditions. Generally, the assumption of an executory contract or unexpired lease requires a debtor to satisfy pre-petition obligations under contracts, which may include payment of pre-petition liabilities in whole or in part. Rejection of an executory contract or unexpired lease is typically treated as a breach occurring as of the moment immediately preceding the Chapter 11 filing. Subject to certain exceptions, this rejection relieves the debtor from performing its future obligations under the contract but entitles the counterparty to assert a pre-petition general unsecured claim for damages. Parties to executory contracts or unexpired leases rejected by a debtor may file proofs of claim against that debtor's estate for rejection damages. Since the Petition Date we have renegotiated or rejected a limited number of executory contracts and unexpired leases. For the years ended December 31, 2015 and 2014 this activity has resulted in the recognition of approximately $40 million and $20 million , respectively, in contract claim and assumption adjustments recorded in reorganization items as detailed in Note 10. The Plan Supplement includes a list of contracts that the Debtors intend to either assume or reject pursuant to the Bankruptcy Code.

Pending Purchase of La Frontera

Pending Purchase of La Frontera Holdings, LLC (Notes)	12 Months Ended
	Dec. 31, 2015
Business Combinations [Abstract]
Business Combination Disclosure [Text Block]	PENDING PURCHASE OF LA FRONTERA HOLDINGS, LLC In November 2015, Luminant entered into a purchase and sale agreement with La Frontera Ventures, LLC, a subsidiary of NextEra Energy, Inc., to purchase all of the membership interests in La Frontera Holdings, LLC, the indirect owner of two natural gas fueled generation facilities totaling 2,988 MW of capacity located in ERCOT. The aggregate purchase price under the agreement is approximately $1.313 billion plus approximately $276 million for cash and net working capital, subject to customary adjustments based on the amounts of cash and net working capital at closing. The existing project financing of La Frontera Holdings, LLC and its subsidiaries will be repaid at closing of the transaction. The purchase price is expected be funded by cash-on-hand and borrowings under the DIP Facility. The purchase and sale agreement contains customary closing conditions for transactions of this type. The only remaining regulatory approval necessary to complete the acquisition is approval by the PUCT.

Goodwill And Identifiable Intan

Goodwill And Identifiable Intangible Assets	12 Months Ended
	Dec. 31, 2015
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 through 2014 (15,970 ) Balance at December 31, 2014 2,352 Additional noncash impairment charges in 2015 (2,200 ) Balance at December 31, 2015 (a) $ 152 ___________ (a) Net of accumulated impairment charges totaling $18.170 billion . 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. We perform the following steps in testing goodwill for impairment: first, we estimate the debt-free enterprise value of the business as of the testing date taking into account future estimated cash flows and current securities values of comparable companies; second, we estimate the fair values of the individual assets and liabilities of the business at that date; third, we calculate implied goodwill as the excess of the estimated enterprise value over the estimated value of the net operating assets; and finally, we compare the implied goodwill amount to the carrying value of goodwill and, if the carrying amount exceeds the implied value, we record an impairment charge for the amount the carrying value of goodwill exceeds implied goodwill. Wholesale electricity prices in the ERCOT market, in which TCEH largely operates, have generally moved with natural gas prices as marginal electricity demand is generally supplied by natural gas fueled generation facilities. Accordingly, the sustained decline in natural gas prices, which we have experienced since mid-2008, negatively impacts our profitability and cash flows and reduces the value of our generation assets, which consist largely of lignite/coal and nuclear fueled facilities. While we had partially mitigated these effects with hedging activities, we are now significantly exposed to this price risk. Because of this market condition, our analyses over the past several years have indicated that the carrying value of TCEH exceeds its estimated fair value (enterprise value). Consequently, we continually monitor trends in electricity prices, natural gas prices, market heat rates, capital spending for environmental and other projects and other operational factors to determine if goodwill impairment testing should be done during the course of a year and not only at the annual December 1 testing date. During the fourth quarter of 2015, we performed our goodwill impairment analysis as of our annual testing date of December 1. Further, during the fourth quarter of 2015, there were significant declines in the market values of several similarly situated peer companies with publicly traded equity, which indicated our overall enterprise value should be reassessed. Our testing resulted in an impairment of goodwill of $800 million at December 1, 2015. During the first nine months of 2015, we experienced impairment indicators 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 during the first nine months of 2015 resulted in impairment charges totaling $1.4 billion . Key inputs into our goodwill impairment testing at December 1, September 30 and March 31, 2015 and December 1, 2014 were as follows: • The carrying value (excluding debt) of TCEH exceeded its estimated enterprise value by approximately 48% at December 1, 2015 and 17% at December 1, 2014. • The fair value of TCEH was estimated using a two-thirds weighting of value based on internally developed cash flow projections and a one-third weighting of value using implied cash flow multiples based on current securities values of comparable publicly traded companies. The internally developed cash flow projections reflect annual estimates through a terminal year calculated using a terminal year EBITDA multiple approach. • The discount rates applied to internally developed cash flow projections were 6.00% for the impairments recorded in 2015 and 6.25% at December 1, 2014. The discount rate represents the weighted average cost of capital consistent with our views of the rate that an expected market participant would utilize for valuation, including the risk inherent in future cash flows, taking into account the capital structure, debt ratings and current debt yields of comparable public companies as well as an estimate of return on equity that reflects historical market returns and current market volatility for the industry. • The cash flow projections used in both 2015 and 2014 assume rising wholesale electricity prices, although the forecasted electricity prices are less than those assumed in the cash flow projections used in prior goodwill impairment testing. Changes in the above and other assumptions could materially affect the calculated amount of implied goodwill and any resulting goodwill impairment charge. During the third quarter of 2014, we experienced an impairment indicator related to significant decreases in forward wholesale electricity prices when compared to those prices reflected in our December 1, 2013 goodwill impairment testing analysis. As a result, the likelihood of a goodwill impairment had increased, and we initiated further testing of goodwill as of September 30, 2014, which was completed during the fourth quarter. Our testing resulted in an impairment of $ 1.6 billion of goodwill at September 30, 2014, which we recorded in the fourth quarter of 2014. During the fourth quarter of 2014, we also performed our goodwill impairment analysis as of our annual testing date of December 1. During the fourth quarter of 2014, we completed our annual update of our long-range financial and operating plan, which reflected extended seasonal outages and reduced operations at several of our older lignite/coal fueled generation facilities as a result of the lower wholesale electricity prices and potential impacts to those facilities from proposed environmental regulations. The resulting impairment charge recorded on our long-lived assets was factored into our December 1 goodwill impairment test. Our testing did not result in an additional impairment of goodwill at December 1, 2014. During the fourth quarter of 2013, we recorded a $1.0 billion goodwill impairment charge. The impairment charge in 2013 reflected declines in our estimated fair value as a result of lower wholesale electricity prices, the sustained decline in natural gas prices, the maturing of positions in our natural gas hedge program and declines in market values of securities of comparable companies. The impairment determinations involved significant assumptions and judgments. The calculations supporting the estimates of the fair value of our business and the fair values of its assets and liabilities utilized models that take into consideration multiple inputs, including commodity prices, operating parameters, discount rates, capital expenditures, the effects of proposed and final environmental regulations, securities prices of comparable publicly traded companies and other inputs. Assumptions regarding each of these inputs could have a significant effect on the related valuations. In performing these calculations, we also take into consideration assumptions on how current market participants would value TCEH and its operating assets and liabilities. Changes to assumptions that reflect the views of current market participants can also have a significant effect on the related valuations. The fair value measurements resulting from these models are classified as non-recurring Level 3 measurements consistent with accounting standards related to the determination of fair value (see Note 15). Because of the volatility of these factors, we cannot predict the likelihood of any future impairment. Identifiable Intangible Assets Identifiable intangible assets, including amounts that arose in connection with accounting for the Merger, are comprised of the following: December 31, 2015 December 31, 2014 Identifiable Intangible Asset Gross Carrying Amount Accumulated Amortization Net Gross Carrying Amount Accumulated Amortization Net Retail customer relationship $ 463 $ 442 $ 21 $ 463 $ 425 $ 38 Software and other technology-related assets 385 224 161 369 202 167 Other identifiable intangible assets (a) 72 35 37 460 291 169 Total identifiable intangible assets subject to amortization $ 920 $ 701 219 $ 1,292 $ 918 374 Retail trade name (not subject to amortization) 955 955 Mineral interests (not currently subject to amortization) 5 7 Total identifiable intangible assets $ 1,179 $ 1,336 ____________ (a) Includes favorable purchase and sales contracts, environmental allowances and credits and mining development costs. See discussion below regarding impairment charges recorded in 2014 and 2015 related to other identifiable intangible assets. At December 31, 2015 and 2014, 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 statements of consolidated income (loss) line item) consisted of: Identifiable Intangible Asset Statements of Consolidated Income (Loss) Line Remaining useful lives at December 31, 2015 (weighted average in years) Year Ended December 31, 2015 2014 2013 Retail customer relationship Depreciation and amortization 2 $ 17 $ 23 $ 24 Software and other technology-related assets Depreciation and amortization 3 60 59 47 Other identifiable intangible assets Operating revenues/fuel, purchased power costs and delivery fees/depreciation and amortization 8 30 88 69 Total amortization expense (a) $ 107 $ 170 $ 140 ____________ (a) Amounts recorded in depreciation and amortization totaled $85 million , $116 million and $102 million in 2015, 2014 and 2013, respectively. Following is a description of the separately identifiable intangible assets recorded as part of purchase accounting for the Merger. The intangible assets were recorded at estimated fair value as of the Merger date, based on observable prices or estimates of fair value using valuation models. • Retail customer relationship – Retail customer relationship intangible asset represents the fair value of the non-contracted customer base and is being amortized using an accelerated method based on customer attrition rates and reflecting the expected pattern in which economic benefits are realized over their estimated useful life. • Retail trade name – The trade name intangible asset represents the fair value of the TXU Energy trade name, and was determined to be an indefinite-lived asset not subject to amortization. This intangible asset is evaluated for impairment at least annually in accordance with accounting guidance related to goodwill and other intangible assets. Significant assumptions included within the development of the fair value estimate include TXU Energy's estimated gross margin for future periods and an implied royalty rate. No impairment was recorded as a result of our 2015 analysis. • Favorable purchase and sales contracts – Favorable purchase and sales contracts intangible asset primarily represents the above market value of commodity contracts for which: (i) we had made the normal purchase or sale election allowed by accounting standards related to derivative instruments and hedging transactions or (ii) the contracts did not meet the definition of a derivative. The amortization periods of these intangible assets are based on the terms of the contracts. Unfavorable purchase and sales contracts are recorded as other noncurrent liabilities and deferred credits (see Note 19) See below for discussion of impairment of certain intangible assets related to favorable purchase and sales contracts in 2015 and 2014. • Environmental allowances and credits – This intangible asset represents the fair value of environmental credits, substantially all of which were expected to be used in our power generation activities. These credits are amortized utilizing a units-of-production method. See below for discussion of impairment of certain allowances in 2015 and 2014. I ntangible Impairments The impairments of our generation facilities in 2015 (see Note 8) 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 15). We also impaired certain of our SO 2 allowances under the Cross-State Air Pollution Rule (CSAPR) related to the impaired generation facilities. Accordingly, in the year ended December 31, 2015, we recorded noncash impairment charges of $55 million (before deferred income tax benefit) in other deductions related to our existing environmental allowances and credits intangible asset. SO 2 emission allowances granted to us under the acid rain cap-and-trade program were recorded as intangible assets at fair value in connection with purchase accounting related to the Merger in 2007. Additionally, the impairments of our generation and related mining facilities in September 2015 resulted in our recording noncash impairment charges of $19 million (before deferred income tax benefit) in other deductions (see Note 7) related to mine development costs (included in other identifiable intangible assets in the table above) at the facilities. During the first quarter of 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 first quarter of 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 7). During the fourth quarter of 2014, we determined that certain intangible assets related to favorable power purchase contracts should be evaluated for impairment. That conclusion was based on the combination of (1) the review of contracts for rejection as part of the Chapter 11 Cases, which could result in termination of contracts before the end of their estimated useful life and (2) declines in wholesale electricity prices. 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 REC prices in ERCOT. As a result of the analysis, we recorded a noncash impairment charge of $183 million (before deferred income tax benefit) in other deductions (see Note 7). As a result of the CSAPR, which became effective on January 1, 2015, and other new or proposed EPA rules, we projected that as of December 31, 2014 we had excess SO 2 emission allowances under the Clean Air Act's existing acid rain cap-and-trade program. In addition, the impairments of our Monticello, Martin Lake and Sandow 5 generation facilities (see Note 8) resulted in the impairment of the SO 2 allowances 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 15). Accordingly we recorded a noncash impairment charge of $80 million (before deferred income tax benefit) in other deductions related to our existing environmental allowances and credits intangible asset in 2014. SO 2 emission allowances granted to us were recorded as intangible assets at fair value in connection with purchase accounting related to the Merger in 2007. 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 $ 72 2017 $ 60 2018 $ 36 2019 $ 22 2020 $ 11

Accounting For Uncertainty In I

Accounting For Uncertainty In Income Taxes	12 Months Ended
	Dec. 31, 2015
Accounting for Uncertainty in Income Taxes [Abstract]
Accounting for Uncertainty in Income Taxes	ACCOUNTING FOR UNCERTAINTY IN INCOME TAXES Accounting guidance related to uncertain tax positions requires that all tax positions subject to uncertainty be reviewed and assessed with recognition and measurement of the tax benefit based on a "more-likely-than-not" standard with respect to the ultimate outcome, regardless of whether this assessment is favorable or unfavorable. EFH Corp. and its subsidiaries file or have filed income tax returns in US federal, state and foreign jurisdictions and are subject to examinations by the IRS and other taxing authorities. Examinations of income tax returns filed by EFH Corp. and any of its subsidiaries for the years ending prior to January 1, 2010 are complete. Federal income tax returns are under examination for tax years 2010 to 2014. Texas franchise and margin tax returns are under examination or still open for examination for tax years beginning after 2006. In June 2015, EFH Corp. signed a final agreed Revenue Agent Report (RAR) with the IRS and associated documentation for the 2008 and 2009 tax years. The Bankruptcy Court approved EFH Corp.'s signing of the RAR in July 2015. As a result of EFH Corp. receiving, agreeing to and signing the final RAR, we reduced the liability for uncertain tax positions by $22 million , resulting in an $18 million increase in noncurrent inter-company tax payable to EFH Corp., a $2 million reclassification to the accumulated deferred income tax liability and the recording of a $2 million income tax benefit. In 2014, the IRS filed a claim with the Bankruptcy Court for open tax years through 2013 that was consistent with the settlement EFH Corp. reached with IRS Appeals for tax years 2003-2006. Also in 2014, EFH Corp. signed a final RAR with the IRS and associated documentation for the 2007 tax year. As a result of these events, EFH Corp. effectively settled the 2003-2007 open tax years, and we reduced the liability for uncertain tax positions related to such years by $132 million , resulting in a $122 million reclassification to the accumulated deferred income tax liability and the recording of a $10 million income tax benefit reflecting the settlement of certain positions. In recording the 2014 impacts, the Company identified approximately $85 million of income tax expense related to 2013 which was recorded in December 2014. The impact of recording this expense was not material to the financial statements in 2013 or 2014. In 2013, EFH Corp. and the IRS agreed on terms to resolve disputed adjustments related to the IRS audit for the years 2003 through 2006, which was concluded in June 2011. Also in 2013, EFH Corp. received approval from the Joint Committee on Taxation of the IRS appeals settlement of all issues arising from the 1997 through 2002 IRS audit. The IRS proposed a significant number of adjustments to the originally filed returns for such years related to one significant accounting method issue and other less significant issues. As a result of these events, we reduced the liability for uncertain tax positions by $878 million , including $139 million in interest accruals. Other effects included the recording of current federal income tax and state income tax liabilities to EFH Corp. of $78 million and $14 million , respectively, under the Federal and State Income Tax Allocation Agreement (see Note 6). In total, the settlements in 2013 resulted in an increase of $1.063 billion in the accumulated deferred income tax liability, and an income tax benefit of $80 million . Of the total income tax benefit, $90 million (after-tax) was attributable to the release of accrued interest. In accordance with the provisions of the Federal and State Income Tax Allocation Agreement with EFH Corp., amounts previously reported as accumulated deferred income taxes totaling $535 million were reclassified to the liabilities subject to compromise, the total amount of which is not expected to be settled within the next twelve months. The settlements resulted in the elimination of net operating loss carryforwards and a substantial majority of alternative minimum tax credit carryforwards generated through 2013. In September 2013, the US Treasury and the IRS issued final tangible property regulations that relate to repair and maintenance costs. As a result of our analysis of these regulations, in the fourth quarter 2013 we reduced the liability for uncertain tax positions by $159 million and reclassified that amount to the accumulated deferred income tax liability and recorded a $6 million income tax benefit representing a reversal of accrued interest. We classify interest and penalties related to uncertain tax positions as current income tax expense. Ongoing accruals of interest after the IRS settlements were not material in 2015, 2014 and 2013. Noncurrent liabilities included a total of $4 million and $9 million in accrued interest at December 31, 2015 and 2014, respectively. The federal income tax benefit on the interest accrued on uncertain tax positions is recorded as accumulated deferred income taxes. The following table summarizes the changes to the uncertain tax positions, reported in other noncurrent liabilities in the consolidated balance sheets, during the years ended December 31, 2015, 2014 and 2013: Year Ended December 31, 2015 2014 2013 Balance at January 1, excluding interest and penalties $ 65 $ 193 $ 1,078 Additions based on tax positions related to prior years — 55 246 Reductions based on tax positions related to prior years (11 ) (164 ) (1,070 ) Additions based on tax positions related to the current year — — 13 Settlements with taxing authorities (18 ) (19 ) (74 ) Balance at December 31, excluding interest and penalties $ 36 $ 65 $ 193 Of the balance at December 31, 2015, $2 million represents tax positions for which the uncertainty relates to the timing of recognition in tax returns. The disallowance of such positions would not affect the effective tax rate, but could accelerate the payment of cash to the taxing authority to an earlier period. With respect to tax positions for which the ultimate deductibility is uncertain (permanent items), should EFH Corp. sustain such positions on income tax returns previously filed, tax liabilities recorded would be reduced by $35 million , and accrued interest would be reversed resulting in a $3 million after-tax benefit, resulting in increased net income and a favorable impact on the effective tax rate. With respect to the items discussed above, we reasonably expect the total amount of liabilities recorded related to uncertain tax positions will significantly decrease in the next twelve months due to the anticipated resolution of claims outstanding with the Texas Comptroller of Public Accounts and the IRS. We expect an approximately $2 million reclassification to the accumulated deferred income tax liability from the uncertain tax position liability during the next 12 months.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Income Taxes	INCOME TAXES EFH Corp. files a US federal income tax return that includes the results of EFCH and TCEH. EFH Corp. and its subsidiaries (including EFCH and TCEH) are parties to a Federal and State Income Tax Allocation Agreement, which provides for the computation of income tax liabilities and benefits, and among other things, that any corporate member or disregarded entity in the 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. Under the terms of the Settlement Agreement, no further cash payments among the Debtors will be made in respect of federal income taxes. However, solely for accounting purposes, the EFH Corp. group continues to allocate federal income taxes among entities within the same registrant. The Settlement Agreement did not alter the allocation and payment for state income taxes, which will continue to be settled. The components of our income tax benefit are as follows: Year Ended December 31, 2015 2014 2013 Current: US Federal $ 68 $ 43 $ (166 ) State 21 29 41 Total current 89 72 (125 ) Deferred: US Federal (875 ) (2,385 ) (611 ) State (72 ) (17 ) (1 ) Total deferred (947 ) (2,402 ) (612 ) Total $ (858 ) $ (2,330 ) $ (737 ) Reconciliation of income taxes computed at the US federal statutory rate to income tax benefit recorded is as follows: Year Ended December 31, 2015 2014 2013 Loss before income taxes $ (5,461 ) $ (8,559 ) $ (3,054 ) Income taxes at the US federal statutory rate of 35% $ (1,911 ) $ (2,996 ) $ (1,069 ) IRS audit and appeals settlements — 46 (80 ) Nondeductible goodwill impairment 770 560 350 Texas margin tax, net of federal benefit — 10 8 Lignite depletion allowance (8 ) (14 ) (12 ) Interest accrued for uncertain tax positions, net of tax (2 ) — (17 ) Nondeductible interest expense 22 21 21 Nondeductible debt restructuring costs 64 42 4 Impairment of joint venture assets attributable to noncontrolling interests (Note 8) — — 37 Valuation allowance 191 — — Other 16 1 21 Income tax benefit $ (858 ) $ (2,330 ) $ (737 ) Effective tax rate 15.7 % 27.2 % 24.1 % Deferred Income Tax Balances Deferred income taxes provided for temporary differences based on tax laws in effect at December 31, 2015 and 2014 are as follows: 2015 2014 Total Noncurrent (a) Total Current Noncurrent Deferred Income Tax Assets Alternative minimum tax credit carryforwards $ 22 $ 22 $ — $ 22 Net operating loss (NOL) carryforwards 413 719 — 719 Unfavorable purchase and sales contracts 193 202 — 202 Commodity contracts and interest rate swaps 125 6 — 6 Debt extinguishment gains 1,116 873 — 873 Employee benefit obligations 51 54 2 52 Accrued interest — 88 — 88 Other 59 41 2 39 Total 1,979 2,005 4 2,001 Deferred Income Tax Liabilities Property, plant and equipment 1,540 2,465 — 2,465 Commodity contracts and interest rate swaps — 44 44 — Identifiable intangible assets 321 362 — 362 Debt fair value discounts — 196 — 196 Debt extinguishment gains — 74 74 — Accrued interest 140 — — — Total 2,001 3,141 118 3,023 Valuation allowance $ 191 — $ — $ — Net Accumulated Deferred Income Tax (Asset) Liability $ 213 $ 1,136 $ 114 $ 1,022 ____________ (a) Reflects adoption of ASU 2015-17, Balance Sheet Classification of Deferred Taxes . See Note 1. At December 31, 2015 we had $1.180 billion in net operating loss (NOL) carryforwards for federal income tax purposes that will expire between 2035 and 2036. As discussed in Note 5, audit settlements reached in 2013 resulted in the elimination of substantially all NOL carryforwards generated through 2013 and available AMT credits. The NOL carryforwards can be used to offset future taxable income. EFCH believes that it is more likely than not that the full tax benefit from the NOLs will not be realized. In recognition of this risk, EFCH has recorded a valuation allowance of $191 million on the net deferred tax assets balance at December 31, 2015. In assessing the need for the valuation allowance, we considered both positive and negative evidence related to the likelihood of realization of the deferred tax assets. As a result of our assessment, we concluded that there was uncertainty as to whether our current deferred tax assets (other than our indefinite lived deferred tax assets) would be fully utilized by future reversals of existing taxable temporary differences. If EFCH's assumptions change and it determines it will be able to realize these NOLs, the tax benefits relating to any reversal of the valuation allowance on deferred tax assets would be recorded to income tax benefit. At December 31, 2015, we had $22 million in alternative minimum tax (AMT) credit carryforwards available which may, in certain limited circumstances, be used to offset future tax payments. The AMT credit carryforwards have no expiration date, but may be limited in a change of control. The income tax effects of the components included in accumulated other comprehensive income at December 31, 2015 and 2014 totaled a net deferred tax asset of $18 million and $19 million , respectively. See Note 5 for discussion regarding accounting for uncertain tax positions, including the effects of the resolution of IRS audit matters.

Other Income and Deductions

Other Income and Deductions	12 Months Ended
	Dec. 31, 2015
Other Income and Expenses [Abstract]
Other Income and Deductions	OTHER INCOME AND DEDUCTIONS Year Ended December 31 2015 2014 2013 Other income: Mineral rights royalty income $ 4 $ 4 $ 5 All other 13 12 4 Total other income $ 17 $ 16 $ 9 Other deductions: Impairment of favorable purchase contracts (Note 4) $ 8 $ 183 $ — Impairment of emission allowances (Note 4) 55 80 — Impairment of mining development costs (Note 4) 19 — — All other 11 18 22 Total other deductions $ 93 $ 281 $ 22

Impairment of Long-Lived Assets

Impairment of Long-Lived Assets (Notes)	12 Months Ended
	Dec. 31, 2015
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments and Joint Ventures Disclosure [Text Block]	. IMPAIRMENT OF LONG-LIVED ASSETS Impairment of Lignite/Coal Fueled Generation and Mining Assets We evaluated our generation assets for impairment during 2015 as a result of impairment indicators related to the continued decline in forecasted wholesale electricity prices in ERCOT. Our evaluations concluded that impairments existed, and the carrying values at our Big Brown, Martin Lake, Monticello, Sandow 4 and Sandow 5 generation facilities and related mining facilities were reduced in total by $2.541 billion . We evaluated our generation assets for impairment during 2014 as a result of several impairment indicators, including lower forecasted wholesale electricity prices in ERCOT, changes to operating assumptions for certain generation assets as detailed in our updated annual financial and operating plan and potential effects of new and/or proposed environmental regulations. Our evaluation concluded that impairments existed, and the carrying values for our Martin Lake, Monticello and Sandow 5 generation facilities and related mining facilities were reduced in total by $4.640 billion . 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 15). 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. In 2014, we wrote off previously incurred and deferred costs totaling $30 million for mining projects not expected to be completed due to economic forecasts and regulatory uncertainty. These charges have been recorded in impairment of long-lived assets. Additional material impairments may occur in the future with respect to these assets or other of our generation facilities if forward wholesale electricity prices continue to decline or forecasted costs of producing electricity at our generation facilities increase, including increased costs of compliance with new and/or proposed environmental regulations. Impairment of Nuclear Generation Development Joint Venture Assets in 2013 In 2009, subsidiaries of TCEH and Mitsubishi Heavy Industries Ltd. (MHI) formed a joint venture, Comanche Peak Nuclear Power Company LLC (CPNPC), to develop two new nuclear generation units at our existing Comanche Peak nuclear plant site. CPNPC was a consolidated VIE. In the fourth quarter 2014, MHI withdrew from the joint venture, and the TCEH subsidiary now owns 100% of CPNPC. In the fourth quarter of 2013, MHI notified us and the NRC of its plans to reduce its support of review activities related to the NRC's Design Certification of MHI's US APWR technology. As a result, Luminant notified the NRC of its intent to suspend (but not withdraw) all reviews associated with the combined operating license application by March 31, 2014. MHI's decision and the expected amendment of the joint venture agreement triggered an analysis of the recoverability of the joint venture's assets. Because of the significant uncertainty regarding the development of the nuclear generation units, considering the wholesale electricity price environment in ERCOT and risks related to financing and cost escalation, in the fourth quarter 2013 essentially all the joint venture's assets were impaired resulting in a charge of $140 million . The charge is reported as other deductions. MHI's allocated portion of the impairment charge totaled $107 million and is reported in net loss attributable to noncontrolling interests in the statements of consolidated income (loss). A deferred income tax benefit was recorded for our $33 million allocated portion of the impairment charge and is included in income tax benefit in the statements of consolidated income (loss).

Interest Expense and Related Ch

Interest Expense and Related Charges (Notes)	12 Months Ended
	Dec. 31, 2015
Interest Expense and Related Charges [Abstract]
Interest Expense Disclosure [Text Block]	INTEREST EXPENSE AND RELATED CHARGES Year Ended December 31, 2015 2014 2013 Interest paid/accrued on debtor-in-possession financing $ 63 $ 37 $ — Adequate protection amounts paid/accrued (a) 1,233 828 — Interest paid/accrued on pre-petition debt (b) 8 886 2,724 Interest related to pushed down debt — 1 6 Noncash realized net loss on termination of interest rate swaps (offset in unrealized net gain) (c) — 1,225 — Unrealized mark-to-market net gain on interest rate swaps — (1,290 ) (1,053 ) Amortization of debt issuance, amendment and extension costs and discounts — 86 264 Capitalized interest (11 ) (17 ) (25 ) Other — 2 17 Total interest expense and related charges $ 1,293 $ 1,758 $ 1,933 ____________ (a) Post-petition period only. (b) Includes amounts related to interest rate swaps totaling $193 million and $621 million for the years ended December 31, 2014 and 2013, respectively. Of the $193 million for the year ended December 31, 2014, $127 million is included in the liability arising from the termination of TCEH interest rate swaps discussed in Note 16. (c) See Note 16. Interest expense for the year ended December 31, 2015 reflects interest paid and accrued on debtor-in-possession financing (see Note 11), as well as 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 16), 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. Additionally, interest expense for the year ended December 31, 2014 includes interest paid and accrued on all pre-petition debt for the period prior to the Petition Date. The interest rate applicable to the adequate protection amounts paid/accrued at December 31, 2015 is 4.69% (one-month LIBOR plus 4.50% ). In connection with the completion of the Plan of Reorganization, 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. The Bankruptcy Code generally restricts payment of interest on pre-petition debt, subject to certain exceptions. However, the Bankruptcy Court ordered the payment of adequate protection amounts as discussed above. Other interest payments may also be made upon approval by the Bankruptcy Court. Other than these amounts ordered or approved by the Bankruptcy Court, effective April 29, 2014, we discontinued recording interest expense on outstanding pre-petition debt classified as liabilities subject to compromise (LSTC), other than payments approved by the Bankruptcy Court. 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 as calculated under the contractual terms of EFCH's debt, all of which is subject to compromise, totaled $2.077 billion and $1.396 billion and for the year ended December 31, 2015 and the post-petition period through December 31, 2014, respectively. This amount exceeded interest expense recorded of $1.173 billion and $787 million for the year ended December 31, 2015 and the post-petition period through December 31, 2014, respectively by $904 million and $609 million , respectively. See tables below. Interest expense recorded represented adequate protection amounts since the Bankruptcy Filing allowed by the Bankruptcy Court. For the years ended December 31, 2015 and 2014, adequate protection paid/accrued excludes $60 million and $40 million , respectively, related to the TCEH first-lien interest rate and commodity hedge claims (see Note 16), as such amounts are not included in contractual interest amounts presented above. Year Ended December 31, 2015 Entity: Contractual Interest on Adequate Protection Contractual Interest on EFCH 7 — 7 TCEH 2,070 1,173 897 Total $ 2,077 $ 1,173 $ 904 Post-Petition Period Ended December 31, 2014 Entity: Contractual Interest on Adequate Protection Contractual Interest on EFCH 4 — 4 TCEH 1,392 787 605 Total $ 1,396 $ 787 $ 609

Reorganization Items Reorganiza

Reorganization Items Reorganization Items	12 Months Ended
	Dec. 31, 2015
Reorganization Items [Abstract]
Reorganization Items	REORGANIZATION ITEMS Expenses and income directly associated with the Chapter 11 Cases are reported separately in the statements of consolidated income (loss) as reorganization items as required by ASC 852, Reorganizations . Reorganization items also include adjustments to reflect the carrying value of liabilities subject to compromise (LSTC) at their estimated allowed claim amounts, as such adjustments are determined. The following table presents reorganization items incurred in the year ended December 31, 2015 and the post-petition period ended December 31, 2014 as reported in the statements of consolidated income (loss): Twelve Months Ended December 31, 2015 Post-Petition Period Ended Expenses related to legal advisory and representation services $ 141 $ 65 Expenses related to other professional consulting and advisory services 69 67 Contract claims adjustments 54 20 Noncash adjustment for estimated allowed claims related to debt (Note 12) 897 — Adjustment to affiliate claims pursuant to settlement agreement (Note 18) (736 ) — Gain on settlement of debt held by affiliates (Note 18) (382 ) — Gain on settlement of interest on debt held by affiliates (20 ) — Sponsor management agreement settlement (Notes 2 and 18) (19 ) — Contract assumption adjustments (14 ) — Noncash liability adjustment arising from termination of interest rate swaps (Note 12) — 277 Fees associated with extension/completion of the DIP Facility 9 92 Other 2 — Total reorganization items $ 1 $ 521

Debtor-In-Possession Borrowing

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 (Notes)	12 Months Ended
	Dec. 31, 2015
Debtor-In-Possession Obligations [Abstract]
Debtor-In-Possession Borrowing Facilities and Long-Term Debt Not Subject to Compromise [Text Block]	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 $1.95 billion and a term loan facility of up to $1.425 billion . 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 December 31, 2015 are presented below. Borrowings are reported in the consolidated balance sheets as borrowings under the debtor-in-possession credit facility. In October 2015, the TCEH Debtors paid an $8 million extension fee and extended the maturity date of the DIP Facility to the earlier of (a) November 2016 or (b) the effective date of any reorganization plan of TCEH. The terms of the facility were otherwise unchanged by the extension. In September 2015, the TCEH Debtors extended their use of cash collateral to the earlier of (a) the effective date of a plan of reorganization or (b) 60 days following termination of the Debtors' Plan Support Agreement, provided that the TCEH Debtors do not otherwise cause an event of default under the cash collateral order. The DIP Facility must be repaid in full prior to the TCEH Debtors emergence from the Chapter 11 Cases. December 31, 2015 DIP Facility Facility Limit Available Cash Borrowing Capacity Available Letter of Credit Capacity TCEH DIP Revolving Credit Facility (a) $ 1,950 $ 1,950 $ — TCEH DIP Term Loan Facility (b) 1,425 — 281 Total DIP Facility $ 3,375 $ 1,950 $ 281 ___________ (a) Facility used for general corporate purposes. No amounts were borrowed at December 31, 2015. Pursuant to an order of the Bankruptcy Court, the TCEH Debtors may not have more than $1.650 billion of TCEH 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 December 31, 2015 and 2014, all $1.425 billion of the TCEH 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 December 31, 2015, $281 million is reported as cash and cash equivalents and $519 million is reported as restricted cash, which represents the amount of outstanding letters of credit. As discussed in Note 3, we intend to utilize a portion of the remaining available cash borrowing capacity under the TCEH DIP Revolving Credit Facility and cash on hand to fund the acquisition of La Frontera Holdings, LLC. Amounts borrowed under the DIP Facility bear interest based on applicable LIBOR rates, subject to a 0.75% floor, plus 3% . At both December 31, 2015 and 2014, 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, 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 parent 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 , as a substitute for its self-bond, 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. As a result, in July 2014, TCEH terminated the $1.1 billion RCT Delayed Draw Letter of Credit commitment included in the original DIP facility. 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. 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. December 31, 2015 2014 EFCH 9.58% Fixed Notes due in annual installments through December 4, 2019 (a) $ 13 $ 21 8.254% Fixed Notes due in quarterly installments through December 31, 2021 (a) 24 29 Unamortized fair value discount (b) (2 ) (3 ) Total EFCH 35 47 TCEH 7.48% Fixed Secured Facility Bonds with amortizing payments through January 2017 (c) 13 25 7.46% Fixed Secured Facility Bonds with amortizing payments through January 2015 (c) — 4 Capital lease obligations 5 44 Other 2 2 Unamortized discount (1 ) (2 ) Total TCEH 19 73 Total EFCH consolidated 54 120 Less amounts due currently (31 ) (35 ) Total long-term debt not subject to compromise $ 23 $ 85 ____________ (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.

Borrowing Facilities and Debt

Borrowing Facilities and Debt	12 Months Ended
	Dec. 31, 2015
Debt and Capital Lease Obligations [Abstract]
Short-Term Borrowings And Long-Term Debt	Amounts presented below represent principal amounts of pre-petition notes, loans and other debt reported as liabilities subject to compromise. December 31, 2015 2014 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 (a) 15,691 15,710 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 (a) 1,833 2,046 10.25% Fixed Senior Notes due November 1, 2015, Series B (a) 1,292 1,442 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 Unamortized fair value discount related to pollution control revenue bonds (b) — (103 ) Other: Other 1 1 Unamortized discount — (91 ) Total TCEH 31,668 31,856 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 Unamortized fair value discount — (1 ) Subtotal 9 8 December 31, 2015 2014 EFH Corp. pre-petition debt pushed down (c) 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. pre-petition debt pushed down 30 30 Total EFCH (parent entity) 39 38 Deferred debt issuance and extension costs (d) — (702 ) Total EFCH consolidated notes, loans and other debt $ 31,707 $ 31,192 ____________ (a) As discussed below and in Note 18, principal amounts of notes/term loans totaling $382 million at December 31, 2014 were held by EFH Corp. and EFIH. The amounts of TCEH debt held by EFIH or EFH Corp. were eliminated as a result of the Settlement Agreement approved by the Bankruptcy Court in December 2015. (b) Amount represents unamortized fair value adjustments recorded under purchase accounting. (c) 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 . (d) Due to the Settlement Agreement our pre-petition notes, loans and other debt reported as liabilities subject to compromise were updated to reflect our expected allowed claim amounts, resulting in the write-off to reorganization items of unamortized deferred debt issuance and extension costs, premiums and discounts classified as LSTC (see Note 10). 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 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. In the first quarter of 2014, TCEH issued a $157 million letter of credit to a subsidiary of EFH Corp. to secure its current and future amounts payable to the subsidiary arising from recurring transactions in the normal course of business, and in 2014, the subsidiary drew on the letter of credit in the amount of $150 million to settle amounts due from TCEH. The remaining $7 million under the letter of credit expired in July 2014. For the years ended December 31, 2015 and 2014, $45 million and $245 million , respectively, of letters of credit were drawn upon by counterparties to settle amounts due from TCEH. Included in the year ended December 31, 2015 amount was $20 million drawn by certain executive officers to satisfy payments related to long-term incentive awards, and included in the year ended December 31, 2014 amount was $204 million related to pollution control revenue bonds that were tendered as noted below. Debt Related Activity in 2014 Repayments of debt in the year ended December 31, 2014 totaled $235 million and consisted of $227 million of payments of principal at scheduled maturity or mandatory tender and remarketing dates (including $204 million of pollution control revenue bond and $11 million of fixed secured facility bond payments) and $8 million of contractual payments under capital leases. 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 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 consolidated balance sheets as pushed down pre-petition debt ( $30 million at both December 31, 2015 and 2014 as shown in the table above) represents 50% of the principal amount of the EFH Corp. Merger-related debt guaranteed by EFCH. 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 years ended December 31, 2014 and 2015. EFH Corp. payments of interest on debt pushed down totaled $23 million in the year ended December 31, 2013. Information Regarding Significant Pre-Petition Debt TCEH elected not to make interest payments due in April 2014 totaling $123 million on certain debt obligations. The TCEH pre-petition debt described below is junior in right of priority and payment to the DIP Facility. TCEH Senior Secured Facilities — Borrowings under the TCEH Senior Secured Facilities total $22.616 billion and consist of: • $3.809 billion of TCEH Term Loan Facilities with interest at LIBOR plus 3.50% ; • $15.691 billion of TCEH Term Loan Facilities with interest at LIBOR plus 4.50% ; • $42 million of cash borrowed under the TCEH Letter of Credit Facility with interest at LIBOR plus 3.50% ; • $1.020 billion of cash borrowed under the TCEH Letter of Credit Facility with interest at LIBOR plus 4.50% , and • Amounts borrowed under the TCEH Revolving Credit Facility, which represent the entire amount of commitments under the facility totaling $2.054 billion . The TCEH Senior Secured Facilities are fully and unconditionally guaranteed jointly and severally on a senior secured basis by EFCH, and subject to certain exceptions, each existing and future direct or indirect wholly owned US subsidiary of TCEH. The TCEH Senior Secured Facilities, the TCEH Senior Secured Notes and the TCEH first lien hedges (or any termination amounts related thereto), discussed below, are secured on a first priority basis by (i) substantially all of the current and future assets of TCEH and TCEH's subsidiaries who are guarantors of such facilities and (ii) pledges of the capital stock of TCEH and certain current and future direct or indirect subsidiaries of TCEH. TCEH 11.5% Senior Secured Notes — The principal amount of the TCEH 11.5% Senior Secured Notes totals $1.750 billion , with interest payable at a fixed rate of 11.5% per annum. The notes are fully and unconditionally guaranteed on a joint and several basis by EFCH and each subsidiary of TCEH that guarantees the TCEH Senior Secured Facilities (collectively, the Guarantors). The notes are secured, on a first-priority basis, by security interests in all of the assets of TCEH, and the guarantees are secured on a first-priority basis by all of the assets and equity interests held by the Guarantors, in each case, to the extent such assets and equity interests secure obligations under the TCEH Senior Secured Facilities (the TCEH Collateral), subject to certain exceptions and permitted liens. The notes are (i) senior obligations and rank equally in right of payment with all senior indebtedness of TCEH, (ii) senior in right of payment to all existing or future unsecured and second-priority secured debt of TCEH to the extent of the value of the TCEH Collateral and (iii) senior in right of payment to any future subordinated debt of TCEH. These notes are effectively subordinated to all secured obligations of TCEH that are secured by assets other than the TCEH Collateral, to the extent of the value of the assets securing such obligations. The guarantees of the TCEH Senior Secured Notes by the Guarantors are effectively senior to any unsecured and second-priority debt of the Guarantors to the extent of the value of the TCEH Collateral. The guarantees are effectively subordinated to all debt of the Guarantors secured by assets that are not part of the TCEH Collateral, to the extent of the value of the collateral securing that debt. TCEH 15% Senior Secured Second Lien Notes (including Series B) — The principal amount of the TCEH 15% Senior Secured Second Lien Notes totals $1.571 billion with interest at a fixed rate of 15% per annum. The notes are fully and unconditionally guaranteed on a joint and several basis by EFCH and, subject to certain exceptions, each subsidiary of TCEH that guarantees the TCEH Senior Secured Facilities. The notes are secured, on a second-priority basis, by security interests in all of the assets of TCEH, and the guarantees (other than the guarantee of EFCH) are secured on a second-priority basis by all of the assets and equity interests of all of the Guarantors other than EFCH (collectively, the Subsidiary Guarantors), in each case, to the extent such assets and security interests secure obligations under the TCEH Senior Secured Facilities on a first-priority basis, subject to certain exceptions (including the elimination of the pledge of equity interests of any Subsidiary Guarantor to the extent that separate financial statements would be required to be filed with the SEC for such Subsidiary Guarantor under Rule 3-16 of Regulation S-X) and permitted liens. The guarantee from EFCH is not secured. The notes are senior obligations of the issuer and rank equally in right of payment with all senior indebtedness of TCEH, are senior in right of payment to all existing or future unsecured debt of TCEH to the extent of the value of the TCEH Collateral (after taking into account any first-priority liens on the TCEH Collateral) and are senior in right of payment to any future subordinated debt of TCEH. These notes are effectively subordinated to TCEH's obligations under the TCEH Senior Secured Facilities, the TCEH Senior Secured Notes and TCEH's commodity and interest rate hedges that are secured by a first-priority lien on the TCEH Collateral and any future obligations subject to first-priority liens on the TCEH Collateral, to the extent of the value of the TCEH Collateral, and to all secured obligations of TCEH that are secured by assets other than the TCEH Collateral, to the extent of the value of the assets securing such obligations. The guarantees of the TCEH Senior Secured Second Lien Notes by the Subsidiary Guarantors are effectively senior to any unsecured debt of the Subsidiary Guarantors to the extent of the value of the TCEH Collateral (after taking into account any first-priority liens on the TCEH Collateral). These guarantees are effectively subordinated to all debt of the Subsidiary Guarantors secured by the TCEH Collateral on a first-priority basis or that is secured by assets that are not part of the TCEH Collateral, to the extent of the value of the collateral securing that debt. EFCH's guarantee ranks equally with its unsecured debt (including debt it guarantees on an unsecured basis) and is effectively subordinated to any of its secured debt to the extent of the value of the collateral securing that debt. TCEH 10.25% Senior Notes (including Series B) and 10.50%/11.25% Senior Toggle Notes (collectively, the TCEH Senior Notes ) — The principal amount of the TCEH Senior Notes totals $4.874 billion and the notes are fully and unconditionally guaranteed on a joint and several unsecured basis by TCEH's direct parent, (EFCH), and by each subsidiary that guarantees the TCEH Senior Secured Facilities. The TCEH 10.25% Notes bore interest at a fixed rate of 10.25% per annum. The TCEH Toggle Notes bore interest at a fixed rate of 10.50% per annum. Material Cross Default/Acceleration Provisions — Certain of our pre-petition financing arrangements contain provisions that result in an event of default if there were a failure under other financing arrangements to meet payment terms or to observe other covenants that could or does result in an acceleration of payments due. Such provisions are referred to as "cross default" or "cross acceleration" provisions. The Bankruptcy Filing triggered defaults on our pre-petition debt obligations, but pursuant to the Bankruptcy Code, the creditors are stayed from taking any actions against the Debtors as a result of such defaults. Intercreditor Agreement — TCEH has entered into an intercreditor agreement with Citibank, N.A. and five secured commodity hedge counterparties (the Secured Commodity Hedge Counterparties). The intercreditor agreement takes into account, among other things, the possibility that TCEH could have issued notes and/or loans secured by collateral (other than the collateral that secures the TCEH Senior Secured Facilities) that ranks on parity with, or junior to, TCEH's existing first lien obligations under the TCEH Senior Secured Facilities. The Intercreditor Agreement provides that the lien granted to the Secured Commodity Hedge Counterparties ranks pari passu with the lien granted with respect to the collateral of the secured parties under the TCEH Senior Secured Facilities. The Intercreditor Agreement also provides that the Secured Commodity Hedge Counterparties are entitled to share, on a pro rata basis, in the proceeds of any liquidation of such collateral in connection with a foreclosure on such collateral in an amount provided in the TCEH Senior Secured Facilities. The Intercreditor Agreement also provides that the Secured Commodity Hedge Counterparties have voting rights with respect to any amendment or waiver of any provision of the Intercreditor Agreement that changes the priority of the Secured Commodity Hedge Counterparties' lien on such collateral relative to the priority of lien granted to the secured parties under the TCEH Senior Secured Facilities or the priority of payments to the Secured Commodity Hedge Counterparties upon a foreclosure and liquidation of such collateral relative to the priority of the lien granted to the secured parties under the TCEH Senior Secured Facilities. Second Lien Intercreditor Agreement — TCEH has also entered into a second lien intercreditor agreement (the Second Lien Intercreditor Agreement) with Citibank, N.A., as senior collateral agent, and The Bank of New York Mellon Trust Company, N.A., as initial second priority representative. The Second Lien Intercreditor Agreement provides that liens on the collateral that secure the obligations under the TCEH Senior Secured Facilities, the obligations of the Secured Commodity Hedge Counterparties and any other obligations which are permitted to be secured on a pari passu basis therewith (collectively, the First Lien Obligations) rank prior to the liens on such collateral securing the obligations under the TCEH Senior Secured Second Lien Notes, and any other obligations which are permitted to be secured on a pari passu basis (collectively, the Second Lien Obligations). The Second Lien Intercreditor Agreement provides that the holders of the First Lien Obligations are entitled to the proceeds of any liquidation of such collateral in connection with a foreclosure on such collateral until paid in full, and that the holders of the Second Lien Obligations are not entitled to receive any such proceeds until the First Lien Obligations have been paid in full. The Second Lien Intercreditor Agreement also provides that the holders of the First Lien Obligations control enforcement actions with respect to such collateral, and the holders of the Second Lien Obligations are not entitled to commence any such enforcement actions, with limited exceptions. The Second Lien Intercreditor Agreement also provides that releases of the liens on the collateral by the holders of the First Lien Obligations automatically require that the liens on such collateral by the holders of the Second Lien Obligations be automatically released, and that amendments, waivers or consents with respect to any of the collateral documents in connection with the First Lien Obligations apply automatically to any comparable provision of the collateral documents in connection with the Second Lien Obligations.

Commitments And Contingencies

Commitments And Contingencies	12 Months Ended
	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments And Contingencies	COMMITMENTS AND CONTINGENCIES Contractual Commitments At December 31, 2015, we had contractual commitments, some of which are subject to potential rejection in the Chapter 11 Cases, under energy-related contracts, leases and other agreements as follows: Coal purchase and transportation agreements Pipeline transportation and storage reservation fees Nuclear Fuel Contracts Other Contracts 2016 $ 307 $ 13 $ 62 $ 130 2017 — 1 46 42 2018 — 1 72 14 2019 — 1 35 12 2020 — 1 37 14 Thereafter — 7 96 36 Total $ 307 $ 24 $ 348 $ 248 Expenditures under our coal purchase and coal transportation agreements totaled $218 million , $348 million and $353 million for the years ended December 31, 2015, 2014 and 2013, respectively. At December 31, 2015, future minimum lease payments under both capital leases and operating leases are as follows: Capital Leases Operating Leases (a) 2016 $ 3 $ 24 2017 2 29 2018 — 27 2019 — 26 2020 — 25 Thereafter — 139 Total future minimum lease payments 5 $ 270 Less amounts representing interest — Present value of future minimum lease payments 5 Less current portion 3 Long-term capital lease obligation $ 2 ___________ (a) Includes operating leases with initial or remaining noncancellable lease terms in excess of one year. Rent reported as operating costs, fuel costs and SG&A expenses totaled $55 million , $54 million and $57 million for the years ended December 31, 2015, 2014 and 2013, respectively. 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 11 and 12 for discussion of guarantees and security for certain of our post-petition and pre-petition debt and EFCH guarantees of certain EFH Corp. debt. Letters of Credit At December 31, 2015, TCEH had outstanding letters of credit under the DIP Facility totaling $519 million as follows: • $230 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; • $72 million to support executory contracts and insurance agreements; • $55 million to support TCEH's REP financial requirements with the PUCT, and • $162 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. See Note 12 for discussion of letter of credit draws in 2015 and 2014. 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. Potential Inter/Intra Debtor Claims — In August 2014, the Bankruptcy Court entered an order in the Chapter 11 Cases establishing discovery procedures governing, among other things, certain prepetition transactions among the various Debtors' estates. In February 2015, the ad hoc group of TCEH unsecured creditors; the official committee representing unsecured interests at EFCH and its direct subsidiary, TCEH; and the official committee representing unsecured interests at EFH and EFIH filed motions with the Bankruptcy Court seeking standing to prosecute derivative claims on behalf of TCEH relating to certain of these prepetition transactions. These claims were released effective when the Bankruptcy Court approved the Settlement Agreement. The Settlement Agreement was approved in December 2015 and is expected to remain effective even if the Plan of Reorganization does not become effective. 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 CO 2 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 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 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 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. 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 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. 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. Environmental Contingencies See discussion above regarding the CSAPR that includes provisions which, among other things, place limits on SO 2 and NO X emissions produced by electricity generation plants. We do not believe the CSAPR provisions and the MATS rule issued by the EPA in December 2011 will have any material impact on our business, results of operations, liquidity or financial condition. We must comply with environmental laws and regulations applicable to the handling and disposal of hazardous waste. We believe that we are in compliance with current environmental laws and regulations; however, the impact, if any, of changes to existing regulations or the implementation of new regulations is not determinable and could materially affect our financial condition, results of operations and liquidity. The costs to comply with environmental regulations could be significantly affected by the following external events or conditions: • enactment of state or federal regulations regarding CO 2 and other greenhouse gas emissions; • other changes to existing state or federal regulation regarding air quality, water quality, control of toxic substances and hazardous and solid wastes, and other environmental matters, including revisions to clean air regulations developed by the EPA as a result of court rulings discussed above and MATS and Regional Haze, and • the identification of sites requiring clean-up or the filing of other complaints in which we may be asserted to be a potential responsible party under applicable environmental laws or regulations. In February 2016, the EPA notified Texas of the EPA's preliminary intention to designate as nonattainment areas around our Big Brown, Monticello and Martin Lake plants based on modeling data submitted to the EPA by Sierra Club. We continue to believe that these models do not accurately predict actual SO 2 emissions measurements and that these designations should be determined by emissions data from air quality monitors. Should the EPA finalize these designations as intended in July 2016, Texas will begin the multi-year process to evaluate what potential emission controls or operational changes, if any, may be necessary to demonstrate attainment. Labor Contracts Certain personnel engaged in TCEH activities are represented by labor unions and covered by collective bargaining agreements. During 2015, all collective bargaining agreements covering bargaining unit personnel engaged in lignite mining operations, lignite/coal fueled generation operations, nuclear fueled generation operations and some of our natural gas powered generation operations were extended to March 2017. We do not expect any changes in collective bargaining agreements to have a material effect on our results of operations, liquidity or financial condition. Nuclear Insurance Nuclear insurance includes liability coverage, property damage, decontamination and premature decommissioning coverage and accidental outage and/or extra expense coverage. Nuclear insurance maintained meets or exceeds requirements promulgated by Section 170 (Price-Anderson) of the Atomic Energy Act (Act) and Title 10 of the Code of Federal Regulations. We intend to maintain insurance against nuclear risks as long as such insurance is available. The company is self-insured to the extent that losses (i) are within the policy deductibles, (ii) are not covered per policy exclusions, terms and limitations, (iii) exceed the amount of insurance maintained, or (iv) are not covered due to lack of insurance availability. Such losses could have a material effect on our financial condition and results of operations and liquidity. With regard to liability coverage, the Act provides for financial protection for the public in the event of a significant nuclear generation plant incident. The Act sets the statutory limit of public liability for a single nuclear incident at $13.6 billion and requires nuclear generation plant operators to provide financial protection for this amount. The US Congress could impose revenue-raising measures on the nuclear industry to pay claims exceeding the $13.6 billion limit for a single incident mandated by the Act. As required, the company provides this financial protection for a nuclear incident at Comanche Peak resulting in public bodily injury and property damage through a combination of private insurance and industry-wide retrospective payment plan known as the Secondary Financial Protection (SFP). Under the SFP, in the event of an incident at any nuclear generation plant in the US, each operating licensed reactor in the US is subject to an assessment of up to $127.3 million and this amount is subject to increases for inflation every five years, with the next adjustment expected in September 2018. Assessments are currently limited to $19 million per operating licensed reactor per year per incident. The company's maximum potential assessment under the industry retrospective plan would be $254.6 million per incident but no more than $37.9 million in any one year for each incident. The potential assessment is triggered by a nuclear liability loss in excess of $375 million per accident at any nuclear facility. With respect to nuclear decontamination and property damage insurance, the NRC requires that nuclear generation plant license-holders maintain at least $1.06 billion of such insurance and require the proceeds thereof to be used to place a plant in a safe and stable condition, to decontaminate it pursuant to a plan submitted to and approved by the NRC before the proceeds can be used for plant repair or restoration or to provide for premature decommissioning. The company maintains nuclear decontamination and property damage insurance for Comanche Peak in the amount of $2.25 billion (subject to $5 million deductible per accident), above which the company is self-insured. The company maintains Accidental Outage insurance to cover the additional costs of obtaining replacement electricity from another source if one or both of the units at Comanche Peak are out of service for more than twelve weeks as a result of covered direct physical damage. The coverage provides for weekly payments of $3.5 million for the first fifty-two weeks and $2.8 million for the next 110 weeks for each outage, respectively, after the initial twelve-week waiting period. The total maximum coverage is $490 million per unit. The coverage amounts applicable to each unit will be reduced to 80% if both units are out of service at the same time as a result of the same accident.

Equity

Equity	12 Months Ended
	Dec. 31, 2015
Stockholders' Equity Note [Abstract]
Equity	EQUITY Cash Distributions to Parent We paid no cash distributions to EFH Corp. in 2015, 2014 or 2013. Dividend Restrictions 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. 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 dividends are eligible to be paid without the approval of the Bankruptcy Court. Noncontrolling Interests As discussed in Notes 8 and 19, we consolidated a joint venture formed in 2009 for the purpose of developing two new nuclear generation units, which resulted in a noncontrolling interests component of equity. Net loss attributable to noncontrolling interests of $107 million for the year ended December 31, 2013 reflected the noncontrolling interest share of the impairment of the assets of the nuclear generation development joint venture. Net loss attributable to the noncontrolling interests was immaterial for the years ended December 31, 2015 and 2014.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2015
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. In addition, for valuation of interest rate swaps, we used generally accepted interest rate swap valuation models utilizing month-end interest rate curves. 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 16 for additional information regarding credit risk associated with our derivatives). We utilize published credit ratings, default rate factors and debt trading values in calculating these fair value measurement adjustments. Certain derivatives and financial instruments are valued utilizing option pricing models that take into consideration multiple inputs including, but not limited to, commodity prices, volatility factors, discount rates and other market based factors. Additionally, when there is not a sufficient amount of observable market data, valuation models are developed that incorporate proprietary views of market factors. Significant unobservable inputs used to develop the valuation models include volatility curves, correlation curves, illiquid pricing locations and credit/non-performance risk assumptions. Those valuation models are generally used in developing long-term forward price curves for certain commodities. We believe the development of such curves is consistent with industry practice; however, the fair value measurements resulting from such curves are classified as Level 3. The significant unobservable inputs and valuation models are developed by employees trained and experienced in market operations and fair value 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: December 31, 2015 Level 1 Level 2 Level 3 (a) Total Assets: Commodity contracts $ 385 $ 41 $ 49 $ 475 Nuclear decommissioning trust – equity securities (b) 380 219 — 599 Nuclear decommissioning trust – debt securities (b) — 319 — 319 Total assets $ 765 $ 579 $ 49 $ 1,393 Liabilities: Commodity contracts $ 128 $ 64 $ 12 $ 204 Total liabilities $ 128 $ 64 $ 12 $ 204 December 31, 2014 Level 1 Level 2 Level 3 (a) Total Assets: Commodity contracts $ 402 $ 46 $ 49 $ 497 Nuclear decommissioning trust – equity securities (b) 375 217 — 592 Nuclear decommissioning trust – debt securities (b) — 301 — 301 Total assets $ 777 $ 564 $ 49 $ 1,390 Liabilities: Commodity contracts $ 278 $ 25 $ 14 $ 317 Total liabilities $ 278 $ 25 $ 14 $ 317 _______________ (a) See table below for description of Level 3 assets and liabilities. (b) The nuclear decommissioning trust investment is included in the investments line in the consolidated balance sheets. See Note 19. 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 16 for further discussion regarding derivative instruments, including the termination of certain natural gas hedging agreements shortly after the Bankruptcy Filing. 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 December 31, 2015 and 2014: 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 congestion revenue rights 39 (4 ) 35 Market Approach (e) Illiquid price differences between settlement points (f) $0 to $10/MWh Other (i) 9 (7 ) 2 Total $ 49 $ (12 ) $ 37 December 31, 2014 Fair Value Contract Type (a) Assets Liabilities Total Valuation Technique Significant Unobservable Input Range (b) Electricity purchases and sales $ 4 $ (5 ) $ (1 ) Valuation Model Illiquid pricing locations (c) $30 to $50/MWh Hourly price curve shape (d) $20 to $70/MWh Electricity congestion revenue rights 38 (4 ) 34 Market Approach (e) Illiquid price differences between settlement points (f) $0 to $20/MWh Coal purchases — (4 ) (4 ) Market Approach (e) Illiquid price variances between mines (g) $0 to $1/ton Illiquid price variances between heat content (h) $0 to $1/ton Other (i) 7 (1 ) 6 Total $ 49 $ (14 ) $ 35 ____________ (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 congestion revenue rights contracts consist of forward purchase contracts (swaps and options) used to hedge electricity price differences between settlement points within ERCOT. Coal purchase contracts relate to western (Powder River Basin) coal. (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) While we use the market approach, there is either insufficient market data to consider the valuation liquid or the significance of credit reserves or non-performance risk adjustments results in a Level 3 designation. (f) Based on the historical price differences between settlement points within the ERCOT hubs and load zones. (g) Based on the historical range of price variances between mine locations. (h) Based on historical ranges of forward average prices between different heat contents (potential energy in coal for a given mass). (i) Other includes contracts for ancillary services, natural gas, power options, diesel options and coal options. There were no significant transfers between Level 1 and Level 2 of the fair value hierarchy for the years ended December 31, 2015, 2014 and 2013. See the table of changes in fair values of Level 3 assets and liabilities below for discussion of transfers between Level 2 and Level 3 for the years ended December 31, 2015, 2014 and 2013. The following table presents the changes in fair value of the Level 3 assets and liabilities for the years ended December 31, 2015, 2014 and 2013. Year Ended December 31, 2015 2014 2013 Net asset (liability) balance at beginning of period $ 35 $ (973 ) $ 29 Total unrealized valuation gains (losses) 27 (97 ) (48 ) Purchases, issuances and settlements (a): Purchases 49 63 92 Issuances (13 ) (5 ) (7 ) Settlements (48 ) 1,053 138 Transfers into Level 3 (b) 1 — (1,181 ) Transfers out of Level 3 (b) (14 ) (6 ) 4 Net change (c) 2 1,008 (1,002 ) Net asset (liability) balance at end of period $ 37 $ 35 $ (973 ) Unrealized valuation gains (losses) relating to instruments held at end of period $ 18 $ (5 ) $ 435 ____________ (a) Settlements reflect reversals of unrealized mark-to-market valuations previously recognized in net income. Purchases and issuances reflect option premiums paid or received. Settlement amounts in 2014 reflect termination of the TCEH interest rate swaps and include the reversal of a nonperformance risk adjustment as discussed in Note 16. (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 years presented are in and out of Level 2. Transfers into Level 3 during 2013 reflect a nonperformance risk adjustment in the valuation of the TCEH interest rate swaps, which were secured by a first-lien interest in the same assets of TCEH (on a pari passu basis) with the TCEH Senior Secured Facilities and the TCEH Senior Secured Notes (see Note 12). (c) Substantially all changes in values of commodity contracts are reported in the statements of consolidated income (loss) in net gain (loss) from commodity hedging and trading activities. Changes in values of interest rate swaps transferred into Level 3 in 2013 are reported in the statements of consolidated income (loss) in interest expense and related charges (see Note 9). 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	12 Months Ended
	Dec. 31, 2015
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 15 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 statements of consolidated income (loss) in net gain (loss) from commodity hedging and trading activities. Interest Rate Swap Transactions — Interest rate swap agreements have been used to reduce exposure to interest rate changes by converting floating-rate debt to fixed rates, thereby hedging future interest costs and related cash flows. Interest rate basis swaps were used to effectively reduce the hedged borrowing costs. Unrealized gains and losses arising from changes in the fair value of the swaps as well as realized gains and losses upon settlement of the swaps were reported in the statements of consolidated income (loss) in interest expense and related charges. As of December 31, 2015 and 2014, we had no active interest rate swap derivatives. 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 net liability recorded for the terminations totaled $1.116 billion , which represented a realized loss of $1.233 billion related to the interest rate swaps, net of a realized gain of $117 million related to the natural gas hedging positions. Additionally, net accounts payable amounts related to matured interest rate swaps of $127 million are also secured by the same first-lien secured 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 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 9). The derivative liability related to the TCEH interest rate swaps had included a nonperformance risk adjustment (resulting in a Level 3 valuation). This fair value adjustment reflected the counterparties' exposure to our credit risk. The amount of the adjustment was after consideration of derivative assets related to natural gas hedging positions with the same counterparties. The difference between the net liability arising upon the termination of the interest rate swaps and the natural gas hedging positions and the net derivative assets and liabilities recorded totaled $277 million , substantially all of which represented the nonperformance risk adjustment, and is reported as a noncash charge in reorganization items in the statements of consolidated income (loss) in accordance with ASC 852 (see Note 10). Financial Statement Effects of Derivatives Substantially all derivative contractual assets and liabilities arise from mark-to-market accounting consistent with accounting standards related to derivative instruments and hedging activities. The following tables provide detail of commodity and other derivative contractual assets and liabilities (with the column totals representing the net positions of the contracts) as reported in the consolidated balance sheets at December 31, 2015 and 2014 (noncurrent assets and liabilities are reported in other noncurrent assets and other noncurrent liabilities and deferred credits, respectively). All amounts relate to commodity contracts. December 31, 2015 December 31, 2014 Derivative Assets Derivative Liabilities Total Derivative Assets Derivative Liabilities Total Current assets $ 465 $ — $ 465 $ 492 $ — $ 492 Noncurrent assets 10 — 10 5 — 5 Current liabilities — (203 ) (203 ) — (316 ) (316 ) Noncurrent liabilities — (1 ) (1 ) — (1 ) (1 ) Net assets (liabilities) $ 475 $ (204 ) $ 271 $ 497 $ (317 ) $ 180 At December 31, 2015 and 2014, there were no derivative positions accounted for as cash flow or fair value hedges. The following table presents the pretax effect of derivatives on net income (gains (losses)), including realized and unrealized effects: Year Ended December 31, Derivative (statements of consolidated income (loss) presentation) 2015 2014 2013 Commodity contracts (Net gain (loss) from commodity hedging and trading activities) (a) $ 380 $ 17 $ (54 ) Interest rate swaps (Interest expense and related charges) (b) — (128 ) 433 Interest rate swaps (Reorganization items) (Note 10) — (277 ) — Net gain (loss) $ 380 $ (388 ) $ 379 _______________ (a) Amount represents changes in fair value of positions in the derivative portfolio during the period, as realized amounts related to positions settled are assumed to equal reversals of previously recorded unrealized amounts. (b) Includes unrealized mark-to-market net gain (loss) as well as the net realized effect on interest paid/accrued, both reported in Interest Expense and Related Charges (see Note 9). 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 the years ended December 31, 2015, 2014 and 2013. There were no amounts recognized in OCI for the years ended December 31, 2015, 2014 and 2013. There were no transactions designated as cash flow hedges during the years ended December 31, 2015, 2014 or 2013. Accumulated other comprehensive income related to cash flow hedges at December 31, 2015 and 2014 totaled $33 million and $35 million in net losses (after-tax), respectively, substantially all of which relates to interest rate swaps previously accounted for as cash flow hedges. We expect that $2 million of net losses (after-tax) related to cash flow hedges included in accumulated other comprehensive income at December 31, 2015 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 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 consolidated balance sheets. Margin deposits received from counterparties are either used for working capital or other corporate purposes or are deposited in a separate restricted cash account. At December 31, 2015 and 2014, 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 consolidated balance sheets to net amounts after taking into consideration netting arrangements with counterparties and financial collateral: 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 December 31, 2014 Amounts Presented in Balance Sheet Offsetting Instruments (a) Financial Collateral (Received) Pledged (b) Net Amounts Derivative assets: Commodity contracts $ 497 $ (298 ) $ (16 ) $ 183 Derivative liabilities: Commodity contracts (317 ) 298 2 (17 ) Net amounts $ 180 $ — $ (14 ) $ 166 ____________ (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 December 31, 2015 and 2014: December 31, 2015 2014 Derivative type Notional Volume Unit of Measure Natural gas (a) 1,489 1,687 Million MMBtu Electricity 58,022 22,820 GWh Congestion Revenue Rights (b) 106,260 89,484 GWh Coal 10 10 Million US tons Fuel oil 35 36 Million gallons Uranium 75 150 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 December 31, 2015 and 2014, the fair value of liabilities related to derivative instruments under agreements with credit risk-related contingent features that were not fully collateralized totaled $58 million and $17 million , respectively. The liquidity exposure associated with these liabilities was reduced by cash and letter of credit postings with counterparties totaling $31 million and $5 million at December 31, 2015 and 2014, 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 December 31, 2015 and 2014. In addition, certain derivative agreements include indebtedness cross-default provisions that could result in the settlement of such contracts if there were a failure under other financing arrangements to meet payment terms or to comply with other covenants that could result in the acceleration of such indebtedness. At December 31, 2015 and 2014, 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 $59 million and $18 million at December 31, 2015 and 2014, 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 December 31, 2015, total credit risk exposure to all counterparties related to derivative contracts totaled $527 million (including associated accounts receivable). The net exposure to those counterparties totaled $199 million at December 31, 2015 after taking into effect netting arrangements, setoff provisions and collateral, with the largest net exposure to a single counterparty totaling $110 million . At December 31, 2015, the credit risk exposure to the banking and financial sector represented 78% of the total credit risk exposure and 56% 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.

Pension And Other Postretiremen

Pension And Other Postretirement Employee Benefits (OPEB) Plans	12 Months Ended
	Dec. 31, 2015
Compensation and Retirement Disclosure [Abstract]
Pension And Other Postretirement Employee Benefits (OPEB) Plans	Pension Plan Our subsidiaries are participating employers in the EFH Retirement Plan (the Retirement Plan), a defined benefit pension plan sponsored by EFH Corp. After amendments in 2012, employees in the Retirement Plan now consist entirely of our active and retired collective bargaining unit employees. The Retirement Plan is a qualified defined benefit pension plan under Section 401(a) of the Internal Revenue Code of 1986, as amended (Code) and is subject to the provisions of ERISA. All benefits are funded by the participating employers. The Retirement Plan provides benefits to participants under one of two formulas: (i) a Cash Balance Formula under which participants earn monthly contribution credits based on their compensation and a combination of their age and years of service, plus monthly interest credits or (ii) a Traditional Retirement Plan Formula based on years of service and the average earnings of the three years of highest earnings. Under the Cash Balance Formula, future increases in earnings will not apply to prior service costs. It is EFH Corp.'s policy to fund the Retirement Plan assets only to the extent deductible under existing federal tax regulations. Our subsidiaries also participate in EFH Corp.'s supplemental unfunded retirement plans for certain employees whose retirement benefits cannot fully be earned under the qualified Retirement Plan, the information for which is included below. Other Postretirement Employee Benefit (OPEB) Plan Our subsidiaries participate with EFH Corp. and certain other affiliated subsidiaries of EFH Corp. to offer OPEB in the form of health care and life insurance to eligible employees and their eligible dependents upon the retirement of such employees. For employees retiring on or after January 1, 2002, the retiree contributions required for such coverage vary based on a formula depending on the retiree's age and years of service. In 2011, we changed the OPEB plan whereby, effective January 1, 2013, Medicare-eligible retirees are subject to a cap on increases in subsidies received under the plan to offset medical costs. Pension and OPEB Costs Recognized as Expense The following details net pension and OPEB costs recognized as expense. Ongoing allocations of pension and OPEB costs are reimbursed to EFH Corp. The pension and OPEB amounts provided represent allocations to us of amounts related to EFH Corp.'s plans. Year Ended December 31, 2015 2014 2013 Pension costs $ 8 $ 7 $ 9 OPEB costs 3 5 3 Total benefit costs recognized as expense $ 11 $ 12 $ 12 For determining net periodic pension cost, EFH Corp. uses the calculated value method to determine the market-related value of the assets held in trust. EFH Corp. includes the realized and unrealized gains or losses in the market-related value of assets over a rolling four -year period. Each year, 25% of such gains and losses for the current year and for each of the preceding three years is included in the market-related value. Each year, the market-related value of assets is increased for contributions to the plan and investment income and is decreased for benefit payments and expenses for that year. For determining net periodic OPEB cost, EFH Corp. uses the fair value method of determining the market-related value of the assets held in trust. Regulatory Recovery of Pension and OPEB Costs PURA provides for the recovery by Oncor, in its regulated revenue rates, of pension and OPEB costs applicable to services of Oncor's active and retired employees, as well as services of active and retired personnel engaged in TCEH's activities, related to their service prior to the deregulation and disaggregation of EFH Corp.'s electric utility business effective January 1, 2002. Accordingly, Oncor and TCEH entered into an agreement whereby Oncor assumed responsibility for applicable pension and OPEB costs related to those personnel. Additional Multiemployer Plan Participation Disclosures We have not been allocated any overfunded asset or underfunded liability related to our participation in EFH Corp.'s pension and OPEB plans. However, we are jointly and severally liable for all EFH Corp. pension and OPEB plan liabilities and are subject to certain risks including the following: • Funding/assets contributed by us may be used to provide benefits to employees from other participating entities; • We may be required to bear the unfunded obligations of another participating employer that stops making contributions, and • If we stop participating, we may be required to pay an amount to the plan based on the underfunded status of the plan. Our share of contributions to the Retirement Plan assets was 24% in the year ended December 31, 2015 and 24% in the year ended December 31, 2014. We made no contributions to the Retirement Plan assets in the year ended December 31, 2013. The Retirement Plan was at least 80% funded pre-petition and 100% funded subsequent to the Petition date as determined under the provisions of ERISA. The Employer Identification Number of the Retirement Plan is 75-2669310 and the plan number is 002. Assumed Discount Rate The discount rate reflected in net periodic pension costs was 4.19% , 5.07% and 4.30% for the years ended December 31, 2015, 2014 and 2013, respectively. The discount rate reflected in net OPEB costs was 3.81% , 4.98% and 4.10% for the years ended December 31, 2015, 2014 and 2013, respectively. The expected rate of return on plan assets reflected in the 2015 cost amounts is 5.38% for the pension plan assets. Contributions in 2015 and 2016 In December 2015, a cash contribution totaling $67 million was made to the Retirement Plan assets, of which $51 million was contributed by Oncor and $16 million was contributed by TCEH, resulting in the plan being fully funded as calculated under the provisions of ERISA. As a result of the Bankruptcy Filing, participants in the Retirement Plan who choose to retire would not be eligible for the lump sum payout option under the Retirement Plan unless the Retirement Plan is fully funded. Pension plan funding in 2016 is expected to total $3 million . OPEB plan funding in 2015 totaled $8 million , and funding in 2016 is expected to total $8 million . Thrift Plan Our employees may participate in a qualified savings plan, the EFH Thrift Plan (Thrift Plan). This plan is a participant-directed defined contribution plan intended to qualify under Section 401(a) of the Code, and is subject to the provisions of ERISA. Under the terms of the Thrift Plan, employees who do not earn more than the IRS threshold compensation limit used to determine highly compensated employees may contribute, through pre-tax salary deferrals and/or after-tax payroll deductions, the lesser of 75% of their regular salary or wages or the maximum amount permitted under applicable law. Employees who earn more than such threshold may contribute from 1% to 20% of their regular salary or wages. Employer matching contributions are also made in an amount equal to 100% ( 75% for employees covered under the Traditional Retirement Plan Formula) of the first 6% of employee contributions. Employer matching contributions are made in cash and may be allocated by participants to any of the plan's investment options. Our contributions to the Thrift Plan totaled $21 million for each of the years ended December 31, 2015, 2014 and 2013. In accordance with an agreement in 2014 between Oncor and EFH Corp., Oncor ceased participation in EFH Corp.'s Thrift Plan effective January 1, 2015 and established its own plan.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2015
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 approximately $1.0 billion for each of the years ended December 31, 2015, 2014 and 2013. The fees are based on rates regulated by the PUCT that apply to all REPs. The consolidated balance sheets at both December 31, 2015 and 2014 reflect amounts due currently to Oncor totaling $118 million (included in trade accounts and other payables to affiliates) largely related to these electricity delivery fees. • Notes receivable from EFH Corp. were payable to TCEH on demand (TCEH Demand Notes) and arose from cash loaned for debt principal and interest payments and other general corporate purposes of EFH Corp. The TCEH Demand Notes were guaranteed by EFIH and EFCH on a senior unsecured basis. The TCEH Demand Notes were pledged as collateral under the TCEH Senior Secured Facilities. In January 2013, EFIH used $680 million of the proceeds from its August 2012 debt issuance to pay a dividend to EFH Corp., which EFH Corp. used with cash on hand to repay the entire balance of the TCEH Demand Notes. The average daily balance of the TCEH Demand Notes totaled $57 million for the year ended December 31, 2013. The TCEH Demand Notes carried interest at a rate based on the one-month LIBOR rate plus 5.00% , and interest income related to the TCEH Demand Notes totaled $3 million for the year ended December 31, 2013. • EFCH (parent entity) has a demand note payable to EFH Corp., the proceeds from which were used to repay outstanding debt. The note totaled $107 million at December 31, 2014, and carried interest at a rate based on the one-month LIBOR rate plus 5.00% . Interest expense related to this note totaled $2 million and $5 million for the years ended December 31, 2014 and 2013, respectively. Since the Petition Date, the note payable was classified as a liability subject to compromise (LSTC) and interest expense was not recorded since the Petition Date. In December 2015, the demand note was eliminated as part of the Settlement Agreement. • 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 ERISA, 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 $24 million at December 31, 2015, with $6 million recorded as a current asset and $18 million recorded as a noncurrent asset. The balance of the advance totaled $15 million at December 31, 2014, with $8 million recorded as a current asset and $7 million recorded as a noncurrent asset. • Receivables from affiliates are measured at historical cost and have historically 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 December 31, 2015 and 2014, respectively. • 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 $205 million , $204 million and $241 million for the years ended December 31, 2015, 2014 and 2013, respectively. These amounts include allocated expense, which totaled $10 million and $29 million for the years ended December 31, 2014 and 2013, respectively, for management fees owed and paid by EFH Corp. to the Sponsor Group. Effective with the Petition Date, EFH Corp. suspended allocations of such fees to EFCH. Fees accrued as of the Petition Date are classified as LSTC as of December 31, 2014 and were eliminated in December 2015 as part of the Settlement Agreement. Beginning in 2012, we reimburse a subsidiary of EFH Corp. for an allocated share of technology-related equipment purchased by the subsidiary. Amounts we paid in 2014 and 2013 related to technology-related equipment totaled $4 million and $29 million and were accounted for as an intangible asset to be amortized over the life of the equipment. Previously, the depreciation of such equipment was included in the administrative cost billings. • See Note 12 for discussion of a letter of credit issued by TCEH in 2014 to a subsidiary of EFH Corp. to secure its amounts payable to the subsidiary arising from recurring transactions in the normal course. • During 2015, TCEH purchased $16 million in information technology assets from a subsidiary of EFH Corp. and settled $14 million of these assets in 2015 and $2 million in early 2016. In 2014, a subsidiary of EFH Corp. sold information technology assets to TCEH totaling $52 million . TCEH cash settled $45 million of these transactions and a subsidiary of EFH Corp. settled $7 million of this obligation by drawing on the letter of credit issued by TCEH. 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 consolidated balance sheets, will ultimately be sufficient to fund the actual future decommissioning liability, reported in noncurrent liabilities in our consolidated balance sheets. The delivery fee surcharges remitted to TCEH totaled $17 million for both of the years ended December 31, 2015 and 2014 and $16 million for the year ended December 31, 2013. Income and expenses associated with the trust fund and the decommissioning liability incurred by TCEH are offset by a net change in a receivable/payable that ultimately will be settled through changes in Oncor's delivery fee rates. At December 31, 2015 and 2014, the excess of the trust fund balance over the decommissioning liability resulted in a payable totaling $409 million and $479 million , respectively, reported in other noncurrent liabilities. In November 2015, the PUCT approved Luminant's updated nuclear decommissioning cost study and funding analysis. • 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 December 31, 2015, we had current income tax liabilities of $10 million . As of December 31, 2014, we had current income tax liabilities of $16 million and we had $626 million in noncurrent income tax liabilities payable to EFH Corp. reported as LSTC. In 2015, $604 million of the income tax liability was eliminated under the terms of the Settlement Agreement. We made tax payments to EFH Corp. totaling $29 million , $33 million and $137 million for the years ended December 31, 2015, 2014 and 2013, respectively. • Pursuant to the Federal and State Income Tax Allocation Agreement between EFH Corp. and TCEH, in September 2013, TCEH made a federal income tax payment of $84 million to EFH Corp. related to the 1997 through 2002 IRS appeals settlement. The Plan of Reorganization provides that the Debtors will reject this agreement at the effective time of the Plan of Reorganization. Under the Settlement Agreement, no further cash payments will be made in respect of federal income tax. See Note 6. • 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 December 31, 2015 and 2014, respectively, TCEH had posted letters of credit and/or cash in the amount of $6 million and $9 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. • As a result of debt repurchase and exchange transactions in 2009 through 2011, EFH Corp. and EFIH held TCEH debt securities at December 31, 2014 as shown below (principal amounts). The $382 million in notes payable as of the Petition Date was classified as LSTC. The amounts of TCEH debt held by EFIH or EFH Corp. were eliminated as a result of the Settlement Agreement approved by the Bankruptcy Court in December 2015. In conjunction with the Settlement Agreement approved by the Bankruptcy Court in December 2015, EFH Corp. and EFIH waived their rights to the claims associated with these debt securities, resulting in a gain recorded in reorganization items (see Note 10). Principal Amount TCEH Senior Notes: Held by EFH Corp. $ 284 Held by EFIH 79 TCEH Term Loan Facilities: Held by EFH Corp. 19 Total $ 382 Interest expense on the notes totaled $1 million , $13 million and $38 million for the years ended December 31, 2015, 2014 and 2013, respectively. Contractual interest, not paid or recorded, totaled $37 million and $25 million for the years ended December 31, 2015 and 2014, respectively. See Note 9. See Notes 12 and 13 for guarantees and push-down of certain EFH Corp. debt and Note 17 for allocation of EFH Corp. pension and OPEB costs to us.

Supplementary Financial Informa

Supplementary Financial Information	12 Months Ended
	Dec. 31, 2015
Supplementary Financial Information [Abstract]
Supplementary Financial Information	Restricted Cash December 31, 2015 December 31, 2014 Current Noncurrent Assets Current Noncurrent Assets Amounts related to the DIP Facility (Note 11) $ 519 $ — $ — $ 350 Amounts related to TCEH's pre-petition Letter of Credit — 507 — 551 Other — — 2 — Total restricted cash $ 519 $ 507 $ 2 $ 901 ____________ (a) See Note 12 for discussion of letter of credit draws in 2014 and 2015. Trade Accounts Receivable December 31, 2015 2014 Wholesale and retail trade accounts receivable $ 542 $ 603 Allowance for uncollectible accounts (9 ) (15 ) Trade accounts receivable — net $ 533 $ 588 Gross trade accounts receivable at December 31, 2015 and 2014 included unbilled revenues of $231 million and $239 million , respectively. Allowance for Uncollectible Accounts Receivable Year Ended December 31, 2015 2014 2013 Allowance for uncollectible accounts receivable at beginning of period $ 15 $ 14 $ 9 Increase for bad debt expense 34 38 33 Decrease for account write-offs (40 ) (37 ) (28 ) Allowance for uncollectible accounts receivable at end of period $ 9 $ 15 $ 14 Variable Interest Entities A variable interest entity (VIE) is an entity with which we have a relationship or arrangement that indicates some level of control over the entity or results in economic risks to us. Accounting standards require consolidation of a VIE if we have (a) the power to direct the significant activities of the VIE and (b) the right or obligation to absorb profit and loss from the VIE (i.e., we are the primary beneficiary of the VIE). In determining the appropriateness of consolidation of a VIE, we evaluate its purpose, governance structure, decision making processes and risks that are passed on to its interest holders. We also examine the nature of any related party relationships among the interest holders of the VIE and the nature of any special rights granted to the interest holders of the VIE. There are no material investments accounted for under the equity or cost method. Prior to the fourth quarter of 2014, we consolidated as a VIE Comanche Peak Nuclear Power Company LLC (CPNPC), a joint venture formed by subsidiaries of TCEH and Mitsubishi Heavy Industries Ltd. (MHI) for the purpose of developing two new nuclear generation units at our existing Comanche Peak nuclear fueled generation facility. In the fourth quarter of 2014, the MHI subsidiary withdrew from the joint venture. As a result, the TCEH subsidiary owns 100% of CPNPC, CPNPC no longer qualifies as a VIE and CPNPC is now consolidated as a wholly owned subsidiary. See Note 8 for additional discussion of CPNPC, including impairment of essentially all of its assets in 2013. Inventories by Major Category December 31, 2015 2014 Materials and supplies $ 226 $ 214 Fuel stock 170 215 Natural gas in storage 32 39 Total inventories $ 428 $ 468 Investments December 31, 2015 2014 Nuclear plant decommissioning trust $ 918 $ 893 Assets related to employee benefit plans, including employee savings programs, net of distributions 1 1 Land 36 37 Miscellaneous other 7 10 Total investments $ 962 $ 941 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 18). The nuclear decommissioning trust fund is not a debtor under the Chapter 11 Cases. A summary of investments in the fund follows: 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 December 31, 2014 Cost (a) Unrealized gain Unrealized loss Fair market value Debt securities (b) $ 288 $ 13 $ — $ 301 Equity securities (c) 276 320 (4 ) 592 Total $ 564 $ 333 $ (4 ) $ 893 ____________ (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. The debt securities are heavily weighted with municipal bonds. The debt securities had an average coupon rate of 3.68% and 4.35% at December 31, 2015 and 2014, respectively, and an average maturity of 8 years and 6 years at December 31, 2015 and 2014, respectively. (c) The investment objective for equity securities is to invest tax efficiently and to match the performance of the S&P 500 Index. Debt securities held at December 31, 2015 mature as follows: $102 million in one to five years, $75 million in five to ten years and $142 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. Year Ended December 31, 2015 2014 2013 Realized gains $ 1 $ 11 $ 2 Realized losses $ (1 ) $ (2 ) $ (4 ) Proceeds from sales of securities $ 401 $ 314 $ 175 Investments in securities $ (418 ) $ (331 ) $ (191 ) Property, Plant and Equipment December 31, 2015 2014 Generation and mining (Note 8) $ 10,886 $ 14,986 Other assets 546 526 Total 11,432 15,512 Less accumulated depreciation 2,654 3,948 Net of accumulated depreciation 8,778 11,564 Construction work in progress 323 459 Nuclear fuel (net of accumulated amortization of $1.383 billion and $1.237 billion) 248 265 Property, plant and equipment — net $ 9,349 $ 12,288 Depreciation expense totaled $767 million , $1.154 billion and $1.231 billion for the years ended December 31, 2015, 2014 and 2013, respectively. Assets related to capital leases included above totaled $1 million and $51 million at December 31, 2015 and 2014, respectively, net of accumulated depreciation. In conjunction with the impairment charges taken in 2014 and 2015 (see Note 8), we reviewed the estimated useful life of the impaired generation facilities. The estimated remaining useful lives range from 17 to 54 years for the lignite/coal and nuclear fueled generation units. Those estimated lives are subject to change as market factors evolve, including changes in environmental regulation and wholesale electricity price forecasts. 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. We have established an estimated $69 million asset retirement obligation related to the Disposal of Coal Combustion Residuals from Electric Utilities rule for our existing facilities. The following table summarizes the changes to these obligations, reported in other current liabilities and other noncurrent liabilities and deferred credits in the consolidated balance sheets, for the years ended December 31, 2015 and 2014: Nuclear Plant Decommissioning Mining Land Reclamation Other Total Liability at January 1, 2014 $ 390 $ 98 $ 36 $ 524 Additions: Accretion 23 22 3 48 Incremental reclamation costs (a) — 127 — 127 Reductions: Payments — (82 ) (3 ) (85 ) Liability at December 31, 2014 $ 413 $ 165 $ 36 $ 614 Additions: Accretion 25 20 6 51 Adjustment for new cost estimate (b) 70 — — 70 Incremental reclamation costs (c) — 84 69 153 Reductions: Payments — (54 ) (4 ) (58 ) Liability at December 31, 2015 508 215 107 830 Less amounts due currently — (66 ) — (66 ) Noncurrent liability at December 31, 2015 $ 508 $ 149 $ 107 $ 764 ____________ (a) The increase in the mining reclamation liability of $127 million during 2014 was primarily due to final remediation for certain mines occurring sooner than previously estimated and increases in remediation cost estimates at other mining locations. (b) The adjustment for nuclear plant decommissioning resulted from a new cost estimate completed in the second quarter of 2015. Under applicable accounting standards, the liability is remeasured when significant changes in the amount or timing of cash flows occurs, and PUCT rules require a new cost estimate at least every five years. The increase in the liability was driven by increased security and fuel-handling costs. (c) The adjustment for other asset retirement obligations resulted from the effect on our estimated retirement obligation related to coal combustion residual facilities at our lignite/coal fueled generation facilities that arose from the CCR rule discussed above. Other Noncurrent Liabilities and Deferred Credits The balance of other noncurrent liabilities and deferred credits consists of the following: December 31, 2015 2014 Uncertain tax positions (including accrued interest) (Note 5) $ 41 $ 74 Asset retirement and mining reclamation obligations 764 560 Unfavorable purchase and sales contracts 543 566 Nuclear decommissioning fund excess over asset retirement obligation (Note 18) 409 479 Other, including retirement and other employee benefits 23 21 Total other noncurrent liabilities and deferred credits $ 1,780 $ 1,700 Unfavorable Purchase and Sales Contracts — The amortization of unfavorable purchase and sales contracts totaled $23 million , $23 million and $25 million for the years ended December 31, 2015, 2014 and 2013, respectively. 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 December 31, 2015 December 31, 2014 Debt: Carrying Amount Fair Value Carrying Amount Fair Value Borrowings under debtor-in-possession credit facility (Note 11) $ 1,425 $ 1,411 $ 1,425 $ 1,430 Long-term debt not subject to compromise, excluding capital lease obligations (Note 11) $ 49 $ 53 $ 76 $ 79 We determine fair value in accordance with accounting standards as discussed in Note 15, and at December 31, 2015, 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 as of December 31, 2015 is impractical, and the fair values will ultimately be decided through the Chapter 11 Cases. Supplemental Cash Flow Information Year Ended December 31, 2015 2014 2013 Cash payments related to: Interest paid (a) $ 1,302 $ 1,259 $ 2,695 Capitalized interest (11 ) (17 ) (25 ) Interest paid (net of capitalized interest) (a) $ 1,291 $ 1,242 $ 2,670 Income taxes $ 29 $ 33 $ 137 Reorganization items (b) $ 224 $ 93 $ — Noncash investing and financing activities: Effect of Parent's payment of interest on pushed-down debt $ — $ — $ 23 Construction expenditures (c) $ 75 $ 108 $ 45 Contribution to membership interests (Note 18) $ — $ 2 $ 2 Reduction of debt pushed down from EFH Corp. (Note 12) (d) $ — $ — $ (420 ) Debt extension transactions (e) $ — $ — $ (340 ) Debt assumed related to acquisition of combustion turbine trust interest $ — $ — $ (45 ) ____________ (a) Net of amounts received under interest rate swap agreements. For the years ended December 31, 2015 and 2014, this amount also includes amounts paid for adequate protection. (b) Represents cash payments for legal and other consulting services. (c) Represents end-of-period accruals. (d) For the year ended December 31, 2013, represents $838 million principal amount of EFH Corp. debt exchanged (at 50% ). See Note 12. (e) Principal amounts of incremental loans under the TCEH Term Loan Facilities issued in consideration for the extension of the maturity date of such facilities.

Supplemental Guarantor Condense

Supplemental Guarantor Condensed Financial Information	12 Months Ended
	Dec. 31, 2015
Supplemental Guarantor Condensed Financial Information [Abstract]
Supplemental Guarantor Condensed Financial Information	SUPPLEMENTAL GUARANTOR FINANCIAL INFORMATION At December 31, 2015 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). 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. The following tables have been prepared in accordance with SEC Regulation S-X Rule 3-10, Financial Statements of Guarantors and Issuers of Guaranteed Securities Registered or Being Registered in order to present the statements of consolidating income (loss) and of cash flows of EFCH (Parent), TCEH (Issuer), the Guarantors and the Non-Guarantors for the years ended December 31, 2015, 2014 and 2013 and the consolidating balance sheets at December 31, 2015 and December 31, 2014 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 December 31, 2015 and December 31, 2014 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 December 31, 2015 and December 31, 2014 (see Note 12). 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 December 31, 2015, 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 years ended December 31, 2015, 2014 and 2013. ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Consolidating Statements of Income (Loss) Year Ended December 31, 2015 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Operating revenues $ — $ — $ 5,370 $ — $ — $ 5,370 Fuel, purchased power costs and delivery fees — — (2,692 ) — — (2,692 ) Net gain from commodity hedging and trading activities — — 334 — — 334 Operating costs — — (834 ) — — (834 ) Depreciation and amortization — (8 ) (844 ) — — (852 ) Selling, general and administrative expenses — 5 (681 ) — — (676 ) Impairment of goodwill — (2,200 ) — — — (2,200 ) Impairment of long-lived assets — — (2,541 ) — — (2,541 ) Other income — — 12 5 — 17 Other deductions — (2 ) (91 ) — — (93 ) Interest income — 26 125 — (151 ) — Interest expense and related charges (6 ) (1,419 ) (19 ) — 151 (1,293 ) Reorganization items 100 (1,428 ) 1,327 — — (1 ) Income (loss) before income taxes 94 (5,026 ) (534 ) 5 — (5,461 ) Income tax benefit (expense) (20 ) 697 164 (4 ) 21 858 Equity earnings (losses) of subsidiaries (4,677 ) (348 ) 1 — 5,024 — Net income (loss) (4,603 ) (4,677 ) (369 ) 1 5,045 (4,603 ) Net income (loss) attributable to noncontrolling interests — — — — — — Net income (loss) attributable to EFCH $ (4,603 ) $ (4,677 ) $ (369 ) $ 1 $ 5,045 $ (4,603 ) Consolidating Statements of Comprehensive Income (Loss) Year Ended December 31, 2015 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Net income (loss) (4,603 ) (4,677 ) (369 ) 1 5,045 (4,603 ) Other comprehensive income 2 2 — — (2 ) 2 Comprehensive income (loss) (4,601 ) (4,675 ) (369 ) 1 5,043 (4,601 ) Comprehensive income (loss) attributable to noncontrolling interests — — — — — — Comprehensive income (loss) attributable to EFCH $ (4,601 ) $ (4,675 ) $ (369 ) $ 1 $ 5,043 $ (4,601 ) ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Consolidating Statements of Income (Loss) Year Ended December 31, 2014 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Operating revenues $ — $ — $ 5,978 $ — $ — $ 5,978 Fuel, purchased power costs and delivery fees — — (2,842 ) — — (2,842 ) Net gain (loss) from commodity hedging and trading activities — (90 ) 101 — — 11 Operating costs — — (914 ) — — (914 ) Depreciation and amortization — — (1,270 ) — — (1,270 ) Selling, general and administrative expenses — (29 ) (677 ) (2 ) — (708 ) Impairment of goodwill — (1,600 ) — — — (1,600 ) Impairment of long-lived assets — — (4,670 ) — — (4,670 ) Other income — — 14 2 — 16 Other deductions — (4 ) (277 ) — — (281 ) Interest income 1 81 285 — (367 ) — Interest expense and related charges (10 ) (2,045 ) (802 ) — 1,099 (1,758 ) Reorganization items — (500 ) (21 ) — — (521 ) Income (loss) before income taxes (9 ) (4,187 ) (5,095 ) — 732 (8,559 ) Income tax benefit (expense) 9 846 1,710 1 (236 ) 2,330 Equity earnings (losses) of subsidiaries (6,229 ) (2,888 ) 1 — 9,116 — Net income (loss) (6,229 ) (6,229 ) (3,384 ) 1 9,612 (6,229 ) Net income (loss) attributable to noncontrolling interests — — — — — — Net income (loss) attributable to EFCH $ (6,229 ) $ (6,229 ) $ (3,384 ) $ 1 $ 9,612 $ (6,229 ) Consolidating Statements of Comprehensive Income (Loss) Year Ended December 31, 2014 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Net income (loss) (6,229 ) (6,229 ) (3,384 ) 1 9,612 (6,229 ) Other comprehensive income 1 1 — — (1 ) 1 Comprehensive income (loss) (6,228 ) (6,228 ) (3,384 ) 1 9,611 (6,228 ) Comprehensive income (loss) attributable to noncontrolling interests — — — — — — Comprehensive income (loss) attributable to EFCH $ (6,228 ) $ (6,228 ) $ (3,384 ) $ 1 $ 9,611 $ (6,228 ) ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Consolidating Statements of Income (Loss) Year Ended December 31, 2013 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Operating revenues $ — $ — $ 5,899 $ 59 $ (59 ) $ 5,899 Fuel, purchased power costs and delivery fees — — (2,848 ) — — (2,848 ) Net gain (loss) from commodity hedging and trading activities — (56 ) 2 — — (54 ) Operating costs — — (881 ) — — (881 ) Depreciation and amortization — — (1,333 ) — — (1,333 ) Selling, general and administrative expenses — (64 ) (723 ) (28 ) 59 (756 ) Impairment of goodwill — (1,000 ) — — — (1,000 ) Impairment of long-lived assets — — — (140 ) — (140 ) Other income — — 9 — — 9 Other deductions — — (22 ) — — (22 ) Interest income 1 243 795 — (1,034 ) 5 Interest expense and related charges (19 ) (2,716 ) (2,462 ) (10 ) 3,274 (1,933 ) Income (loss) before income taxes (18 ) (3,593 ) (1,564 ) (119 ) 2,240 (3,054 ) Income tax benefit (expense) 5 828 664 4 (764 ) 737 Equity earnings (losses) of subsidiaries (2,304 ) 461 (23 ) — 1,866 — Net loss (2,317 ) (2,304 ) (923 ) (115 ) 3,342 (2,317 ) Net loss attributable to noncontrolling interests 107 107 — 107 (214 ) 107 Net loss attributable to EFCH $ (2,210 ) $ (2,197 ) $ (923 ) $ (8 ) $ 3,128 $ (2,210 ) Consolidating Statements of Comprehensive Income (Loss) Year Ended December 31, 2013 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Net loss (2,317 ) (2,304 ) (923 ) (115 ) 3,342 (2,317 ) Other comprehensive income 6 6 — — (6 ) 6 Comprehensive loss (2,311 ) (2,298 ) (923 ) (115 ) 3,336 (2,311 ) Comprehensive loss attributable to noncontrolling interests 107 107 — 107 (214 ) 107 Comprehensive income (loss) attributable to EFCH $ (2,204 ) $ (2,191 ) $ (923 ) $ (8 ) $ 3,122 $ (2,204 ) ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Consolidating Statements of Cash Flows Year Ended December 31, 2015 (millions of dollars) Parent/ Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Cash provided by (used in) operating activities $ (8 ) $ (1,607 ) $ 1,846 $ (2 ) $ — $ 229 Cash flows – financing activities: Fees paid for DIP Facility — (9 ) — — — (9 ) Notes/advances due to affiliates 21 1,297 — 2 (1,320 ) — Repayments/repurchases of debt (13 ) — (21 ) — — (34 ) Cash provided by (used in) financing activities 8 1,288 (21 ) 2 (1,320 ) (43 ) Cash flows – investing activities: Capital expenditures — (2 ) (335 ) — — (337 ) Nuclear fuel purchases — — (123 ) — — (123 ) Settlements of notes due from affiliates — — (1,336 ) — 1,320 (16 ) Changes in restricted cash — (124 ) 1 — — (123 ) Proceeds from sales of nuclear decommissioning trust fund securities — — 401 — — 401 Investments in nuclear decommissioning trust fund securities — — (418 ) — — (418 ) Other, net — (13 ) (9 ) 9 — (13 ) Cash provided by (used in) investing activities — (139 ) (1,819 ) 9 1,320 (629 ) Net change in cash and cash equivalents — (458 ) 6 9 — (443 ) Cash and cash equivalents – beginning balance — 1,826 16 1 — 1,843 Cash and cash equivalents – ending balance $ — $ 1,368 $ 22 $ 10 $ — $ 1,400 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Consolidating Statements of Cash Flows Year Ended December 31, 2014 (millions of dollars) Parent/ Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Cash provided by (used in) operating activities $ (7 ) $ (1,498 ) $ 1,947 $ (5 ) $ — $ 437 Cash flows – financing activities: Proceeds from DIP Facility — 1,425 — — — 1,425 Fees paid for DIP Facility — (92 ) — — — (92 ) Notes/advances due to affiliates 19 1,462 — — (1,481 ) — Repayments/repurchases of long-term debt (12 ) (203 ) (20 ) — — (235 ) Contributions from noncontrolling interests — — — 1 — 1 Cash provided by (used in) financing activities 7 2,592 (20 ) 1 (1,481 ) 1,099 Cash flows – investing activities: Capital expenditures — — (336 ) — — (336 ) Nuclear fuel purchases — — (77 ) — — (77 ) Settlements of notes due from affiliates — — (1,496 ) — 1,481 (15 ) Purchase of right to use certain computer-related assets from parent — — (4 ) — — (4 ) Changes in restricted cash — 44 (2 ) — — 42 Proceeds from sales of nuclear decommissioning trust fund securities — — 314 — — 314 Investments in nuclear decommissioning trust fund securities — — (331 ) — — (331 ) Other, net — (37 ) 5 — — (32 ) Cash provided by (used in) investing activities — 7 (1,927 ) — 1,481 (439 ) Net change in cash and cash equivalents — 1,101 — (4 ) — 1,097 Cash and cash equivalents – beginning balance — 725 16 5 — 746 Cash and cash equivalents – ending balance $ — $ 1,826 $ 16 $ 1 $ — $ 1,843 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Consolidating Statements of Cash Flows Year Ended December 31, 2013 (millions of dollars) Parent/ Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Cash provided by (used in) operating activities $ (1 ) $ (1,643 ) $ 1,458 $ (85 ) $ — $ (271 ) Cash flows – financing activities: Repayments/repurchases of long-term debt (11 ) (64 ) (30 ) — — (105 ) Net short-term borrowings under accounts receivable securitization program — — — (82 ) — (82 ) Contributions from parent — — — 136 (136 ) — Other, net 12 1,461 — (4 ) (1,456 ) 13 Cash provided by (used in) financing activities 1 1,397 (30 ) 50 (1,592 ) (174 ) Cash flows – investing activities: Capital expenditures — — (467 ) (5 ) — (472 ) Nuclear fuel purchases — — (116 ) — — (116 ) Notes/loans due from affiliates — — (758 ) — 1,456 698 Investment in subsidiary — (146 ) 10 — 136 — Purchase of right to use certain computer-related assets from parent — — (29 ) — — (29 ) Acquisition of combustion turbine trust interest — — (40 ) — (40 ) Changes in restricted cash — 2 — — — 2 Proceeds from sales of nuclear decommissioning trust fund securities — — 175 — — 175 Investments in nuclear decommissioning trust fund securities — — (191 ) — — (191 ) Other, net — — (11 ) — — (11 ) Cash provided by (used in) investing activities — (144 ) (1,427 ) (5 ) 1,592 16 Net change in cash and cash equivalents — (390 ) 1 (40 ) — (429 ) Cash and cash equivalents – beginning balance — 1,115 15 45 — 1,175 Cash and cash equivalents – ending balance $ — $ 725 $ 16 $ 5 $ — $ 746 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION 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 Advance 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 Advance to parent — 18 — — — 18 Investments (32,818 ) 9,095 983 5 23,697 962 Property, plant and equipment – net — 12 9,334 3 — 9,349 Goodwill — 152 — — — 152 Identifiable intangible assets – net — 31 1,148 — — 1,179 Accumulated deferred income taxes — 438 393 11 (842 ) — Other noncurrent assets — 1 38 — — 39 Total assets $ (32,818 ) $ 12,242 $ 13,412 $ 29 $ 22,763 $ 15,628 LIABILITIES AND EQUITY 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 Accrued taxes other than income — — 98 — — 98 Accrued interest — 119 1 — — 120 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 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 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Consolidating Balance Sheets December 31, 2014 (millions of dollars) Parent Issuer Other Non-guarantors Eliminations Consolidated ASSETS Current assets: Cash and cash equivalents $ — $ 1,826 $ 16 $ 1 $ — $ 1,843 Restricted cash — — 2 — — 2 Advances to affiliates — 8 1,179 — (1,179 ) 8 Trade accounts receivable – net — — 588 — — 588 Income taxes receivable — 176 — — (176 ) — Inventories — — 468 — — 468 Commodity and other derivative contractual assets — — 492 — — 492 Other current assets — 9 59 — — 68 Total current assets — 2,019 2,804 1 (1,355 ) 3,469 Restricted cash — 901 — — — 901 Advance to affiliates — 7 — — — 7 Investments (28,114 ) 10,845 958 8 17,244 941 Property, plant and equipment – net — 34 12,251 3 — 12,288 Goodwill — 2,352 — — — 2,352 Identifiable intangible assets – net — 14 1,322 — — 1,336 Accumulated deferred income taxes — 757 — 15 (772 ) — Other noncurrent assets, principally unamortized amendment/issuance costs — 3 36 — — 39 Total assets $ (28,114 ) $ 16,932 $ 17,371 $ 27 $ 15,117 $ 21,333 LIABILITIES AND EQUITY Current liabilities: Notes/advances from affiliates $ 8 $ 1,171 $ — $ — $ (1,179 ) $ — Long-term debt due currently 13 — 22 — — $ 35 Trade accounts payable — 7 375 — — 382 Trade accounts and other payables to affiliates 2 7 154 2 — 165 Commodity and other derivative contractual liabilities — — 316 — — 316 Margin deposits related to commodity positions — — 26 — — 26 Accumulated deferred income taxes 24 47 43 — — 114 Accrued income taxes payable to parent — — 192 — (176 ) 16 Accrued taxes other than income — — 107 — — 107 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Consolidating Balance Sheets December 31, 2014 (millions of dollars) Parent Issuer Other Non-guarantors Eliminations Consolidated Accrued interest — 116 1 — — 117 Other current liabilities — 37 227 — — 264 Total current liabilities 47 1,385 1,463 2 (1,355 ) 1,542 Borrowings under debtor-in-possession credit facilities — 1,425 — — — 1,425 Long-term debt, less amounts due currently 34 — 51 — — 85 Liabilities subject to compromise 144 42,239 32,581 — (40,931 ) 34,033 Accumulated deferred income taxes 40 — 944 — 38 1,022 Other noncurrent liabilities and deferred credits — (3 ) 1,703 — — 1,700 Total liabilities 265 45,046 36,742 2 (42,248 ) 39,807 EFCH membership interests (28,379 ) (28,114 ) (19,371 ) 25 57,365 (18,474 ) Noncontrolling interests in subsidiaries — — — — — — Total membership interests (28,379 ) (28,114 ) (19,371 ) 25 57,365 (18,474 ) Total liabilities and membership interests $ (28,114 ) $ 16,932 $ 17,371 $ 27 $ 15,117 $ 21,333

Business And Significant Acco29

Business And Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Basis of Presentation	The consolidated financial statements have been prepared in accordance with US GAAP. The 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 consolidated financial statements reflect the application of Financial Accounting Standards Board Accounting Standards Codification (ASC) 852, Reorganizations . 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 10 and 12 for discussion of these accounting and reporting changes. All intercompany items and transactions have been eliminated in consolidation. 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.
Derivative Instruments and Mark-to-Market Accounting	We enter into contracts for the purchase and sale of electricity, natural gas, coal, uranium and other commodities and also enter into other derivative instruments such as options, swaps, futures and forwards primarily to manage our commodity price and interest rate risks. If the instrument meets the definition of a derivative under accounting standards related to derivative instruments and hedging activities, changes in the fair value of the derivative are recognized in net income as unrealized gains and losses, unless the criteria for certain exceptions are met, and an offsetting derivative asset or liability is recorded in the consolidated balance sheets. This recognition is referred to as mark-to-market accounting. The fair values of our unsettled derivative instruments under mark-to-market accounting are reported in the consolidated balance sheets as commodity and other derivative contractual assets or liabilities. We report derivative assets and liabilities in the consolidated balance sheets without taking into consideration netting arrangements we have with counterparties. Margin deposits that contractually offset these assets and liabilities are reported separately in the consolidated balance sheets. When derivative instruments are settled and realized gains and losses are recorded, the previously recorded unrealized gains and losses and derivative assets and liabilities are reversed. See Notes 15 and 16 for additional information regarding fair value measurement and commodity and other derivative contractual assets and liabilities. Under the election criteria of accounting standards related to derivative instruments and hedging activities, we may elect the normal purchase and sale exemption. A commodity-related derivative contract may be designated as a normal purchase or sale if the commodity is to be physically received or delivered for use or sale in the normal course of business. If designated as normal, the derivative contract is accounted for under the accrual method of accounting (not marked-to-market) with no balance sheet or income statement recognition of the contract until settlement. Because derivative instruments are frequently used as economic hedges, accounting standards related to derivative instruments and hedging activities allow for hedge accounting, which provides for the designation of such instruments as cash flow or fair value hedges if certain conditions are met. At December 31, 2015 and 2014, there were no derivative positions accounted for as cash flow or fair value hedges. Accumulated other comprehensive loss includes amounts related to interest rate swaps previously designated as cash flow hedges that are being reclassified to net loss as the hedged transactions impact net loss (see Note 16). Realized and unrealized gains and losses from transacting in energy-related derivative instruments are primarily reported in the statements of consolidated income (loss) in net gain (loss) from commodity hedging and trading activities.
Revenue Recognition	We record revenue from electricity sales under the accrual method of accounting. Revenues are recognized when electricity is provided to customers on the basis of periodic cycle meter readings and include an estimated accrual for the revenues earned from the meter reading date to the end of the period (unbilled revenue). We report physically delivered commodity sales and purchases in the statements of consolidated income (loss) on a gross basis in revenues and fuel, purchased power and delivery fees, respectively, and we report all other commodity related contracts and financial instruments (primarily derivatives) in the statements of consolidated income (loss) on a net basis in net gain (loss) from commodity hedging and trading activities. Volumes under bilateral purchase and sales contracts, including contracts intended as hedges, are not scheduled as physical power with ERCOT. Accordingly, unless the volumes represent physical deliveries to customers or purchases from counterparties, such contracts are reported net in the statements of consolidated income (loss) in net gain (loss) from commodity hedging and trading activities instead of reported gross as wholesale revenues or purchased power costs. If volumes delivered to our retail and wholesale customers are less than our generation volumes (as determined on a daily settlement basis), we record additional wholesale revenues, and if volumes delivered to our retail and wholesale customers exceed our generation volumes, we record additional purchased power costs. The additional wholesale revenues or purchased power costs are offset in net gain (loss) from commodity hedging and trading activities.
Impairment of Long-Lived Assets	We evaluate long-lived assets (including intangible assets with finite lives) for impairment whenever indications of impairment exist. The carrying value of such assets is deemed to be impaired if the projected undiscounted cash flows are less than the carrying value. If there is such impairment, a loss would be recognized based on the amount by which the carrying value exceeds the fair value. Fair value is determined primarily by discounted cash flows, supported by available market valuations, if applicable. See Note 8 for discussion of impairments of certain long-lived assets. Finite-lived intangibles identified as a result of purchase accounting are amortized over their estimated useful lives based on the expected realization of economic effects. See Note 4 for additional information.
Goodwill and Intangible Assets with Indefinite Lives	We evaluate goodwill and intangible assets with indefinite lives for impairment at least annually (at December 1), or when indications of impairment exist. See Note 4 for details of goodwill and intangible assets with indefinite lives, including discussion of fair value determinations and goodwill impairments.
Amortization of Nuclear Fuel	Amortization of nuclear fuel is calculated on the units-of-production method and is reported as fuel costs.
Major Maintenance	Major maintenance costs incurred during generation plant outages and the costs of other maintenance activities are charged to expense as incurred and reported as operating costs.
Defined Benefit Pension Plans and OPEB Plans	We bear a portion of the costs of the EFH Corp. sponsored pension and OPEB plans offering certain health care and life insurance benefits to eligible employees and their eligible dependents upon the retirement of such employees from the company and also offer pension benefits to eligible employees under collective bargaining agreements based on either a traditional defined benefit formula or a cash balance formula. Costs of pension and OPEB plans are dependent upon numerous factors, assumptions and estimates. Under multiemployer plan accounting, EFH Corp. has elected to not allocate retirement plan assets and liabilities to us. See Note 17 for additional information regarding pension and OPEB plans
Sales and Excise Taxes	Sales and excise taxes are accounted for as a "pass through" item on the consolidated balance sheets with no effect on the statements of consolidated income (loss); i.e., the tax is billed to customers and recorded as trade accounts receivable with an offsetting amount recorded as a liability to the taxing jurisdiction.
Franchise and Revenue-Based Taxes	Unlike sales and excise taxes, franchise and gross receipt taxes are not a "pass through" item. These taxes are assessed to us by state and local government bodies, based on revenues or kWh delivered, as a cost of doing business and are recorded as an expense. Rates we charge to customers are intended to recover our costs, including the franchise and gross receipt taxes, but we are not acting as an agent to collect the taxes from customers. We report franchise and revenue-based taxes in SG&A expense in our statements of consolidated income (loss).
Income Taxes	EFH Corp. files a consolidated US federal income tax return that includes the results of EFCH and TCEH; however, our income tax expense and related balance sheet amounts are recorded as if we file separate corporate income tax returns. Deferred income taxes are provided for temporary differences between the book and tax basis of assets and liabilities as required under accounting rules. See Note 6. We report interest and penalties related to uncertain tax positions as current income tax expense. See Note 5.
Accounting for Contingencies	Our financial results may be affected by judgments and estimates related to loss contingencies. Accruals for loss contingencies are recorded when management determines that it is probable that an asset has been impaired or a liability has been incurred and that such economic loss can be reasonably estimated. Such determinations are subject to interpretations of current facts and circumstances, forecasts of future events and estimates of the financial impacts of such events. As part of our Chapter 11 Cases we have received numerous pre-petition claims, many of which are unsubstantiated or irrelevant to our business operations. Further, at this time, some of those claims might be relevant but are not reasonably estimable. See Notes 2 and 13 for a discussion of contingencies.
Restricted Cash	The terms of certain agreements require the restriction of cash for specific purposes. See Notes 11, 12 and 19 for more details regarding restricted cash.
Property, Plant and Equipment	As a result of purchase accounting, carrying amounts of property, plant and equipment were adjusted to estimated fair values at the Merger date. Subsequent additions have been recorded at cost. The cost of self-constructed property additions includes materials and both direct and indirect labor and applicable overhead, including payroll-related costs. Interest related to qualifying construction projects and qualifying software projects is capitalized in accordance with accounting guidance related to capitalization of interest cost. See Note 9. Depreciation of our property, plant and equipment is calculated on a straight-line basis over the estimated service lives of the properties. Depreciation expense is calculated on a component asset-by-asset basis. Estimated depreciable lives are based on management's estimates of the assets' economic useful lives. See Note 19.
Asset Retirement Obligations	A liability is initially recorded at fair value for an asset retirement obligation associated with the retirement of tangible long-lived assets in the period in which it is incurred if a fair value is reasonably estimable. 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. Over time, the liability is accreted for the change in present value and the initial capitalized costs are depreciated over the remaining useful lives of the assets. See Note 19.
Inventories	Inventories are reported at the lower of cost (on a weighted average basis) or market unless expected to be used in the generation of electricity.
Investments	Investments in a nuclear decommissioning trust fund are carried at current market value in the consolidated balance sheets. Assets related to employee benefit plans represent investments held to satisfy deferred compensation liabilities and are recorded at current market value. See Note 19 for discussion of these and other investments.
Noncontrolling Interests	See Notes 8 and 14 for discussion of accounting for noncontrolling interests in subsidiaries.
Push-Down of EFH Corp. Debt	In accordance with SEC Staff Accounting Bulletin (SAB) Topic 5-J, we reflect amounts of certain EFH Corp. senior notes on our balance sheets and the related interest expense in our income statement. The amount reflected on our balance sheet was calculated based upon the relative equity investment of EFCH and EFIH in their respective operating subsidiaries at the time of the Merger (see Note 12).

Goodwill And Identifiable Int30

Goodwill And Identifiable Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2015
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 through 2014 (15,970 ) Balance at December 31, 2014 2,352 Additional noncash impairment charges in 2015 (2,200 ) Balance at December 31, 2015 (a) $ 152 ___________ (a) Net of accumulated impairment charges totaling $18.170 billion .
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: December 31, 2015 December 31, 2014 Identifiable Intangible Asset Gross Carrying Amount Accumulated Amortization Net Gross Carrying Amount Accumulated Amortization Net Retail customer relationship $ 463 $ 442 $ 21 $ 463 $ 425 $ 38 Software and other technology-related assets 385 224 161 369 202 167 Other identifiable intangible assets (a) 72 35 37 460 291 169 Total identifiable intangible assets subject to amortization $ 920 $ 701 219 $ 1,292 $ 918 374 Retail trade name (not subject to amortization) 955 955 Mineral interests (not currently subject to amortization) 5 7 Total identifiable intangible assets $ 1,179 $ 1,336
Schedule of amortization expense related to intangible assets (including income statement line item)	Amortization expense related to finite-lived identifiable intangible assets (including the statements of consolidated income (loss) line item) consisted of: Identifiable Intangible Asset Statements of Consolidated Income (Loss) Line Remaining useful lives at December 31, 2015 (weighted average in years) Year Ended December 31, 2015 2014 2013 Retail customer relationship Depreciation and amortization 2 $ 17 $ 23 $ 24 Software and other technology-related assets Depreciation and amortization 3 60 59 47 Other identifiable intangible assets Operating revenues/fuel, purchased power costs and delivery fees/depreciation and amortization 8 30 88 69 Total amortization expense (a) $ 107 $ 170 $ 140 ____________ (a) Amounts recorded in depreciation and amortization totaled $85 million , $116 million and $102 million in 2015, 2014 and 2013, 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 $ 72 2017 $ 60 2018 $ 36 2019 $ 22 2020 $ 11

Accounting For Uncertainty In31

Accounting For Uncertainty In Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2015
Accounting for Uncertainty in Income Taxes [Abstract]
Summary of changes to the uncertain tax positions, reported in other noncurrent liabilities in the consolidated balance sheet	The following table summarizes the changes to the uncertain tax positions, reported in other noncurrent liabilities in the consolidated balance sheets, during the years ended December 31, 2015, 2014 and 2013: Year Ended December 31, 2015 2014 2013 Balance at January 1, excluding interest and penalties $ 65 $ 193 $ 1,078 Additions based on tax positions related to prior years — 55 246 Reductions based on tax positions related to prior years (11 ) (164 ) (1,070 ) Additions based on tax positions related to the current year — — 13 Settlements with taxing authorities (18 ) (19 ) (74 ) Balance at December 31, excluding interest and penalties $ 36 $ 65 $ 193

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Schedule of components of our income tax expense (benefit) applicable to continuing operations	The components of our income tax benefit are as follows: Year Ended December 31, 2015 2014 2013 Current: US Federal $ 68 $ 43 $ (166 ) State 21 29 41 Total current 89 72 (125 ) Deferred: US Federal (875 ) (2,385 ) (611 ) State (72 ) (17 ) (1 ) Total deferred (947 ) (2,402 ) (612 ) Total $ (858 ) $ (2,330 ) $ (737 )
Reconciliation of income taxes computed at the US federal statutory rate to income tax expense	Reconciliation of income taxes computed at the US federal statutory rate to income tax benefit recorded is as follows: Year Ended December 31, 2015 2014 2013 Loss before income taxes $ (5,461 ) $ (8,559 ) $ (3,054 ) Income taxes at the US federal statutory rate of 35% $ (1,911 ) $ (2,996 ) $ (1,069 ) IRS audit and appeals settlements — 46 (80 ) Nondeductible goodwill impairment 770 560 350 Texas margin tax, net of federal benefit — 10 8 Lignite depletion allowance (8 ) (14 ) (12 ) Interest accrued for uncertain tax positions, net of tax (2 ) — (17 ) Nondeductible interest expense 22 21 21 Nondeductible debt restructuring costs 64 42 4 Impairment of joint venture assets attributable to noncontrolling interests (Note 8) — — 37 Valuation allowance 191 — — Other 16 1 21 Income tax benefit $ (858 ) $ (2,330 ) $ (737 ) Effective tax rate 15.7 % 27.2 % 24.1 %
Schedule of deferred tax assets and liabilities	Deferred income taxes provided for temporary differences based on tax laws in effect at December 31, 2015 and 2014 are as follows: 2015 2014 Total Noncurrent (a) Total Current Noncurrent Deferred Income Tax Assets Alternative minimum tax credit carryforwards $ 22 $ 22 $ — $ 22 Net operating loss (NOL) carryforwards 413 719 — 719 Unfavorable purchase and sales contracts 193 202 — 202 Commodity contracts and interest rate swaps 125 6 — 6 Debt extinguishment gains 1,116 873 — 873 Employee benefit obligations 51 54 2 52 Accrued interest — 88 — 88 Other 59 41 2 39 Total 1,979 2,005 4 2,001 Deferred Income Tax Liabilities Property, plant and equipment 1,540 2,465 — 2,465 Commodity contracts and interest rate swaps — 44 44 — Identifiable intangible assets 321 362 — 362 Debt fair value discounts — 196 — 196 Debt extinguishment gains — 74 74 — Accrued interest 140 — — — Total 2,001 3,141 118 3,023 Valuation allowance $ 191 — $ — $ — Net Accumulated Deferred Income Tax (Asset) Liability $ 213 $ 1,136 $ 114 $ 1,022 ____________ (a) Reflects adoption of ASU 2015-17, Balance Sheet Classification of Deferred Taxes . See Note 1.

Other Income and Deductions (Ta

Other Income and Deductions (Tables)	12 Months Ended
	Dec. 31, 2015
Other Income and Expenses [Abstract]
Schedule of other income and deductions	OTHER INCOME AND DEDUCTIONS Year Ended December 31 2015 2014 2013 Other income: Mineral rights royalty income $ 4 $ 4 $ 5 All other 13 12 4 Total other income $ 17 $ 16 $ 9 Other deductions: Impairment of favorable purchase contracts (Note 4) $ 8 $ 183 $ — Impairment of emission allowances (Note 4) 55 80 — Impairment of mining development costs (Note 4) 19 — — All other 11 18 22 Total other deductions $ 93 $ 281 $ 22

Interest Expense and Related 34

Interest Expense and Related Charges (Tables)	12 Months Ended
	Dec. 31, 2015
Interest Expense and Related Charges [Abstract]
Schedule of interest expense and related charges	Year Ended December 31, 2015 2014 2013 Interest paid/accrued on debtor-in-possession financing $ 63 $ 37 $ — Adequate protection amounts paid/accrued (a) 1,233 828 — Interest paid/accrued on pre-petition debt (b) 8 886 2,724 Interest related to pushed down debt — 1 6 Noncash realized net loss on termination of interest rate swaps (offset in unrealized net gain) (c) — 1,225 — Unrealized mark-to-market net gain on interest rate swaps — (1,290 ) (1,053 ) Amortization of debt issuance, amendment and extension costs and discounts — 86 264 Capitalized interest (11 ) (17 ) (25 ) Other — 2 17 Total interest expense and related charges $ 1,293 $ 1,758 $ 1,933 ____________ (a) Post-petition period only. (b) Includes amounts related to interest rate swaps totaling $193 million and $621 million for the years ended December 31, 2014 and 2013, respectively. Of the $193 million for the year ended December 31, 2014, $127 million is included in the liability arising from the termination of TCEH interest rate swaps discussed in Note 16. (c) See Note 16.

Reorganization Items (Tables)

Reorganization Items (Tables)	12 Months Ended
	Dec. 31, 2015
Reorganization Items [Abstract]
Schedule of Reorganization Items	The following table presents reorganization items incurred in the year ended December 31, 2015 and the post-petition period ended December 31, 2014 as reported in the statements of consolidated income (loss): Twelve Months Ended December 31, 2015 Post-Petition Period Ended Expenses related to legal advisory and representation services $ 141 $ 65 Expenses related to other professional consulting and advisory services 69 67 Contract claims adjustments 54 20 Noncash adjustment for estimated allowed claims related to debt (Note 12) 897 — Adjustment to affiliate claims pursuant to settlement agreement (Note 18) (736 ) — Gain on settlement of debt held by affiliates (Note 18) (382 ) — Gain on settlement of interest on debt held by affiliates (20 ) — Sponsor management agreement settlement (Notes 2 and 18) (19 ) — Contract assumption adjustments (14 ) — Noncash liability adjustment arising from termination of interest rate swaps (Note 12) — 277 Fees associated with extension/completion of the DIP Facility 9 92 Other 2 — Total reorganization items $ 1 $ 521

Debtor-In-Possession Borrowin36

Debtor-In-Possession Borrowing Facility and Long-Term Debt Not Subject to Compromise Debtor-In-Possession Borrowing Facility (Tables)	12 Months Ended
	Dec. 31, 2015
Debtor-In-Possession Obligations [Abstract]
Schedule of Line of Credit Facilities	The DIP Facility and related available capacity at December 31, 2015 are presented below. Borrowings are reported in the consolidated balance sheets as borrowings under the debtor-in-possession credit facility. In October 2015, the TCEH Debtors paid an $8 million extension fee and extended the maturity date of the DIP Facility to the earlier of (a) November 2016 or (b) the effective date of any reorganization plan of TCEH. The terms of the facility were otherwise unchanged by the extension. In September 2015, the TCEH Debtors extended their use of cash collateral to the earlier of (a) the effective date of a plan of reorganization or (b) 60 days following termination of the Debtors' Plan Support Agreement, provided that the TCEH Debtors do not otherwise cause an event of default under the cash collateral order. The DIP Facility must be repaid in full prior to the TCEH Debtors emergence from the Chapter 11 Cases. December 31, 2015 DIP Facility Facility Limit Available Cash Borrowing Capacity Available Letter of Credit Capacity TCEH DIP Revolving Credit Facility (a) $ 1,950 $ 1,950 $ — TCEH DIP Term Loan Facility (b) 1,425 — 281 Total DIP Facility $ 3,375 $ 1,950 $ 281 ___________ (a) Facility used for general corporate purposes. No amounts were borrowed at December 31, 2015. Pursuant to an order of the Bankruptcy Court, the TCEH Debtors may not have more than $1.650 billion of TCEH 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.

Liabilities Subject To Compromi

Liabilities Subject To Compromise (Tables)	12 Months Ended
	Dec. 31, 2015
Debt and Capital Lease Obligations [Abstract]
Schedule of Long-term Debt Instruments	Amounts presented below represent principal amounts of pre-petition notes, loans and other debt reported as liabilities subject to compromise. December 31, 2015 2014 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 (a) 15,691 15,710 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 (a) 1,833 2,046 10.25% Fixed Senior Notes due November 1, 2015, Series B (a) 1,292 1,442 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 Unamortized fair value discount related to pollution control revenue bonds (b) — (103 ) Other: Other 1 1 Unamortized discount — (91 ) Total TCEH 31,668 31,856 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 Unamortized fair value discount — (1 ) Subtotal 9 8 December 31, 2015 2014 EFH Corp. pre-petition debt pushed down (c) 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. pre-petition debt pushed down 30 30 Total EFCH (parent entity) 39 38 Deferred debt issuance and extension costs (d) — (702 ) Total EFCH consolidated notes, loans and other debt $ 31,707 $ 31,192 ____________ (a) As discussed below and in Note 18, principal amounts of notes/term loans totaling $382 million at December 31, 2014 were held by EFH Corp. and EFIH. The amounts of TCEH debt held by EFIH or EFH Corp. were eliminated as a result of the Settlement Agreement approved by the Bankruptcy Court in December 2015. (b) Amount represents unamortized fair value adjustments recorded under purchase accounting. (c) 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 . (d) Due to the Settlement Agreement our pre-petition notes, loans and other debt reported as liabilities subject to compromise were updated to reflect our expected allowed claim amounts, resulting in the write-off to reorganization items of unamortized deferred debt issuance and extension costs, premiums and discounts classified as LSTC (see Note 10).
Liabilities Subject To Compromise	The following table presents LSTC as reported in the consolidated balance sheets at December 31, 2015 and 2014: December 31, 2015 2014 Notes, loans and other debt per the following table $ 31,707 $ 31,192 Accrued interest on notes, loans and other debt 648 668 Net liability under terminated TCEH interest rate swap and natural gas hedging agreements (Note 16) 1,243 1,235 Trade accounts payable and other expected allowed claims 177 179 Liability under the Federal and State Income Tax Allocation Agreement (Note 18) — 626 Advances and other payables to affiliates 1 133 Total liabilities subject to compromise $ 33,776 $ 34,033

Commitments And Contingencies (

Commitments And Contingencies (Tables)	12 Months Ended
	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Schedule of noncancellable commitments under energy-related contracts, leases and other agreements	At December 31, 2015, we had contractual commitments, some of which are subject to potential rejection in the Chapter 11 Cases, under energy-related contracts, leases and other agreements as follows: Coal purchase and transportation agreements Pipeline transportation and storage reservation fees Nuclear Fuel Contracts Other Contracts 2016 $ 307 $ 13 $ 62 $ 130 2017 — 1 46 42 2018 — 1 72 14 2019 — 1 35 12 2020 — 1 37 14 Thereafter — 7 96 36 Total $ 307 $ 24 $ 348 $ 248
Schedule of future minimum lease payments for capital leases and operating leases	At December 31, 2015, future minimum lease payments under both capital leases and operating leases are as follows: Capital Leases Operating Leases (a) 2016 $ 3 $ 24 2017 2 29 2018 — 27 2019 — 26 2020 — 25 Thereafter — 139 Total future minimum lease payments 5 $ 270 Less amounts representing interest — Present value of future minimum lease payments 5 Less current portion 3 Long-term capital lease obligation $ 2 ___________ (a) Includes operating leases with initial or remaining noncancellable lease terms in excess of one year.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2015
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: December 31, 2015 Level 1 Level 2 Level 3 (a) Total Assets: Commodity contracts $ 385 $ 41 $ 49 $ 475 Nuclear decommissioning trust – equity securities (b) 380 219 — 599 Nuclear decommissioning trust – debt securities (b) — 319 — 319 Total assets $ 765 $ 579 $ 49 $ 1,393 Liabilities: Commodity contracts $ 128 $ 64 $ 12 $ 204 Total liabilities $ 128 $ 64 $ 12 $ 204 December 31, 2014 Level 1 Level 2 Level 3 (a) Total Assets: Commodity contracts $ 402 $ 46 $ 49 $ 497 Nuclear decommissioning trust – equity securities (b) 375 217 — 592 Nuclear decommissioning trust – debt securities (b) — 301 — 301 Total assets $ 777 $ 564 $ 49 $ 1,390 Liabilities: Commodity contracts $ 278 $ 25 $ 14 $ 317 Total liabilities $ 278 $ 25 $ 14 $ 317 _______________ (a) See table below for description of Level 3 assets and liabilities. (b) The nuclear decommissioning trust investment is included in the investments line in the consolidated balance sheets. See Note 19.
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 December 31, 2015 and 2014: 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 congestion revenue rights 39 (4 ) 35 Market Approach (e) Illiquid price differences between settlement points (f) $0 to $10/MWh Other (i) 9 (7 ) 2 Total $ 49 $ (12 ) $ 37 December 31, 2014 Fair Value Contract Type (a) Assets Liabilities Total Valuation Technique Significant Unobservable Input Range (b) Electricity purchases and sales $ 4 $ (5 ) $ (1 ) Valuation Model Illiquid pricing locations (c) $30 to $50/MWh Hourly price curve shape (d) $20 to $70/MWh Electricity congestion revenue rights 38 (4 ) 34 Market Approach (e) Illiquid price differences between settlement points (f) $0 to $20/MWh Coal purchases — (4 ) (4 ) Market Approach (e) Illiquid price variances between mines (g) $0 to $1/ton Illiquid price variances between heat content (h) $0 to $1/ton Other (i) 7 (1 ) 6 Total $ 49 $ (14 ) $ 35 ____________ (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 congestion revenue rights contracts consist of forward purchase contracts (swaps and options) used to hedge electricity price differences between settlement points within ERCOT. Coal purchase contracts relate to western (Powder River Basin) coal. (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) While we use the market approach, there is either insufficient market data to consider the valuation liquid or the significance of credit reserves or non-performance risk adjustments results in a Level 3 designation. (f) Based on the historical price differences between settlement points within the ERCOT hubs and load zones. (g) Based on the historical range of price variances between mine locations. (h) Based on historical ranges of forward average prices between different heat contents (potential energy in coal for a given mass). (i) Other includes contracts for ancillary services, natural gas, power options, diesel options and coal options.
Schedule of changes in fair value of the Level 3 assets and liabilities (all related to commodity contracts)	The following table presents the changes in fair value of the Level 3 assets and liabilities for the years ended December 31, 2015, 2014 and 2013. Year Ended December 31, 2015 2014 2013 Net asset (liability) balance at beginning of period $ 35 $ (973 ) $ 29 Total unrealized valuation gains (losses) 27 (97 ) (48 ) Purchases, issuances and settlements (a): Purchases 49 63 92 Issuances (13 ) (5 ) (7 ) Settlements (48 ) 1,053 138 Transfers into Level 3 (b) 1 — (1,181 ) Transfers out of Level 3 (b) (14 ) (6 ) 4 Net change (c) 2 1,008 (1,002 ) Net asset (liability) balance at end of period $ 37 $ 35 $ (973 ) Unrealized valuation gains (losses) relating to instruments held at end of period $ 18 $ (5 ) $ 435 ____________ (a) Settlements reflect reversals of unrealized mark-to-market valuations previously recognized in net income. Purchases and issuances reflect option premiums paid or received. Settlement amounts in 2014 reflect termination of the TCEH interest rate swaps and include the reversal of a nonperformance risk adjustment as discussed in Note 16. (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 years presented are in and out of Level 2. Transfers into Level 3 during 2013 reflect a nonperformance risk adjustment in the valuation of the TCEH interest rate swaps, which were secured by a first-lien interest in the same assets of TCEH (on a pari passu basis) with the TCEH Senior Secured Facilities and the TCEH Senior Secured Notes (see Note 12). (c) Substantially all changes in values of commodity contracts are reported in the statements of consolidated income (loss) in net gain (loss) from commodity hedging and trading activities. Changes in values of interest rate swaps transferred into Level 3 in 2013 are reported in the statements of consolidated income (loss) in interest expense and related charges (see Note 9). 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 Derivativ40

Commodity And Other Derivative Contractual Assets And Liabilities (Tables)	12 Months Ended
	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Commodity and Other Derivative Contractual Assets and Liabilities as Reported in the Balance Sheets	Substantially all derivative contractual assets and liabilities arise from mark-to-market accounting consistent with accounting standards related to derivative instruments and hedging activities. The following tables provide detail of commodity and other derivative contractual assets and liabilities (with the column totals representing the net positions of the contracts) as reported in the consolidated balance sheets at December 31, 2015 and 2014 (noncurrent assets and liabilities are reported in other noncurrent assets and other noncurrent liabilities and deferred credits, respectively). All amounts relate to commodity contracts. December 31, 2015 December 31, 2014 Derivative Assets Derivative Liabilities Total Derivative Assets Derivative Liabilities Total Current assets $ 465 $ — $ 465 $ 492 $ — $ 492 Noncurrent assets 10 — 10 5 — 5 Current liabilities — (203 ) (203 ) — (316 ) (316 ) Noncurrent liabilities — (1 ) (1 ) — (1 ) (1 ) Net assets (liabilities) $ 475 $ (204 ) $ 271 $ 497 $ (317 ) $ 180
Schedule of Pre-tax Effect on Net Income of Derivatives Not Under Hedge Accounting, Including Realized and Unrealized Effects	The following table presents the pretax effect of derivatives on net income (gains (losses)), including realized and unrealized effects: Year Ended December 31, Derivative (statements of consolidated income (loss) presentation) 2015 2014 2013 Commodity contracts (Net gain (loss) from commodity hedging and trading activities) (a) $ 380 $ 17 $ (54 ) Interest rate swaps (Interest expense and related charges) (b) — (128 ) 433 Interest rate swaps (Reorganization items) (Note 10) — (277 ) — Net gain (loss) $ 380 $ (388 ) $ 379 _______________ (a) Amount represents changes in fair value of positions in the derivative portfolio during the period, as realized amounts related to positions settled are assumed to equal reversals of previously recorded unrealized amounts. (b) Includes unrealized mark-to-market net gain (loss) as well as the net realized effect on interest paid/accrued, both reported in Interest Expense and Related Charges (see Note 9).
Schedule of Pre-tax Effect on Net Income and Other Comprehensive Income (OCI) of Derivative Instruments Previously Accounted for as Cash Flow Hedges	The following table presents the pretax effect of derivatives on net income (gains (losses)), including realized and unrealized effects: Year Ended December 31, Derivative (statements of consolidated income (loss) presentation) 2015 2014 2013 Commodity contracts (Net gain (loss) from commodity hedging and trading activities) (a) $ 380 $ 17 $ (54 ) Interest rate swaps (Interest expense and related charges) (b) — (128 ) 433 Interest rate swaps (Reorganization items) (Note 10) — (277 ) — Net gain (loss) $ 380 $ (388 ) $ 379 _______________ (a) Amount represents changes in fair value of positions in the derivative portfolio during the period, as realized amounts related to positions settled are assumed to equal reversals of previously recorded unrealized amounts. (b) Includes unrealized mark-to-market net gain (loss) as well as the net realized effect on interest paid/accrued, both reported in Interest Expense and Related Charges (see Note 9).
Offsetting Assets and Liabilities [Table Text Block]	The following tables reconcile our derivative assets and liabilities as presented in the consolidated balance sheets to net amounts after taking into consideration netting arrangements with counterparties and financial collateral: 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 December 31, 2014 Amounts Presented in Balance Sheet Offsetting Instruments (a) Financial Collateral (Received) Pledged (b) Net Amounts Derivative assets: Commodity contracts $ 497 $ (298 ) $ (16 ) $ 183 Derivative liabilities: Commodity contracts (317 ) 298 2 (17 ) Net amounts $ 180 $ — $ (14 ) $ 166 ____________ (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 December 31, 2015 and 2014: December 31, 2015 2014 Derivative type Notional Volume Unit of Measure Natural gas (a) 1,489 1,687 Million MMBtu Electricity 58,022 22,820 GWh Congestion Revenue Rights (b) 106,260 89,484 GWh Coal 10 10 Million US tons Fuel oil 35 36 Million gallons Uranium 75 150 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.

Pension And Other Postretirem41

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Tables)	12 Months Ended
	Dec. 31, 2015
Compensation and Retirement Disclosure [Abstract]
Schedule of Net Benefit Costs	Year Ended December 31, 2015 2014 2013 Pension costs $ 8 $ 7 $ 9 OPEB costs 3 5 3 Total benefit costs recognized as expense $ 11 $ 12 $ 12

Related-Party Transactions (Tab

Related-Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2015
Related Party Transactions [Abstract]
Schedule of related party transactions, debt held by related party	As a result of debt repurchase and exchange transactions in 2009 through 2011, EFH Corp. and EFIH held TCEH debt securities at December 31, 2014 as shown below (principal amounts). The $382 million in notes payable as of the Petition Date was classified as LSTC. The amounts of TCEH debt held by EFIH or EFH Corp. were eliminated as a result of the Settlement Agreement approved by the Bankruptcy Court in December 2015. In conjunction with the Settlement Agreement approved by the Bankruptcy Court in December 2015, EFH Corp. and EFIH waived their rights to the claims associated with these debt securities, resulting in a gain recorded in reorganization items (see Note 10). Principal Amount TCEH Senior Notes: Held by EFH Corp. $ 284 Held by EFIH 79 TCEH Term Loan Facilities: Held by EFH Corp. 19 Total $ 382

Supplementary Financial Infor43

Supplementary Financial Information (Tables)	12 Months Ended
	Dec. 31, 2015
Supplementary Financial Information [Abstract]
Schedule of Restricted Cash	Restricted Cash December 31, 2015 December 31, 2014 Current Noncurrent Assets Current Noncurrent Assets Amounts related to the DIP Facility (Note 11) $ 519 $ — $ — $ 350 Amounts related to TCEH's pre-petition Letter of Credit — 507 — 551 Other — — 2 — Total restricted cash $ 519 $ 507 $ 2 $ 901 ____________ (a) See Note 12 for discussion of letter of credit draws in 2014 and 2015.
Trade Accounts Receivable And Accounts Receivable Securitization Program [Text Block]	Trade Accounts Receivable December 31, 2015 2014 Wholesale and retail trade accounts receivable $ 542 $ 603 Allowance for uncollectible accounts (9 ) (15 ) Trade accounts receivable — net $ 533 $ 588
Schedule of trade accounts receivable and allowance for uncollectible accounts receivable	Trade Accounts Receivable December 31, 2015 2014 Wholesale and retail trade accounts receivable $ 542 $ 603 Allowance for uncollectible accounts (9 ) (15 ) Trade accounts receivable — net $ 533 $ 588 Gross trade accounts receivable at December 31, 2015 and 2014 included unbilled revenues of $231 million and $239 million , respectively. Allowance for Uncollectible Accounts Receivable Year Ended December 31, 2015 2014 2013 Allowance for uncollectible accounts receivable at beginning of period $ 15 $ 14 $ 9 Increase for bad debt expense 34 38 33 Decrease for account write-offs (40 ) (37 ) (28 ) Allowance for uncollectible accounts receivable at end of period $ 9 $ 15 $ 14
Schedule of inventories by major category	Inventories by Major Category December 31, 2015 2014 Materials and supplies $ 226 $ 214 Fuel stock 170 215 Natural gas in storage 32 39 Total inventories $ 428 $ 468
Summary of other investments	Investments December 31, 2015 2014 Nuclear plant decommissioning trust $ 918 $ 893 Assets related to employee benefit plans, including employee savings programs, net of distributions 1 1 Land 36 37 Miscellaneous other 7 10 Total investments $ 962 $ 941
Summary of investments in the fund	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 18). The nuclear decommissioning trust fund is not a debtor under the Chapter 11 Cases. A summary of investments in the fund follows: 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 December 31, 2014 Cost (a) Unrealized gain Unrealized loss Fair market value Debt securities (b) $ 288 $ 13 $ — $ 301 Equity securities (c) 276 320 (4 ) 592 Total $ 564 $ 333 $ (4 ) $ 893 ____________ (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. The debt securities are heavily weighted with municipal bonds. The debt securities had an average coupon rate of 3.68% and 4.35% at December 31, 2015 and 2014, respectively, and an average maturity of 8 years and 6 years at December 31, 2015 and 2014, respectively. (c) The investment objective for equity securities is to invest tax efficiently and to match the performance of the S&P 500 Index.
Summary of proceeds from sales of available-for-sale securities and the related realized gains and losses from such sales	The following table summarizes proceeds from sales of available-for-sale securities and the related realized gains and losses from such sales. Year Ended December 31, 2015 2014 2013 Realized gains $ 1 $ 11 $ 2 Realized losses $ (1 ) $ (2 ) $ (4 ) Proceeds from sales of securities $ 401 $ 314 $ 175 Investments in securities $ (418 ) $ (331 ) $ (191 )
Property, Plant and Equipment	Property, Plant and Equipment December 31, 2015 2014 Generation and mining (Note 8) $ 10,886 $ 14,986 Other assets 546 526 Total 11,432 15,512 Less accumulated depreciation 2,654 3,948 Net of accumulated depreciation 8,778 11,564 Construction work in progress 323 459 Nuclear fuel (net of accumulated amortization of $1.383 billion and $1.237 billion) 248 265 Property, plant and equipment — net $ 9,349 $ 12,288
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 consolidated balance sheets, for the years ended December 31, 2015 and 2014: Nuclear Plant Decommissioning Mining Land Reclamation Other Total Liability at January 1, 2014 $ 390 $ 98 $ 36 $ 524 Additions: Accretion 23 22 3 48 Incremental reclamation costs (a) — 127 — 127 Reductions: Payments — (82 ) (3 ) (85 ) Liability at December 31, 2014 $ 413 $ 165 $ 36 $ 614 Additions: Accretion 25 20 6 51 Adjustment for new cost estimate (b) 70 — — 70 Incremental reclamation costs (c) — 84 69 153 Reductions: Payments — (54 ) (4 ) (58 ) Liability at December 31, 2015 508 215 107 830 Less amounts due currently — (66 ) — (66 ) Noncurrent liability at December 31, 2015 $ 508 $ 149 $ 107 $ 764 ____________ (a) The increase in the mining reclamation liability of $127 million during 2014 was primarily due to final remediation for certain mines occurring sooner than previously estimated and increases in remediation cost estimates at other mining locations. (b) The adjustment for nuclear plant decommissioning resulted from a new cost estimate completed in the second quarter of 2015. Under applicable accounting standards, the liability is remeasured when significant changes in the amount or timing of cash flows occurs, and PUCT rules require a new cost estimate at least every five years. The increase in the liability was driven by increased security and fuel-handling costs. (c) The adjustment for other asset retirement obligations resulted from the effect on our estimated retirement obligation related to coal combustion residual facilities at our lignite/coal fueled generation facilities that arose from the CCR rule discussed above.
Schedule of other noncurrent liabilities and deferred credits	The balance of other noncurrent liabilities and deferred credits consists of the following: December 31, 2015 2014 Uncertain tax positions (including accrued interest) (Note 5) $ 41 $ 74 Asset retirement and mining reclamation obligations 764 560 Unfavorable purchase and sales contracts 543 566 Nuclear decommissioning fund excess over asset retirement obligation (Note 18) 409 479 Other, including retirement and other employee benefits 23 21 Total other noncurrent liabilities and deferred credits $ 1,780 $ 1,700
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 [Table Text Block]	Fair Value of Debt December 31, 2015 December 31, 2014 Debt: Carrying Amount Fair Value Carrying Amount Fair Value Borrowings under debtor-in-possession credit facility (Note 11) $ 1,425 $ 1,411 $ 1,425 $ 1,430 Long-term debt not subject to compromise, excluding capital lease obligations (Note 11) $ 49 $ 53 $ 76 $ 79
Schedule of supplemental cash flow information	Supplemental Cash Flow Information Year Ended December 31, 2015 2014 2013 Cash payments related to: Interest paid (a) $ 1,302 $ 1,259 $ 2,695 Capitalized interest (11 ) (17 ) (25 ) Interest paid (net of capitalized interest) (a) $ 1,291 $ 1,242 $ 2,670 Income taxes $ 29 $ 33 $ 137 Reorganization items (b) $ 224 $ 93 $ — Noncash investing and financing activities: Effect of Parent's payment of interest on pushed-down debt $ — $ — $ 23 Construction expenditures (c) $ 75 $ 108 $ 45 Contribution to membership interests (Note 18) $ — $ 2 $ 2 Reduction of debt pushed down from EFH Corp. (Note 12) (d) $ — $ — $ (420 ) Debt extension transactions (e) $ — $ — $ (340 ) Debt assumed related to acquisition of combustion turbine trust interest $ — $ — $ (45 ) ____________ (a) Net of amounts received under interest rate swap agreements. For the years ended December 31, 2015 and 2014, this amount also includes amounts paid for adequate protection. (b) Represents cash payments for legal and other consulting services. (c) Represents end-of-period accruals. (d) For the year ended December 31, 2013, represents $838 million principal amount of EFH Corp. debt exchanged (at 50% ). See Note 12. (e) Principal amounts of incremental loans under the TCEH Term Loan Facilities issued in consideration for the extension of the maturity date of such facilities.

Supplemental Guarantor Conden44

Supplemental Guarantor Condensed Financial Information (Tables)	12 Months Ended
	Dec. 31, 2015
Supplemental Guarantor Condensed Financial Information [Abstract]
Condensed Consolidating Statements of Income (Loss)	ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Consolidating Statements of Income (Loss) Year Ended December 31, 2015 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Operating revenues $ — $ — $ 5,370 $ — $ — $ 5,370 Fuel, purchased power costs and delivery fees — — (2,692 ) — — (2,692 ) Net gain from commodity hedging and trading activities — — 334 — — 334 Operating costs — — (834 ) — — (834 ) Depreciation and amortization — (8 ) (844 ) — — (852 ) Selling, general and administrative expenses — 5 (681 ) — — (676 ) Impairment of goodwill — (2,200 ) — — — (2,200 ) Impairment of long-lived assets — — (2,541 ) — — (2,541 ) Other income — — 12 5 — 17 Other deductions — (2 ) (91 ) — — (93 ) Interest income — 26 125 — (151 ) — Interest expense and related charges (6 ) (1,419 ) (19 ) — 151 (1,293 ) Reorganization items 100 (1,428 ) 1,327 — — (1 ) Income (loss) before income taxes 94 (5,026 ) (534 ) 5 — (5,461 ) Income tax benefit (expense) (20 ) 697 164 (4 ) 21 858 Equity earnings (losses) of subsidiaries (4,677 ) (348 ) 1 — 5,024 — Net income (loss) (4,603 ) (4,677 ) (369 ) 1 5,045 (4,603 ) Net income (loss) attributable to noncontrolling interests — — — — — — Net income (loss) attributable to EFCH $ (4,603 ) $ (4,677 ) $ (369 ) $ 1 $ 5,045 $ (4,603 ) Consolidating Statements of Comprehensive Income (Loss) Year Ended December 31, 2015 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Net income (loss) (4,603 ) (4,677 ) (369 ) 1 5,045 (4,603 ) Other comprehensive income 2 2 — — (2 ) 2 Comprehensive income (loss) (4,601 ) (4,675 ) (369 ) 1 5,043 (4,601 ) Comprehensive income (loss) attributable to noncontrolling interests — — — — — — Comprehensive income (loss) attributable to EFCH $ (4,601 ) $ (4,675 ) $ (369 ) $ 1 $ 5,043 $ (4,601 ) ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Consolidating Statements of Income (Loss) Year Ended December 31, 2014 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Operating revenues $ — $ — $ 5,978 $ — $ — $ 5,978 Fuel, purchased power costs and delivery fees — — (2,842 ) — — (2,842 ) Net gain (loss) from commodity hedging and trading activities — (90 ) 101 — — 11 Operating costs — — (914 ) — — (914 ) Depreciation and amortization — — (1,270 ) — — (1,270 ) Selling, general and administrative expenses — (29 ) (677 ) (2 ) — (708 ) Impairment of goodwill — (1,600 ) — — — (1,600 ) Impairment of long-lived assets — — (4,670 ) — — (4,670 ) Other income — — 14 2 — 16 Other deductions — (4 ) (277 ) — — (281 ) Interest income 1 81 285 — (367 ) — Interest expense and related charges (10 ) (2,045 ) (802 ) — 1,099 (1,758 ) Reorganization items — (500 ) (21 ) — — (521 ) Income (loss) before income taxes (9 ) (4,187 ) (5,095 ) — 732 (8,559 ) Income tax benefit (expense) 9 846 1,710 1 (236 ) 2,330 Equity earnings (losses) of subsidiaries (6,229 ) (2,888 ) 1 — 9,116 — Net income (loss) (6,229 ) (6,229 ) (3,384 ) 1 9,612 (6,229 ) Net income (loss) attributable to noncontrolling interests — — — — — — Net income (loss) attributable to EFCH $ (6,229 ) $ (6,229 ) $ (3,384 ) $ 1 $ 9,612 $ (6,229 ) Consolidating Statements of Comprehensive Income (Loss) Year Ended December 31, 2014 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Net income (loss) (6,229 ) (6,229 ) (3,384 ) 1 9,612 (6,229 ) Other comprehensive income 1 1 — — (1 ) 1 Comprehensive income (loss) (6,228 ) (6,228 ) (3,384 ) 1 9,611 (6,228 ) Comprehensive income (loss) attributable to noncontrolling interests — — — — — — Comprehensive income (loss) attributable to EFCH $ (6,228 ) $ (6,228 ) $ (3,384 ) $ 1 $ 9,611 $ (6,228 ) ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Consolidating Statements of Income (Loss) Year Ended December 31, 2013 (millions of dollars) Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Operating revenues $ — $ — $ 5,899 $ 59 $ (59 ) $ 5,899 Fuel, purchased power costs and delivery fees — — (2,848 ) — — (2,848 ) Net gain (loss) from commodity hedging and trading activities — (56 ) 2 — — (54 ) Operating costs — — (881 ) — — (881 ) Depreciation and amortization — — (1,333 ) — — (1,333 ) Selling, general and administrative expenses — (64 ) (723 ) (28 ) 59 (756 ) Impairment of goodwill — (1,000 ) — — — (1,000 ) Impairment of long-lived assets — — — (140 ) — (140 ) Other income — — 9 — — 9 Other deductions — — (22 ) — — (22 ) Interest income 1 243 795 — (1,034 ) 5 Interest expense and related charges (19 ) (2,716 ) (2,462 ) (10 ) 3,274 (1,933 ) Income (loss) before income taxes (18 ) (3,593 ) (1,564 ) (119 ) 2,240 (3,054 ) Income tax benefit (expense) 5 828 664 4 (764 ) 737 Equity earnings (losses) of subsidiaries (2,304 ) 461 (23 ) — 1,866 — Net loss (2,317 ) (2,304 ) (923 ) (115 ) 3,342 (2,317 ) Net loss attributable to noncontrolling interests 107 107 — 107 (214 ) 107 Net loss attributable to EFCH $ (2,210 ) $ (2,197 ) $ (923 ) $ (8 ) $ 3,128 $ (2,210 )
Consolidating Statements of Comprehensive Income (Loss)	Parent Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Net income (loss) (4,603 ) (4,677 ) (369 ) 1 5,045 (4,603 ) Other comprehensive income 2 2 — — (2 ) 2 Comprehensive income (loss) (4,601 ) (4,675 ) (369 ) 1 5,043 (4,601 ) Comprehensive income (loss) attributable to noncontrolling interests — — — — — — Comprehensive income (loss) attributable to EFCH $ (4,601 ) $ (4,675 ) $ (369 ) $ 1 $ 5,043 $ (4,601 )
Condensed Consolidating Statements of Cash Flows	ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Consolidating Statements of Cash Flows Year Ended December 31, 2015 (millions of dollars) Parent/ Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Cash provided by (used in) operating activities $ (8 ) $ (1,607 ) $ 1,846 $ (2 ) $ — $ 229 Cash flows – financing activities: Fees paid for DIP Facility — (9 ) — — — (9 ) Notes/advances due to affiliates 21 1,297 — 2 (1,320 ) — Repayments/repurchases of debt (13 ) — (21 ) — — (34 ) Cash provided by (used in) financing activities 8 1,288 (21 ) 2 (1,320 ) (43 ) Cash flows – investing activities: Capital expenditures — (2 ) (335 ) — — (337 ) Nuclear fuel purchases — — (123 ) — — (123 ) Settlements of notes due from affiliates — — (1,336 ) — 1,320 (16 ) Changes in restricted cash — (124 ) 1 — — (123 ) Proceeds from sales of nuclear decommissioning trust fund securities — — 401 — — 401 Investments in nuclear decommissioning trust fund securities — — (418 ) — — (418 ) Other, net — (13 ) (9 ) 9 — (13 ) Cash provided by (used in) investing activities — (139 ) (1,819 ) 9 1,320 (629 ) Net change in cash and cash equivalents — (458 ) 6 9 — (443 ) Cash and cash equivalents – beginning balance — 1,826 16 1 — 1,843 Cash and cash equivalents – ending balance $ — $ 1,368 $ 22 $ 10 $ — $ 1,400 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Consolidating Statements of Cash Flows Year Ended December 31, 2014 (millions of dollars) Parent/ Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Cash provided by (used in) operating activities $ (7 ) $ (1,498 ) $ 1,947 $ (5 ) $ — $ 437 Cash flows – financing activities: Proceeds from DIP Facility — 1,425 — — — 1,425 Fees paid for DIP Facility — (92 ) — — — (92 ) Notes/advances due to affiliates 19 1,462 — — (1,481 ) — Repayments/repurchases of long-term debt (12 ) (203 ) (20 ) — — (235 ) Contributions from noncontrolling interests — — — 1 — 1 Cash provided by (used in) financing activities 7 2,592 (20 ) 1 (1,481 ) 1,099 Cash flows – investing activities: Capital expenditures — — (336 ) — — (336 ) Nuclear fuel purchases — — (77 ) — — (77 ) Settlements of notes due from affiliates — — (1,496 ) — 1,481 (15 ) Purchase of right to use certain computer-related assets from parent — — (4 ) — — (4 ) Changes in restricted cash — 44 (2 ) — — 42 Proceeds from sales of nuclear decommissioning trust fund securities — — 314 — — 314 Investments in nuclear decommissioning trust fund securities — — (331 ) — — (331 ) Other, net — (37 ) 5 — — (32 ) Cash provided by (used in) investing activities — 7 (1,927 ) — 1,481 (439 ) Net change in cash and cash equivalents — 1,101 — (4 ) — 1,097 Cash and cash equivalents – beginning balance — 725 16 5 — 746 Cash and cash equivalents – ending balance $ — $ 1,826 $ 16 $ 1 $ — $ 1,843 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Consolidating Statements of Cash Flows Year Ended December 31, 2013 (millions of dollars) Parent/ Guarantor Issuer Other Guarantors Non- guarantors Eliminations Consolidated Cash provided by (used in) operating activities $ (1 ) $ (1,643 ) $ 1,458 $ (85 ) $ — $ (271 ) Cash flows – financing activities: Repayments/repurchases of long-term debt (11 ) (64 ) (30 ) — — (105 ) Net short-term borrowings under accounts receivable securitization program — — — (82 ) — (82 ) Contributions from parent — — — 136 (136 ) — Other, net 12 1,461 — (4 ) (1,456 ) 13 Cash provided by (used in) financing activities 1 1,397 (30 ) 50 (1,592 ) (174 ) Cash flows – investing activities: Capital expenditures — — (467 ) (5 ) — (472 ) Nuclear fuel purchases — — (116 ) — — (116 ) Notes/loans due from affiliates — — (758 ) — 1,456 698 Investment in subsidiary — (146 ) 10 — 136 — Purchase of right to use certain computer-related assets from parent — — (29 ) — — (29 ) Acquisition of combustion turbine trust interest — — (40 ) — (40 ) Changes in restricted cash — 2 — — — 2 Proceeds from sales of nuclear decommissioning trust fund securities — — 175 — — 175 Investments in nuclear decommissioning trust fund securities — — (191 ) — — (191 ) Other, net — — (11 ) — — (11 ) Cash provided by (used in) investing activities — (144 ) (1,427 ) (5 ) 1,592 16 Net change in cash and cash equivalents — (390 ) 1 (40 ) — (429 ) Cash and cash equivalents – beginning balance — 1,115 15 45 — 1,175 Cash and cash equivalents – ending balance $ — $ 725 $ 16 $ 5 $ — $ 746
Condensed Consolidating Balance Sheet	ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION 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 Advance 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 Advance to parent — 18 — — — 18 Investments (32,818 ) 9,095 983 5 23,697 962 Property, plant and equipment – net — 12 9,334 3 — 9,349 Goodwill — 152 — — — 152 Identifiable intangible assets – net — 31 1,148 — — 1,179 Accumulated deferred income taxes — 438 393 11 (842 ) — Other noncurrent assets — 1 38 — — 39 Total assets $ (32,818 ) $ 12,242 $ 13,412 $ 29 $ 22,763 $ 15,628 LIABILITIES AND EQUITY 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 Accrued taxes other than income — — 98 — — 98 Accrued interest — 119 1 — — 120 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 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 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Consolidating Balance Sheets December 31, 2014 (millions of dollars) Parent Issuer Other Non-guarantors Eliminations Consolidated ASSETS Current assets: Cash and cash equivalents $ — $ 1,826 $ 16 $ 1 $ — $ 1,843 Restricted cash — — 2 — — 2 Advances to affiliates — 8 1,179 — (1,179 ) 8 Trade accounts receivable – net — — 588 — — 588 Income taxes receivable — 176 — — (176 ) — Inventories — — 468 — — 468 Commodity and other derivative contractual assets — — 492 — — 492 Other current assets — 9 59 — — 68 Total current assets — 2,019 2,804 1 (1,355 ) 3,469 Restricted cash — 901 — — — 901 Advance to affiliates — 7 — — — 7 Investments (28,114 ) 10,845 958 8 17,244 941 Property, plant and equipment – net — 34 12,251 3 — 12,288 Goodwill — 2,352 — — — 2,352 Identifiable intangible assets – net — 14 1,322 — — 1,336 Accumulated deferred income taxes — 757 — 15 (772 ) — Other noncurrent assets, principally unamortized amendment/issuance costs — 3 36 — — 39 Total assets $ (28,114 ) $ 16,932 $ 17,371 $ 27 $ 15,117 $ 21,333 LIABILITIES AND EQUITY Current liabilities: Notes/advances from affiliates $ 8 $ 1,171 $ — $ — $ (1,179 ) $ — Long-term debt due currently 13 — 22 — — $ 35 Trade accounts payable — 7 375 — — 382 Trade accounts and other payables to affiliates 2 7 154 2 — 165 Commodity and other derivative contractual liabilities — — 316 — — 316 Margin deposits related to commodity positions — — 26 — — 26 Accumulated deferred income taxes 24 47 43 — — 114 Accrued income taxes payable to parent — — 192 — (176 ) 16 Accrued taxes other than income — — 107 — — 107 ENERGY FUTURE COMPETITIVE HOLDINGS COMPANY LLC AND SUBSIDIARIES A DEBTOR-IN-POSSESSION Consolidating Balance Sheets December 31, 2014 (millions of dollars) Parent Issuer Other Non-guarantors Eliminations Consolidated Accrued interest — 116 1 — — 117 Other current liabilities — 37 227 — — 264 Total current liabilities 47 1,385 1,463 2 (1,355 ) 1,542 Borrowings under debtor-in-possession credit facilities — 1,425 — — — 1,425 Long-term debt, less amounts due currently 34 — 51 — — 85 Liabilities subject to compromise 144 42,239 32,581 — (40,931 ) 34,033 Accumulated deferred income taxes 40 — 944 — 38 1,022 Other noncurrent liabilities and deferred credits — (3 ) 1,703 — — 1,700 Total liabilities 265 45,046 36,742 2 (42,248 ) 39,807 EFCH membership interests (28,379 ) (28,114 ) (19,371 ) 25 57,365 (18,474 ) Noncontrolling interests in subsidiaries — — — — — — Total membership interests (28,379 ) (28,114 ) (19,371 ) 25 57,365 (18,474 ) Total liabilities and membership interests $ (28,114 ) $ 16,932 $ 17,371 $ 27 $ 15,117 $ 21,333

Business And Significant Acco45

Business And Significant Accounting Policies (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Business and Significant Accounting Policies
Restricted Cash and Investments, Noncurrent	$ 507	$ 901

Chapter 11 Cases (Details)

Chapter 11 Cases (Details) $ in Millions	1 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Feb. 29, 2016	Sep. 22, 2015USD ($)
Restructuring Cost and Reserve [Line Items]
Debtor Reorganization Items, Net Gain Loss On Contract Claims And Assumption Adjustments			$ 40
Debtor Reorganization Items Legal And Advisory Professional Fees Related To Settlement, Backstop And Merger Agreement And Plan Of Reorganization	$ 144
Sponsor management agreement settlement (Notes 2 and 18)	86	$ 0	$ (19)	$ 0	$ 0
Debtor Reorganization Items, Adjustment To Intercompany Claims For Subsidiary Unsecured Claim Against Parent	700
Proposed Plan Of Reorganization, Maximum Reimbursement Of Fees And Expenses In Event Of Termination Of Merger And Purchase Agreement, Backstop Agreement Or Equity Commitment Letter							$ 35
Debtor Reorganization Items, Expenses Related To Backstop And Merger And Purchase Agreements	$ 49
Investor Group [Member]
Restructuring Cost and Reserve [Line Items]
Proposed Plan Of Reorganization, Equity And Debt Financing To Be Raised And Invested In Reorganized EFH							12,600
Proposed Plan Of Reorganization, Merger And Purchase Agreement, Equity Commitment Letter							2,513
Rights Offering Participants [Member] | Ovation Acquisition I, LLC [Member]
Restructuring Cost and Reserve [Line Items]
Proposed Plan Of Reorganization, Rights Offering, Offering Of Equity Rights In Common Stock							5,787
Rights Offering Participants [Member] | Backstop Purchasers [Member]
Restructuring Cost and Reserve [Line Items]
Rights Offering, Backstop Agreement							5,087
Senior Secured Term Loan Facility [Member] | Debt Commitment Letter [Member] | Investor Group [Member]
Restructuring Cost and Reserve [Line Items]
Proposed Plan Of Reorganization, Merger And Purchase Agreement, Debt Commitment Letter							5,500
Senior Secured Bridge Loan Facility [Member] | Debt Commitment Letter [Member] | Investor Group [Member]
Restructuring Cost and Reserve [Line Items]
Proposed Plan Of Reorganization, Merger And Purchase Agreement, Debt Commitment Letter							$ 300
Subsequent Event [Member]
Restructuring Cost and Reserve [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						5,500

Pending Purchase of La Fronte47

Pending Purchase of La Frontera Holdings, LLC (Details) - La Frontera Holdings, LLC [Member] - Texas Competitive Electric Holdings Co LLC [Member] - La Frontera Ventures, LLC [Member] $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)Megawatt-hour
Electricity Generation Facility Capacity | Megawatt-hour	2,988
Pending Purchase And Sale Agreement, Aggregate Purchase Price	$ 1,313
Pending Purchase And Sale Agreement, Cash And Net Working Capital Estimate	$ 276

Goodwill And Identifiable Int48

Goodwill And Identifiable Intangible Assets (Narrative) (Details) - USD ($)	1 Months Ended	3 Months Ended	9 Months Ended	12 Months Ended
	Sep. 30, 2014	Dec. 31, 2015	Sep. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 01, 2015	Dec. 01, 2014
Schedule of Goodwill and Indentifiable Intangible Assets [Line Items]
Goodwill, Period Increase (Decrease)		$ 800,000,000	$ 1,400,000,000
Impairment of goodwill	$ 1,600,000,000			$ 2,200,000,000	$ 1,600,000,000	$ 1,000,000,000
Reporting unit, percentage of fair value in excess of carrying amount							48.00%	17.00%
Discount rate applied to internally developed cash flow projections							6.00%	6.25%
Trade Names [Member]
Schedule of Goodwill and Indentifiable Intangible Assets [Line Items]
Impairment of Intangible Assets, Indefinite-lived (Excluding Goodwill)				0
Environmental allowances and credits [Member]
Schedule of Goodwill and Indentifiable Intangible Assets [Line Items]
Impairment of Intangible Assets (Excluding Goodwill)				$ 55,000,000	80,000,000
Competitive Electric [Member]
Schedule of Goodwill and Indentifiable Intangible Assets [Line Items]
Impairment of goodwill					$ 1,000,000,000

Goodwill And Identifiable Int49

Goodwill And Identifiable Intangible Assets (Goodwill) (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Sep. 30, 2014	Dec. 31, 2015	Dec. 31, 2014		Dec. 31, 2013
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill before impairment charges			$ 18,322
Accumulated impairment charges		$ (18,170)	(15,970)	[1]
Goodwill, Impairment Loss	$ (1,600)	(2,200)	(1,600)		$ (1,000)
Balance at December 31, 2012		$ 152	$ 2,352
[1]	Net of accumulated impairment charges totaling $18.170 billion.

Goodwill And Identifiable Int50

Goodwill And Identifiable Intangible Assets (Identifiable Intangible Assets Reported in the Balance Sheet) (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross Carrying Amount		$ 920	$ 1,292
Accumulated Amortization		701	918
Total intangible assets subject to amortization, net		219	374
Identifiable intangible assets – net		1,179	1,336
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	7
Retail customer relationship [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross Carrying Amount		463	463
Accumulated Amortization		442	425
Total intangible assets subject to amortization, net		21	38
Software and other computer-related assets [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross Carrying Amount		385	369
Accumulated Amortization		224	202
Total intangible assets subject to amortization, net		161	167
Other Identifiable Intangible Assets [Member]
Finite-Lived and Indefinite-Lived Intangible [Line Items]
Gross Carrying Amount	[1]	72	460
Accumulated Amortization	[1]	35	291
Total intangible assets subject to amortization, net	[1]	$ 37	$ 169
[1]	Includes favorable purchase and sales contracts, environmental allowances and credits and mining development costs. See discussion below regarding impairment charges recorded in 2014 and 2015 related to other identifiable intangible assets.

Goodwill And Identifiable Int51

Goodwill And Identifiable Intangible Assets (Amortization Expense Related to Intangible Assets (including income statement line item)) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Finite-Lived Intangible Assets [Line Items]
Amortization expense	[1]	$ 107	$ 170	$ 140
Depreciation and amortization [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization expense		85	116	102
Environmental allowances and credits [Member]
Finite-Lived Intangible Assets [Line Items]
Impairment of Intangible Assets (Excluding Goodwill)		$ 55	80
Other Identifiable Intangible Assets [Member] | Operating Revenues, Fuel, Purchased Power Costs And Delivery Fees, Depreciation And Amortization [Member]
Finite-Lived Intangible Assets [Line Items]
Useful life		8 years
Amortization expense		$ 30	88	69
Retail customer relationship [Member] | Depreciation and amortization [Member]
Finite-Lived Intangible Assets [Line Items]
Useful life		2 years
Amortization expense		$ 17	23	24
Software and other computer-related assets [Member] | Depreciation and amortization [Member]
Finite-Lived Intangible Assets [Line Items]
Useful life		3 years
Amortization expense		$ 60	59	47
Mining development costs [Member]
Finite-Lived Intangible Assets [Line Items]
Impairment of Intangible Assets (Excluding Goodwill)		19	0	$ 0
Favorable purchase and sales contracts [Member]
Finite-Lived Intangible Assets [Line Items]
Impairment of Intangible Assets (Excluding Goodwill)		$ 8	$ 183
[1]	Amounts recorded in depreciation and amortization totaled $85 million, $116 million and $102 million in 2015, 2014 and 2013, respectively.

Goodwill And Identifiable Int52

Goodwill And Identifiable Intangible Assets (Estimated Amortization of Intangible Assets) (Details) $ in Millions	Dec. 31, 2015USD ($)
Future Amortization Expense
2,016	$ 72
2,017	60
2,018	36
2,019	22
2,020	$ 11

Accounting For Uncertainty In53

Accounting For Uncertainty In Income Taxes (Narrative) (Details) - USD ($) $ in Millions	1 Months Ended			3 Months Ended			12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014	Oct. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Mar. 31, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Contingency [Line Items]
Income Tax Expense Recorded In Current Year Related To Previous Year		$ 85
Income Tax Expense (Benefit)							$ (858)	$ (2,330)	$ (737)
Reduction of Non Current Income Tax Expense							535
Unrecognized tax benefits, accrued interest		$ 9					4	$ 9
Unrecognized tax benefits, due to timing of recognition in tax returns							2
Unrecognized tax benefits, possible reduction in recorded tax liablity, if company sustain income tax returns previously filed							35
Unrecognized tax benefits, possible reversal of accrued interest, after-tax benefit, resulting from reduction in tax liability if company sustains positions on income tax returns previously filed							3
Increase in Tax Payable to Affiliate							18
Internal Revenue Service (IRS) [Member]
Income Tax Contingency [Line Items]
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities			$ 132
Income Tax Examination, Reclassification To Accumulated Deferred Income Tax Liability			122				1,063
Income Tax Expense (Benefit)			$ 10		$ 78		80
Unrecognized Tax Benefits, Period Increase (Decrease)						$ 878
Income Tax Examination, Estimated Reversal of Accrued Interest from Examination, Before Tax						$ 139
Income Tax Examination, Estimated Reversal of Accrued Interest from Examination, Net of Tax							90
Uncertain Tax Positions, Amount To Be Reclassified To Accumulated Deferred Tax Liability During Next 12 Months							$ 2
Internal Revenue Service (IRS) [Member] | Repair And Maintenance Costs [Member]
Income Tax Contingency [Line Items]
Income Tax Expense (Benefit)				$ 6
Uncertain Tax Liability Reclassified To Accumulated Deferred Income Tax Liability				$ 159
State and Local Jurisdiction [Member]
Income Tax Contingency [Line Items]
Income Tax Expense (Benefit)					$ 14
Tax Years 2008 and 2009 [Member] | Internal Revenue Service (IRS) [Member]
Income Tax Contingency [Line Items]
Unrecognized Tax Benefits, Decrease Resulting from Settlements with Taxing Authorities	$ 22
Income Tax Examination, Reclassification To Accumulated Deferred Income Tax Liability	2
Tax Years 2008 and 2009 [Member] | Competitive Electric [Member] | Internal Revenue Service (IRS) [Member]
Income Tax Contingency [Line Items]
Income Tax Expense (Benefit)	$ 2

Accounting For Uncertainty In54

Accounting For Uncertainty In Income Taxes (Summary of Uncertain Tax Positions, Reported in Other Noncurrent Liabilities) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Balance at January 1, excluding interest and penalties	$ 65	$ 193	$ 1,078
Additions based on tax positions related to prior years	0	55	246
Reductions based on tax positions related to prior years	(11)	(164)	(1,070)
Additions based on tax positions related to the current year	0	0	13
Settlements with taxing authorities	(18)	(19)	(74)
Balance at December 31, excluding interest and penalties	$ 36	$ 65	$ 193

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Details) - USD ($) $ in Millions	Dec. 31, 2015		Dec. 31, 2014
Operating Loss Carryforwards [Line Items]
Alternative minimum tax credit carryforwards	$ 22	[1]	$ 22
Net deferred tax asset related to accumulated other comprehensive income	18		$ 19
Internal Revenue Service (IRS) [Member]
Operating Loss Carryforwards [Line Items]
Tax Credit Carryforward, Amount	$ 1,180
[1]	Reflects adoption of ASU 2015-17, Balance Sheet Classification of Deferred Taxes. See Note 1.

Income Taxes (Components of Inc

Income Taxes (Components of Income Tax Expense (Benefit)) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Current:
US Federal	$ 68	$ 43	$ (166)
State	21	29	41
Total current	89	72	(125)
Deferred:
US Federal	(875)	(2,385)	(611)
State	(72)	(17)	(1)
Total deferred	(947)	(2,402)	(612)
Income tax benefit	$ (858)	$ (2,330)	$ (737)

Income Taxes (Reconciliation of

Income Taxes (Reconciliation of Income Taxes Computed at the US Federal Statutory Rate to Income Tax Expense) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Expense (Benefit), Continuing Operations, Income Tax Reconciliation [Abstract]
Loss before income taxes	$ (5,461)	$ (8,559)	$ (3,054)
Income taxes at the US federal statutory rate of 35%	$ (1,911)	$ (2,996)	$ (1,069)
US federal statutory rate (percent)	35.00%	35.00%	35.00%
IRS audit and appeals settlements	$ 0	$ 46	$ (80)
Nondeductible goodwill impairment	770	560	350
Texas margin tax, net of federal benefit	0	10	8
Lignite depletion allowance	(8)	(14)	(12)
Interest accrued for uncertain tax positions, net of tax	(2)	0	(17)
Nondeductible interest expense	22	21	21
Nondeductible debt restructuring costs	64	42	4
Impairment of joint venture assets attributable to noncontrolling interests (Note 8)	0	0	37
Valuation allowance	191	0	0
Other	16	1	21
Income tax benefit	$ (858)	$ (2,330)	$ (737)
Effective tax rate	15.70%	27.20%	24.10%
Accumulated Other Comprehensive Income (Loss), Income Tax Effect, Net Deferred Tax Asset	$ 18	$ 19

Income Taxes (Deferred Income T

Income Taxes (Deferred Income Tax Balances) (Details) - USD ($) $ in Millions		Dec. 31, 2015		Dec. 31, 2014
Deferred Income Tax Assets
Debt extinguishment gains		$ 1,116	[1]	$ 873
Commodity contracts and interest rate swaps		125	[1]	6
Deferred Tax Assets Unfavorable Purchase And Sales Contracts		193	[1]	202
Alternative minimum tax credit carryforwards		22	[1]	22
Alternative minimum tax credit carryforwards, Current				0
Alternative minimum tax credit carryforwards, Noncurrent				22
Net operating loss (NOL) carryforwards		413	[1]	719
Net operating loss (NOL) carryforwards, Current				0
Net operating loss (NOL) carryforwards, Noncurrent				719
Deferred Tax Assets Unfavorable Purchase And Sales Contracts		193	[1]	202
Unfavorable purchase and sales contracts		193	[1]	202
Unfavorable purchase and sales contracts, Current				0
Unfavorable purchase and sales contracts, Noncurrent				202
Deferred Tax Assets, Derivatives and Hedges		125	[1]	6
Commodity contracts and interest rate swaps, Current				0
Deferred Tax Assets, Debt Extinguishment Gains		1,116	[1]	873
Deferred Tax Assets, Debt Fair Value Discounts				(196)
Debt extinguishment gains, Current				0
Employee benefit obligations		51	[1]	54
Debt extinguishment gains, Noncurrent				873
Employee benefit obligations, Current				2
Employee benefit obligations, Noncurrent				52
Deferred Tax Assets, Accrued Interest	[1]	0
Accrued interest				88
Accrued interest, Current				0
Accrued interest, Noncurrent				88
Other		59	[1]	41
Deferred Tax Assets, Other, Current				2
Other, Noncurrent				39
Total		1,979	[1]	2,005
Total, Current				4
Total, Noncurrent				2,001
Commodity contracts and interest rate swaps, Noncurrent				6
Deferred Income Tax Liabilities
Property, plant and equipment		1,540	[1]	2,465
Property, plant and equipment, current				0
Property, plant and equipment, noncurrent				2,465
Commodity contracts and interest rate swaps		0	[1]	44
Commodity contracts and interest rate swaps, Current				44
Commodity contracts and interest rate swaps, noncurrent				0
Identifiable intangible assets				362
Identifiable intangible assets, current				0
Identifiable intangible assets, noncurrent		321	[1]	362
Debt fair value discounts				196
Debt fair value discounts, current				0
Debt fair value discounts, noncurrent		0	[1]	196
Debt extinguishment gains, noncurrent		0	[1]	0
Deferred Tax Liabilities, Debt Extinguishment Gains				74
Debt extinguishment gains, current				74
ERROR in label resolution.	[1]	140
Deferred Tax Liabilities, Other				0
Deferred Tax Liabilities, Other, Noncurrent				0
Deferred Tax Liabilities, Other, Current				0
Total		2,001	[1]	3,141
Total, current				118
Total, concurrent				3,023
Deferred Tax Assets, Valuation Allowance				0
Deferred Tax Assets, Valuation Allowance, Current				0
Deferred Tax Assets, Valuation Allowance, Noncurrent		191	[1]	0
Net Accumulated Deferred Income Tax (Asset) Liability		213	[1]	1,136
Net Deferred Income Tax Liability, current		0		114
Net Deferred Income Tax Liability, noncurrent		$ 213		$ 1,022
[1]	Reflects adoption of ASU 2015-17, Balance Sheet Classification of Deferred Taxes. See Note 1.

Other Income and Deductions (De

Other Income and Deductions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Other income:
Royalty Revenue	$ 4	$ 4	$ 5
Other Nonoperating Income, Other	13	12	4
Other income	17	16	9
Other deductions:
Other Nonoperating Expense, Other	11	18	22
Other deductions	93	281	22
Favorable purchase and sales contracts [Member]
Other deductions:
Impairment of Intangible Assets (Excluding Goodwill)	8	183	0
Environmental allowances and credits [Member]
Other deductions:
Impairment of Intangible Assets (Excluding Goodwill)	55	80	0
Mining development costs [Member]
Other deductions:
Impairment of Intangible Assets (Excluding Goodwill)	19	0	$ 0
Environmental allowances and credits [Member]
Other deductions:
Impairment of Intangible Assets (Excluding Goodwill)	$ 55	$ 80

Impairment of Long-Lived Asse60

Impairment of Long-Lived Assets (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)Nuclear_generation_units	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Schedule of Equity Method Investments [Line Items]
Impairment of long-lived assets and nuclear generation joint venture (Note 8)	$ 2,541	$ 4,670	$ 140
Write-Off Of Deferred Costs Related To Cancelled Mining Projects	$ 30
Variable Interest Entity, Primary Beneficiary, Aggregated Disclosure [Member]
Schedule of Equity Method Investments [Line Items]
Number of new nuclear generation units in development (in nuclear generation units) | Nuclear_generation_units	2
Impairment of Assets of Generation Development Joint Venture, Including Amounts Attributable to Noncontrolling Interests		140
Variable Interest Entity, Primary Beneficiary, Aggregated Disclosure [Member] | Mitsubishi Heavy Industries Ltd. [Member]
Schedule of Equity Method Investments [Line Items]
Impairment Of Assets Of Nuclear Generation Development Joint Venture, Amounts Attributable To Noncontrolling Interests	$ 107	107
Variable Interest Entity, Primary Beneficiary, Aggregated Disclosure [Member] | Texas Competitive Electric Holdings Co LLC [Member]
Schedule of Equity Method Investments [Line Items]
Impairment Of Assets Of Generation Development Joint Venture, Amounts Attributable To Parent		33
Big Brown Steam Electric Station, Martin Lake Steam Electric Station, Monticello Steam Electric Station, Sandow Steam Electric Station Unit 4 And Sandow Electric Station Unit 5 [Member]
Schedule of Equity Method Investments [Line Items]
Impairment of long-lived assets and nuclear generation joint venture (Note 8)	$ 2,541
Martin Lake Steam Electric Station, Monticello Steam Electric Station And Sandow Steam Electric Station Unit 4 [Member]
Schedule of Equity Method Investments [Line Items]
Impairment of long-lived assets and nuclear generation joint venture (Note 8)		$ 4,640

Interest Expense and Related 61

Interest Expense and Related Charges (Details) - USD ($) $ in Millions		8 Months Ended	12 Months Ended
		Dec. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Interest Expense and Related Charges [Line Items]
Contractual Interest Expense On Pre-Petition Liabilities Classified As Liabilities Subject To Compromise		$ 1,396	$ 2,077
Interest paid/accrued on debtor-in-possession financing			63	$ 37	$ 0
Adequate protection amounts paid/accrued (a)	[1]		1,233	828	0
Interest paid/accrued on pre-petition debt (b)	[2]		8	886	2,724
Interest related to pushed down debt			0	1	6
Noncash realized net loss on termination of interest rate swaps (offset in unrealized net gain) (c)	[3]		0	1,225	0
Unrealized mark-to-market net gain on interest rate swaps			0	(1,290)	(1,053)
Amortization of debt issuance, amendment and extension costs and discounts			0	86	264
Capitalized interest			(11)	(17)	(25)
Interest Expense, Other			0	2	17
Total interest expense and related charges			1,293	1,758	1,933
Interest Expense On Prepetition Liabilities Recognized In Statement of Operations, Adequate Protection Paid Or Accrued		787	1,173
Contractual Interest Expense on Prepetition Liabilities Not Recognized in Statement of Operations		609	904
Interest Rate Swap [Member]
Interest Expense and Related Charges [Line Items]
Gain (Loss) on Derivative Instruments, Net, Pretax				193	$ 621
Energy Future Competitive Holdings Company [Member]
Interest Expense and Related Charges [Line Items]
Contractual Interest Expense On Pre-Petition Liabilities Classified As Liabilities Subject To Compromise		4	7
Interest Expense On Prepetition Liabilities Recognized In Statement of Operations, Adequate Protection Paid Or Accrued		0	0
Contractual Interest Expense on Prepetition Liabilities Not Recognized in Statement of Operations		4	7
Texas Competitive Electric Holdings Co LLC [Member]
Interest Expense and Related Charges [Line Items]
Contractual Interest Expense On Pre-Petition Liabilities Classified As Liabilities Subject To Compromise		1,392	2,070
Interest Expense On Prepetition Liabilities Recognized In Statement of Operations, Adequate Protection Paid Or Accrued		787	1,173
Contractual Interest Expense on Prepetition Liabilities Not Recognized in Statement of Operations		$ 605	897
Texas Competitive Electric Holdings Co LLC [Member] | Interest Rate Swap [Member]
Interest Expense and Related Charges [Line Items]
Noncash realized net loss on termination of interest rate swaps (offset in unrealized net gain) (c)			$ (1,233)
Gain (Loss) On Derivative Instruments, Net, Pretax, Representing Matured Positions Not Settled In Cash During the Period				$ 127
[1]	Post-petition period only.
[2]	Includes amounts related to interest rate swaps totaling $193 million and $621 million for the years ended December 31, 2014 and 2013, respectively. Of the $193 million for the year ended December 31, 2014, $127 million is included in the liability arising from the termination of TCEH interest rate swaps discussed in Note 16.
[3]	See Note 16.

Interest Expense and Related 62

Interest Expense and Related Charges (Narrative) (Details) - USD ($) $ in Millions	8 Months Ended	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Sep. 30, 2014
Interest Expense and Related Charges [Line Items]
Liabilities Subject To Compromise, Debt	$ 31,192	$ 31,707	$ 31,192
Liabilities Subject To Compromise, Liability Under Terminated Agreements, Net	1,235	1,243	1,235	$ 1,243
Contractual Interest Expense On Pre-Petition Liabilities Classified As Liabilities Subject To Compromise	1,396	2,077
Interest Expense On Prepetition Liabilities Recognized In Statement of Operations, Adequate Protection Paid Or Accrued	787	1,173
Contractual Interest Expense on Prepetition Liabilities Not Recognized in Statement of Operations	$ 609	904
Adequate Protection Interest Paid-Accrued, Amount Excluded Related To Terminated Natural Gas Hedging Positions And Interest Rate Swaps		60	$ 40
Senior Secured Second Lien 11.75% Notes due March 1, 2022 [Member] | Secured Debt [Member] | Energy Future Intermediate Holding Co LLC [Member]
Interest Expense and Related Charges [Line Items]
Liabilities Subject To Compromise, Debt		$ 1,750
Adequate Protection Interest Expense [Member]
Interest Expense and Related Charges [Line Items]
Adequate Protection Paid Or Accrued, Weighted Average Interest Rate		4.69%
Adequate Protection Paid Or Accrued, Basis Spread on Variable Rate		4.50%

Reorganization Items (Schedule

Reorganization Items (Schedule of Reorganization Items) (Details) - USD ($) $ in Millions	1 Months Ended	8 Months Ended	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Reorganization Items [Abstract]
Noncash liability adjustment arising from termination of interest rate swaps		$ 277	$ 0	$ 277	$ 0
Fees paid for DIP Facility (Note 11) (reported as financing activities)		92	9	92	0
Debtor Reorganization Items, Other Expense (Income)		0	2
Expenses related to legal advisory and representation services		65	141
Expenses related to other professional consulting and advisory services		67	69
Contract claims adjustments and other		20	54	20	0
Noncash adjustment for estimated allowed claims related to debt (Note 10)		0	897	0	0
Debtor reorganization items, adjustment to affiliate claims pursuant to settlement agreement			(736)	0
Debtor Reorganization Items, Gain (Loss) On Exchange And Settlement Of Debt Instruments			(382)	0
Debtor reorganization items, gain on settlement of interest on debt held by affiliates			(20)	0
Sponsor management agreement settlement (Notes 2 and 18)	$ 86	0	(19)	0	0
Debtor Reorganization Items, Net Gain Loss On Assumption Of Contracts		0	(14)
Total reorganization items		$ 521	$ 1	$ 521	$ 0

Debtor-In-Possession Borrowin64

Debtor-In-Possession Borrowing Facility and Long-Term Debt Not Subject to Compromise (TCEH Debtor-In-Possession Facility (Details) $ in Millions		12 Months Ended
		Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Line of Credit Facility [Line Items]
Debtor-in-Possession Financing, Borrowings Outstanding		$ 0	$ 1,425
Consolidated Superpriority Secured Net Debt to Consolidated EBITDA Covenant Threshold		3.50
Long-term Debt and Capital Lease Obligations, Including Current Maturities		$ 54	120
Long-term Debt and Capital Lease Obligations, Current		(31)	(35)
Long-term Debt and Capital Lease Obligations		23	85
Energy Future Competitive Holdings Company [Member]
Line of Credit Facility [Line Items]
Long-term Debt and Capital Lease Obligations, Including Current Maturities		35	47
Debt Instrument, Unamortized premium (discount) fair value adjustments recorded under purchase accounting	[1]	(2)	(3)
Energy Future Competitive Holdings Company [Member] | Notes Payable to Banks [Member] | Fixed 9.58% Notes due in annual installments through December 4, 2019 [Member]
Line of Credit Facility [Line Items]
Long-term Debt and Capital Lease Obligations, Including Current Maturities	[2]	13	21
Energy Future Competitive Holdings Company [Member] | Notes Payable to Banks [Member] | Fixed 8.254% Notes due in quarterly installments through December 31, 2021 [Member]
Line of Credit Facility [Line Items]
Long-term Debt and Capital Lease Obligations, Including Current Maturities	[2]	24	29
Texas Competitive Electric Holdings Co LLC [Member]
Line of Credit Facility [Line Items]
Long-term Debt and Capital Lease Obligations, Including Current Maturities		19	73
Capital lease obligations		5	44
Other		2	2
Unamortized discount		(1)	(2)
Texas Competitive Electric Holdings Co LLC [Member] | Railroad Commission of Texas [Member]
Line of Credit Facility [Line Items]
Collateral Bond, Securing Mining Land Reclamation Obligations, Secured By First Lien Interest In Assets		1,100
Texas Competitive Electric Holdings Co LLC [Member] | Debtor-In-Possession Facility [Member]
Line of Credit Facility [Line Items]
Debtor-In-Possession Financing, Extension Fee		8
Debtor-in-Possession Financing, Amount Arranged		$ 3,375
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 Co LLC [Member] | Debtor-In-Possession Facility [Member] | Senior Secured Super-Priority Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Debtor-in-Possession Financing, Amount Arranged	[3]	$ 1,950
Debtor-in-Possession Financing, Borrowings Outstanding		0
Texas Competitive Electric Holdings Co LLC [Member] | Debtor-In-Possession Facility [Member] | Senior Secured Super-Priority Term Loan [Member]
Line of Credit Facility [Line Items]
Debtor-in-Possession Financing, Amount Arranged	[4]	1,425
Debtor-in-Possession Financing, Borrowings Outstanding		1,425
Debtor-In-Possession Financing, Collateral Account, Total Amount Held To Support Letters Of Credit		800
Texas Competitive Electric Holdings Co LLC [Member] | 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		281
Texas Competitive Electric Holdings Co LLC [Member] | 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		519
Texas Competitive Electric Holdings Co LLC [Member] | Debtor-In-Possession Facility [Member] | Senior Secured Super-Priority Delayed Draw Term Loan Facility [Member]
Line of Credit Facility [Line Items]
Debtor-In-Possession Financing, Amount Terminated		1,100
Texas Competitive Electric Holdings Co LLC [Member] | Fixed Secured Facility Bonds [Member] | Fixed 7.48% Secured Facility Bonds With Amortizing Payments Through January 2017 [Member]
Line of Credit Facility [Line Items]
Long-term Debt and Capital Lease Obligations, Including Current Maturities	[5]	13	25
Texas Competitive Electric Holdings Co LLC [Member] | Fixed Secured Facility Bonds [Member] | Fixed 7.46% Secured Facility Bonds with amortizing payments through January 2015 [Member]
Line of Credit Facility [Line Items]
Long-term Debt and Capital Lease Obligations, Including Current Maturities	[5]	$ 0	$ 4
[1]	Amount represents unamortized fair value adjustments recorded under purchase accounting.
[2]	Approved by the Bankruptcy Court for repayment.
[3]	Facility used for general corporate purposes. No amounts were borrowed at December 31, 2015. Pursuant to an order of the Bankruptcy Court, the TCEH Debtors may not have more than $1.650 billion of TCEH 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.
[4]	Facility used for general corporate purposes, including but not limited to, $800 million for issuing letters of credit.
[5]	Debt issued by trust and secured by assets held by the trust.

Debtor-In-Possession Borrowin65

Debtor-In-Possession Borrowing Facility and Long-Term Debt Not Subject to Compromise (Schedule of Line of Credit Facilities) (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Line of Credit Facility [Line Items]
Debtor-in-Possession Financing, Borrowings Outstanding		$ 0	$ 1,425
Debtor-In-Possession Facility [Member] | Texas Competitive Electric Holdings Co LLC [Member]
Line of Credit Facility [Line Items]
Facility Limit		3,375
Available Cash Borrowing Capacity		1,950
Available Letter of Credit Capacity		281
Debtor-In-Possession Facility [Member] | Texas Competitive Electric Holdings Co LLC [Member] | Senior Secured Super-Priority Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Facility Limit	[1]	1,950
Available Cash Borrowing Capacity	[1]	1,950
Available Letter of Credit Capacity	[1]	0
Debtor-in-Possession Financing, Borrowings Outstanding		0
Debtor-In-Possession Financing, Maximum Borrowings Allowed Without Consent Or Bankruptcy Court Order		1,650
Debtor-In-Possession Facility [Member] | Texas Competitive Electric Holdings Co LLC [Member] | Senior Secured Super-Priority Term Loan [Member]
Line of Credit Facility [Line Items]
Facility Limit	[2]	1,425
Available Cash Borrowing Capacity	[2]	0
Available Letter of Credit Capacity	[2]	281
Debtor-in-Possession Financing, Borrowings Outstanding		1,425
Debtor-In-Possession Financing, Amount Arranged, Maximum Letter of Credit Capacity		$ 800
[1]	Facility used for general corporate purposes. No amounts were borrowed at December 31, 2015. Pursuant to an order of the Bankruptcy Court, the TCEH Debtors may not have more than $1.650 billion of TCEH 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.

Liabilities Subject To Compro66

Liabilities Subject To Compromise (Liabilities Subject To Compromise) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014	Sep. 30, 2014
Debt Disclosure [Abstract]
Liabilities Subject To Compromise, Debt	$ 31,707	$ 31,192
Liabilities Subject To Compromise, Accrued Interest	648	668
Liabilities Subject To Compromise, Liability Under Terminated Agreements, Net	1,243	1,235	$ 1,243
Liabilities Subject to Compromise, Accounts Payable and Accrued Liabilities	177	179
Liabilities Subject To Compromise, Tax Sharing Agreement	0	626
Liabilities Subject To Compromise, Advances And Other Payables To Affiliates	1	133
Liabilities Subject to Compromise	$ 33,776	$ 34,033

Liabilities Subject To Compro67

Liabilities Subject To Compromise (Long-Term Debt) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 31,707	$ 31,192
Long-term debt due currently		(31)	(35)
Debt and capital lease obligations	[1]		38
Total long-term debt		23	85
Consolidated Debt [Member]
Debt Instrument [Line Items]
Debt and capital lease obligations			31,192
Deferred Debt Issuance And Extension Costs [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	[2]	0	(702)
Texas Competitive Electric Holdings Co LLC [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		31,668
Capital lease obligations		5	44
Other		2	2
Unamortized discount		(1)	(2)
Debt and capital lease obligations			31,856
Texas Competitive Electric Holdings Co LLC [Member] | Pollution control revenue bonds [Member] | Trinity River Authority of Texas [Member]
Debt Instrument [Line Items]
Unamortized fair value premium (discount)	[3]		(103)
Texas Competitive Electric Holdings Co LLC [Member] | Senior Secured Debt [Member]
Debt Instrument [Line Items]
Long-term debt, gross		1,571
Texas Competitive Electric Holdings Co LLC [Member] | 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
Long-term debt, gross			1,750
Stated interest rate (as a percent)		11.50%
Texas Competitive Electric Holdings Co LLC [Member] | 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
Long-term debt, gross			336
Stated interest rate (as a percent)		15.00%
Texas Competitive Electric Holdings Co LLC [Member] | 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
Long-term debt, gross			1,235
Stated interest rate (as a percent)		15.00%
Texas Competitive Electric Holdings Co LLC [Member] | Fixed Senior Notes [Member]
Debt Instrument [Line Items]
Long-term debt, gross		$ 4,874
Due to Related Parties, Current		(382)
Long-term debt held by affiliates (Note 17)		382	382
Texas Competitive Electric Holdings Co LLC [Member] | Fixed Senior Notes [Member] | 10.25% Fixed Senior Notes due November 1, 2015 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	[4]	$ 1,833
Long-term debt, gross	[4]		2,046
Stated interest rate (as a percent)		10.25%
Texas Competitive Electric Holdings Co LLC [Member] | Fixed Senior Notes [Member] | 10.25% Fixed Senior Notes due November 1, 2015, Series B [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	[4]	$ 1,292
Long-term debt, gross	[4]		1,442
Stated interest rate (as a percent)		10.25%
Texas Competitive Electric Holdings Co LLC [Member] | Fixed 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
Long-term debt, gross			1,749
Texas Competitive Electric Holdings Co LLC [Member] | Term loan Facilities [Member]
Debt Instrument [Line Items]
Long-term debt, gross		22,616
Texas Competitive Electric Holdings Co LLC [Member] | Term loan Facilities [Member] | TCEH Term Loan Facilities maturing October 10, 2014 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		3,809
Long-term debt due currently		(3,809)
Long-term debt, gross			3,809
Texas Competitive Electric Holdings Co LLC [Member] | Term loan Facilities [Member] | TCEH Term Loan Facilities maturing October 10, 2017 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	[4]	15,691
Long-term debt due currently		(15,691)
Long-term debt, gross	[4]		15,710
Texas Competitive Electric Holdings Co LLC [Member] | Letter of Credit [Member] | Letter of Credit Facility maturing October 2014 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		42
Long-term debt due currently		(42)
Long-term debt, gross			42
Texas Competitive Electric Holdings Co LLC [Member] | 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
Long-term debt due currently		(1,020)
Long-term debt, gross			1,020
Texas Competitive Electric Holdings Co LLC [Member] | Revolving Credit Facility [Member] | Revolving Credit Facility maturing October 2016 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		2,054
Long-term debt due currently			(2,054)
Texas Competitive Electric Holdings Co LLC [Member] | Fixed/Floating Series [Member] | 5.40% Fixed Series 1994A due May 1, 2029 [Member] | Brazos River Authority [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 39
Long-term debt, gross			39
Stated interest rate (as a percent)		5.40%
Texas Competitive Electric Holdings Co LLC [Member] | Fixed/Floating Series [Member] | 7.70% Fixed Series 1999A due April 1, 2033 [Member] | Brazos River Authority [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 111
Long-term debt, gross			111
Stated interest rate (as a percent)		7.70%
Texas Competitive Electric Holdings Co LLC [Member] | Fixed/Floating Series [Member] | 7.70% Fixed Series 1999C due March 1, 2032 [Member] | Brazos River Authority [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 50
Long-term debt, gross			50
Stated interest rate (as a percent)		7.70%
Texas Competitive Electric Holdings Co LLC [Member] | Fixed/Floating Series [Member] | 8.25% Fixed Series 2001A due October 1, 2030 [Member] | Brazos River Authority [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 71
Long-term debt, gross			71
Stated interest rate (as a percent)		8.25%
Texas Competitive Electric Holdings Co LLC [Member] | Fixed/Floating Series [Member] | 8.25% Fixed Series 2001D-1 due May 1, 2033 [Member] | Brazos River Authority [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 171
Long-term debt, gross			171
Stated interest rate (as a percent)		8.25%
Texas Competitive Electric Holdings Co LLC [Member] | Fixed/Floating Series [Member] | 6.30% Fixed Series 2003B due July 1, 2032 [Member] | Brazos River Authority [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 39
Long-term debt, gross			39
Stated interest rate (as a percent)		6.30%
Texas Competitive Electric Holdings Co LLC [Member] | Fixed/Floating Series [Member] | 6.75% Fixed Series 2003C due October 1, 2038 [Member] | Brazos River Authority [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 52
Long-term debt, gross			52
Stated interest rate (as a percent)		6.75%
Texas Competitive Electric Holdings Co LLC [Member] | Fixed/Floating Series [Member] | 5.40% Fixed Series 2003D due October 1, 2029, remarketing date October 1, 2014 [Member] | Brazos River Authority [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 31
Long-term debt, gross			31
Stated interest rate (as a percent)		5.40%
Texas Competitive Electric Holdings Co LLC [Member] | Fixed/Floating Series [Member] | 5.00% Fixed Series 2006 due March 1, 2041 [Member] | Brazos River Authority [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 100
Long-term debt, gross			100
Stated interest rate (as a percent)		5.00%
Texas Competitive Electric Holdings Co LLC [Member] | Fixed/Floating Series [Member] | 6.45% Fixed Series 2000A due June 1, 2021 [Member] | Sabine River Authority of Texas [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 51
Long-term debt, gross			51
Stated interest rate (as a percent)		6.45%
Texas Competitive Electric Holdings Co LLC [Member] | Fixed/Floating Series [Member] | 5.20% Fixed Series 2001C due May 1, 2028 [Member] | Sabine River Authority of Texas [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 70
Long-term debt, gross			70
Stated interest rate (as a percent)		5.20%
Texas Competitive Electric Holdings Co LLC [Member] | Fixed/Floating Series [Member] | 5.80% Fixed Series 2003A due July 1, 2022 [Member] | Sabine River Authority of Texas [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 12
Long-term debt, gross			12
Stated interest rate (as a percent)		5.80%
Texas Competitive Electric Holdings Co LLC [Member] | Fixed/Floating Series [Member] | 6.15% Fixed Series 2003B due August 1, 2022 [Member] | Sabine River Authority of Texas [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 45
Long-term debt, gross			45
Stated interest rate (as a percent)		6.15%
Texas Competitive Electric Holdings Co LLC [Member] | Fixed/Floating Series [Member] | 6.25% Fixed Series 200A due May 1, 2028 [Member] | Trinity River Authority of Texas [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 14
Long-term debt, gross			14
Stated interest rate (as a percent)		6.25%
Texas Competitive Electric Holdings Co LLC [Member] | Unamortized Fair Value Discount [Member] | Pollution control revenue bonds [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	[3]	$ 0
Texas Competitive Electric Holdings Co LLC [Member] | Fixed Secured Facility Bonds [Member] | Fixed 7.48% Secured Facility Bonds With Amortizing Payments Through January 2017 [Member]
Debt Instrument [Line Items]
Stated interest rate (as a percent)		7.48%
Texas Competitive Electric Holdings Co LLC [Member] | Fixed Secured Facility Bonds [Member] | Fixed 7.46% Secured Facility Bonds with amortizing payments through January 2015 [Member]
Debt Instrument [Line Items]
Stated interest rate (as a percent)		7.46%
Texas Competitive Electric Holdings Co LLC [Member] | Other Debt Obligations [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 1	1
Texas Competitive Electric Holdings Co LLC [Member] | Unamortized Discount [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		0	(91)
Parent Company [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		9
Long-term debt due currently		(15)	(13)
Unamortized fair value premium (discount)			(1)
Debt and capital lease obligations			8
Total long-term debt		20	34
Parent Company [Member] | Unamortized Fair Value Discount [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 0
Parent Company [Member] | Notes Payable to Banks [Member] | Fixed 9.58% Notes due in annual installments through December 4, 2019 [Member]
Debt Instrument [Line Items]
Stated interest rate (as a percent)		9.58%
Parent Company [Member] | Notes Payable to Banks [Member] | Fixed 8.254% Notes due in quarterly installments through December 31, 2021 [Member]
Debt Instrument [Line Items]
Stated interest rate (as a percent)		8.254%
Parent 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
Long-term debt, gross			1
Parent Company [Member] | Junior Subordinated Debt [Member] | Fixed 8.175% Junior Subordinated Debentures, Series E due January 30, 2037 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt		$ 8
Long-term debt, gross			8
Stated interest rate (as a percent)		8.175%
Energy Future Holdings Corp. [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	[1]	$ 39
Debt and capital lease obligations	[1]		30
Percentage of securities guaranteed by and push down debt		50.00%
Energy Future Holdings Corp. [Member] | Fixed Senior Notes [Member] | Fixed Senior 10.875% Notes due November 1, 2017 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	[1]	$ 16
Long-term debt, gross	[1]		16
Stated interest rate (as a percent)		10.875%
Energy Future Holdings Corp. [Member] | Fixed Senior Notes [Member] | Senior Toggle 11.25 / 12.00% Notes due November 1, 2017 [Member]
Debt Instrument [Line Items]
Liabilities Subject To Compromise, Debt	[1]	$ 14
Long-term debt, gross	[1]		$ 14
Energy Future Holdings Corp. [Member] | Fixed 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
Minimum [Member] | Texas Competitive Electric Holdings Co LLC [Member] | Fixed Senior Notes [Member] | 10.50 / 11.25% Senior Toggle Notes due November 1, 2016 [Member]
Debt Instrument [Line Items]
Stated interest rate (as a percent)		10.50%
Minimum [Member] | Energy Future Holdings Corp. [Member] | Fixed Senior Notes [Member] | Senior Toggle 11.25 / 12.00% Notes due November 1, 2017 [Member]
Debt Instrument [Line Items]
Stated interest rate (as a percent)		11.25%
Maximum [Member] | Texas Competitive Electric Holdings Co LLC [Member] | Fixed Senior Notes [Member] | 10.50 / 11.25% Senior Toggle Notes due November 1, 2016 [Member]
Debt Instrument [Line Items]
Stated interest rate (as a percent)		11.25%
Maximum [Member] | Energy Future Holdings Corp. [Member] | Fixed Senior Notes [Member] | Senior Toggle 11.25 / 12.00% Notes due November 1, 2017 [Member]
Debt Instrument [Line Items]
Stated 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.
[2]	Due to the Settlement Agreement our pre-petition notes, loans and other debt reported as liabilities subject to compromise were updated to reflect our expected allowed claim amounts, resulting in the write-off to reorganization items of unamortized deferred debt issuance and extension costs, premiums and discounts classified as LSTC (see Note 10).
[3]	Amount represents unamortized fair value adjustments recorded under purchase accounting.
[4]	As discussed below and in Note 18, principal amounts of notes/term loans totaling $382 million at December 31, 2014 were held by EFH Corp. and EFIH. The amounts of TCEH debt held by EFIH or EFH Corp. were eliminated as a result of the Settlement Agreement approved by the Bankruptcy Court in December 2015.

Liabilities Subject To Compro68

Liabilities Subject To Compromise (Debt Related Activity) (Narrative) (Details) - USD ($) $ in Millions		1 Months Ended	3 Months Ended	12 Months Ended
		Jul. 31, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Debt Instrument [Line Items]
Repayments of Debt and Capital Lease Obligations				$ 235
Repurchases of long-term debt				34	$ 235	$ 105
Repayments of principal at scheduled maturity dates				227
Repayments of contractual payments under capitalized lease obligations				8
Acquisition of combustion turbine trust interest				0	0	(40)
Restricted cash (Note 19)				507	901
Texas Competitive Electric Holdings Co LLC [Member] | Pollution control revenue bonds [Member]
Debt Instrument [Line Items]
Repurchases of long-term debt				204
Repayments of Debt					204
Energy Future Competitive Holdings Company [Member]
Debt Instrument [Line Items]
Repurchases of long-term debt				13	12	11
Acquisition of combustion turbine trust interest						$ 0
Restricted cash (Note 19)				0	0
Fixed Secured Facility Bonds [Member] | Texas Competitive Electric Holdings Co LLC [Member]
Debt Instrument [Line Items]
Repurchases of long-term debt				11
Letter of Credit [Member] | Texas Competitive Electric Holdings Co LLC [Member]
Debt Instrument [Line Items]
Letters Of Credit Drawn By Affiliated Party					7
Letter of Credit [Member] | Texas Competitive Electric Holdings Co LLC [Member] | Letter of Credit Facility maturing October 10, 2017 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross					1,020
Restricted cash (Note 19)				507
Letters Of Credit Issued To Affiliated Party			$ 157
Letters Of Credit Drawn By Affiliated Party					150
Letters of Credit Issued To Affiliated Party Remaining At Expiration Date		$ 7
Letters of Credit Drawn By Nonaffiliated Counterparties				45	245
Letters of Credit Drawn By Executive Officers To Satisfy Payments Related To Long-Term Incentive Awards				20
Senior Secured Debt [Member] | Texas Competitive Electric Holdings Co LLC [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross				1,571
Senior Notes [Member] | Texas Competitive Electric Holdings Co LLC [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross				$ 4,874
Senior Notes [Member] | Energy Future Holdings Corp. [Member] | Senior Toggle 11.25 / 12.00% Notes due November 1, 2017 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[1]				14
Senior Notes [Member] | Energy Future Holdings Corp. [Member] | Fixed Senior 10.875% Notes due November 1, 2017 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[1]				$ 16
[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 Compro69

Liabilities Subject To Compromise (Guarantees and Push Down of EFH Corp. Debt) (Narrative) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Debt and Capital Lease Obligations	[1]		$ 38
Payment of Interest on Pushed-down Debt Accounted for as a Contribution of Capital (net of tax)			23
Energy Future Competitive Holdings Company [Member]
Debt Instrument [Line Items]
Debt and Capital Lease Obligations			$ 8
Senior Notes And Demand Notes Payable [Member] | Financial guarantee [Member] | Energy Future Competitive Holdings Company [Member]
Debt Instrument [Line Items]
Debt Instrument, Principal Amount Guarantee Obligations Of Subsidiaries Before Principal Amounts Cancelled		$ 60
Senior Notes [Member] | Financial guarantee [Member] | EFH Corp. 10.875% Senior Notes [Member] | Energy Future Competitive Holdings Company [Member] | Not Merger-Related [Member]
Debt Instrument [Line Items]
Debt Instrument, Principal Amount Guarantee Obligations Of Subsidiaries Before Principal Amounts Cancelled		33
Senior Notes [Member] | Financial guarantee [Member] | Senior Toggle 11.25 / 12.00% Notes due November 1, 2017 [Member] | Energy Future Competitive Holdings Company [Member] | Not Merger-Related [Member]
Debt Instrument [Line Items]
Debt Instrument, Principal Amount Guarantee Obligations Of Subsidiaries Before Principal Amounts Cancelled		27
Push Down Debt [Member]
Debt Instrument [Line Items]
Debt and Capital Lease Obligations		$ 30
Push Down Debt [Member] | Energy Future Holdings Corp. [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%
[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.

(Information Regarding Other Si

(Information Regarding Other Significant Outstanding Debt) (Narrative) (Details) - USD ($) $ in Millions		1 Months Ended	12 Months Ended
		Apr. 30, 2014	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Notes, loans and other debt			$ 31	$ 35
Liabilities Subject To Compromise, Debt			31,707	31,192
Texas Competitive Electric Holdings Co LLC [Member]
Debt Instrument [Line Items]
Interest Payment Amount, Election To Use Permitted Grace Period		$ 123
Liabilities Subject To Compromise, Debt			31,668
Texas Competitive Electric Holdings Co LLC [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Long-term debt, gross			22,616
Texas Competitive Electric Holdings Co LLC [Member] | Line of Credit [Member] | TCEH Term Loan Facilities maturing October 10, 2014 [Member]
Debt Instrument [Line Items]
Long-term debt, gross				3,809
Notes, loans and other debt			$ 3,809
Debt Instrument, Basis Spread on Variable Rate			3.50%
Liabilities Subject To Compromise, Debt			$ 3,809
Texas Competitive Electric Holdings Co LLC [Member] | Line of Credit [Member] | Term Loan Facilities maturing October 10, 2017 [Member]
Debt Instrument [Line Items]
Long-term debt, gross	[1]			15,710
Notes, loans and other debt			$ 15,691
Debt Instrument, Basis Spread on Variable Rate			4.50%
Liabilities Subject To Compromise, Debt	[1]		$ 15,691
Texas Competitive Electric Holdings Co LLC [Member] | Letter of Credit [Member] | Letter of Credit Facility maturing October 10, 2014 [Member]
Debt Instrument [Line Items]
Long-term debt, gross				42
Notes, loans and other debt			$ 42
Debt Instrument, Basis Spread on Variable Rate			3.50%
Liabilities Subject To Compromise, Debt			$ 42
Texas Competitive Electric Holdings Co LLC [Member] | Letter of Credit [Member] | Letter of Credit Facility maturing October 10, 2017 [Member]
Debt Instrument [Line Items]
Long-term debt, gross				1,020
Notes, loans and other debt			$ 1,020
Debt Instrument, Basis Spread on Variable Rate			4.50%
Liabilities Subject To Compromise, Debt			$ 1,020
Texas Competitive Electric Holdings Co LLC [Member] | Revolving Credit Facility [Member] | Revolving Credit Facility maturing October 2016 [Member]
Debt Instrument [Line Items]
Notes, loans and other debt				2,054
Line of Credit Facility, Amount Outstanding			2,054
Liabilities Subject To Compromise, Debt			2,054
Texas Competitive Electric Holdings Co LLC [Member] | Senior Secured Debt [Member]
Debt Instrument [Line Items]
Long-term debt, gross			1,571
Texas Competitive Electric Holdings Co LLC [Member] | Senior Secured Debt [Member] | 11.5% Fixed Senior Secured Notes due October 1, 2020 [Member]
Debt Instrument [Line Items]
Long-term debt, gross				$ 1,750
Liabilities Subject To Compromise, Debt			1,750
Texas Competitive Electric Holdings Co LLC [Member] | Senior Notes [Member]
Debt Instrument [Line Items]
Long-term debt, gross			$ 4,874
[1]	As discussed below and in Note 18, principal amounts of notes/term loans totaling $382 million at December 31, 2014 were held by EFH Corp. and EFIH. The amounts of TCEH debt held by EFIH or EFH Corp. were eliminated as a result of the Settlement Agreement approved by the Bankruptcy Court in December 2015.

Commitments And Contingencies71

Commitments And Contingencies (Narrative) (Details) - USD ($)	1 Months Ended		12 Months Ended
	Aug. 31, 2015	Feb. 29, 2012	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Commitments and Contingencies [Line Items]
Operating leases, rent expense			$ 55,000,000	$ 54,000,000	$ 57,000,000
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%
Financial Standby Letter of Credit [Member] | Texas Competitive Electric Holdings Co LLC [Member]
Commitments and Contingencies [Line Items]
Letters of Credit			519,000,000
Financial Standby Letter of Credit [Member] | Texas Competitive Electric Holdings Co LLC [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			230,000,000
Financial Standby Letter of Credit [Member] | Texas Competitive Electric Holdings Co LLC [Member] | Support Executory Contracts And Insurance Agreements [Member]
Commitments and Contingencies [Line Items]
Letters of Credit			72,000,000
Financial Standby Letter of Credit [Member] | Texas Competitive Electric Holdings Co LLC [Member] | Support Retail Electric Provider's financial requirements with the PUCT [Member]
Commitments and Contingencies [Line Items]
Letters of Credit			55,000,000
Financial Standby Letter of Credit [Member] | Texas Competitive Electric Holdings Co LLC [Member] | Miscellaneous credit support requirements [Member]
Commitments and Contingencies [Line Items]
Letters of Credit			162,000,000
Cross-State Air Pollution Rule [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%
Coal purchase and transportation agreements [Member]
Commitments and Contingencies [Line Items]
Expenditures			218,000,000	$ 348,000,000	$ 353,000,000
Maximum [Member] | Pending Litigation [Member] | EPA Versus Luminant and Big Brown Power Company (Big Brown and Martin Lake Generation Facilities) [Member]
Commitments and Contingencies [Line Items]
Loss Contingency Damages Sought Value Per Day			37,500
Minimum [Member] | Pending Litigation [Member] | EPA Versus Luminant and Big Brown Power Company (Big Brown and Martin Lake Generation Facilities) [Member]
Commitments and Contingencies [Line Items]
Loss Contingency Damages Sought Value Per Day			$ 32,500

Commitments And Contingencies72

Commitments And Contingencies (Nuclear Insurance) (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Accidental Outage Insurance through NEIL [Member]
Commitments and Contingencies [Line Items]
Replacement electricity costs coverage weekly payments maximum coverage per unit	$ 490
Replacement electricity costs coverage weekly payments percentage reduction if both units are out of service at same time as result of same accident	80.00%
Price-Anderson Act [Member]
Commitments and Contingencies [Line Items]
Nuclear insurance, Annual Coverage limit	$ 13,600
Price-Anderson Act [Member] | Liability Insurance from American Nuclear Insurers [Member]
Commitments and Contingencies [Line Items]
Nuclear insurance, Required per site	375
Price-Anderson Act [Member] | Secondary Financial Protection [Member]
Commitments and Contingencies [Line Items]
Nuclear insurance, Financial protection pool maximum assessment	$ 127.3
Nuclear insurance, Financial protection pool, inflation period adjustment on nuclear incident assessment	5 years
Nuclear insurance, Financial protection pool maximum annual assessment payment	$ 19
Mutual insurance, Total retrospective premium obligation	254.6
Mutual insurance, Total retrospective premium obligation maximum potential assessment under retrospective plan, excluding taxes per incident per year	$ 37.9
Mutual insurance, Total retrospective premium obligation maximum potential assessment under retrospective plan, excluding taxes per incident period	1 year
NCR [Member]
Commitments and Contingencies [Line Items]
Nuclear insurance, Amount of insurance required to maintain	$ 1,060
Mutual insurance, Nuclear decontamination and property damage insurance	2,250
Mutual insurance, Total nuclear decontamination and property damage insurance, deductible per accident	5
First fifty-two weeks after twelve-week waiting period [Member] | Accidental Outage Insurance through NEIL [Member]
Commitments and Contingencies [Line Items]
Replacement electricity costs coverage weekly payments	3.5
After first fifty-two weeks for next 110 weeks after twelve-week waiting period [Member] | Accidental Outage Insurance through NEIL [Member]
Commitments and Contingencies [Line Items]
Replacement electricity costs coverage weekly payments	$ 2.8

Commitments And Contingencies73

Commitments And Contingencies (Noncancellable Commitments Under Energy-related Contracts, Leases and Other Agreements) (Details) $ in Millions	Dec. 31, 2015USD ($)
Coal purchase and transportation agreements [Member]
Contractual Obligation, Fiscal Year Maturity [Abstract]
2,015	$ 307
2,016	0
2,017	0
2,018	0
2,019	0
Thereafter	0
Total	307
Pipeline transportation and storage reservation fees [Member]
Contractual Obligation, Fiscal Year Maturity [Abstract]
2,015	13
2,016	1
2,017	1
2,018	1
2,019	1
Thereafter	7
Total	24
Nuclear fuel contracts [Member]
Contractual Obligation, Fiscal Year Maturity [Abstract]
2,015	62
2,016	46
2,017	72
2,018	35
2,019	37
Thereafter	96
Total	348
Other contracts [Member]
Contractual Obligation, Fiscal Year Maturity [Abstract]
2,015	130
2,016	42
2,017	14
2,018	12
2,019	14
Thereafter	36
Total	$ 248

Commitments And Contingencies74

Commitments And Contingencies (Future Minimum Lease Payments Under Both Capital Leases and Operating Leases) (Details) $ in Millions	Dec. 31, 2015USD ($)
Capital Leases
2,015	$ 3
2,016	2
2,016	0
2,017	0
2,018	0
Thereafter	0
Total future minimum lease payments	5
Less amounts representing interest	0
Present value of future minimum lease payments	5
Less current portion	3
Long-term capital lease obligation	2
Operating Leases
2,015	24	[1]
2,016	29	[1]
2,017	27	[1]
2,018	26	[1]
2,019	25	[1]
Thereafter	139	[1]
Total future minimum lease payments	$ 270	[1]
[1]	Includes operating leases with initial or remaining noncancellable lease terms in excess of one year.

Equity (Narrative) (Details)

Equity (Narrative) (Details) - Variable Interest Entity, Primary Beneficiary, Aggregated Disclosure [Member] $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)Nuclear_generation_units	Dec. 31, 2014USD ($)
Stockholders' Equity [Line Items]
Number of new nuclear generation units in development (in nuclear generation units) | Nuclear_generation_units	2
Mitsubishi Heavy Industries Ltd. [Member]
Stockholders' Equity [Line Items]
Impairment Of Assets Of Nuclear Generation Development Joint Venture, Amounts Attributable To Noncontrolling Interests | $	$ 107	$ 107

Fair Value Measurements (Schedu

Fair Value Measurements (Schedule of Assets and Liabilities Measured at Fair Value on a Recurring Basis) (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Assets:
Nuclear decommissioning trust		$ 918	$ 893
Equity securities [Member]
Assets:
Nuclear decommissioning trust	[1]	599	592
Debt securities [Member]
Assets:
Nuclear decommissioning trust	[2]	319	301
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Assets:
Total assets		765	777
Liabilities:
Total liabilities		128	278
Fair Value, Measurements, Recurring [Member] | Level 1 [Member] | Equity securities [Member]
Assets:
Nuclear decommissioning trust	[3]	380	375
Fair Value, Measurements, Recurring [Member] | Level 1 [Member] | Commodity Contract [Member]
Assets:
Derivative Assets		385	402
Liabilities:
Derivative Liabilities		128	278
Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Assets:
Total assets		579	564
Liabilities:
Total liabilities		64	25
Fair Value, Measurements, Recurring [Member] | Level 2 [Member] | Equity securities [Member]
Assets:
Nuclear decommissioning trust	[3]	219	217
Fair Value, Measurements, Recurring [Member] | Level 2 [Member] | Debt securities [Member]
Assets:
Nuclear decommissioning trust	[3]	319	301
Fair Value, Measurements, Recurring [Member] | Level 2 [Member] | Commodity Contract [Member]
Assets:
Derivative Assets		41	46
Liabilities:
Derivative Liabilities		64	25
Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Assets:
Total assets	[4]	49	49
Liabilities:
Total liabilities	[4]	12	14
Fair Value, Measurements, Recurring [Member] | Level 3 [Member] | Commodity Contract [Member]
Assets:
Derivative Assets	[4]	49	49
Liabilities:
Derivative Liabilities	[4]	12	14
Total [Member] | Fair Value, Measurements, Recurring [Member]
Assets:
Total assets		1,393	1,390
Liabilities:
Total liabilities		204	317
Total [Member] | Fair Value, Measurements, Recurring [Member] | Equity securities [Member]
Assets:
Nuclear decommissioning trust	[3]	599	592
Total [Member] | Fair Value, Measurements, Recurring [Member] | Debt securities [Member]
Assets:
Nuclear decommissioning trust	[3]	319	301
Total [Member] | Fair Value, Measurements, Recurring [Member] | Commodity Contract [Member]
Assets:
Derivative Assets		475	497
Liabilities:
Derivative Liabilities		$ 204	$ 317
[1]	The investment objective for equity securities is to invest tax efficiently and to match the performance of the S&P 500 Index.
[2]	The investment objective for debt securities is to invest in a diversified tax efficient portfolio with an overall portfolio rating of AA or above as graded by S&P or Aa2 by Moody's. The debt securities are heavily weighted with municipal bonds. The debt securities had an average coupon rate of 3.68% and 4.35% at December 31, 2015 and 2014, respectively, and an average maturity of 8 years and 6 years at December 31, 2015 and 2014, respectively.
[3]	The nuclear decommissioning trust investment is included in the investments line in the consolidated balance sheets. See Note 19.
[4]	See table below for description of Level 3 assets and liabilities.

Fair Value Measurements (Sche77

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		12 Months Ended
		Dec. 31, 2015USD ($)$ / T$ / Megawatt-hour		Dec. 31, 2014USD ($)$ / T$ / Megawatt-hour
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets		$ 49		$ 49
Liabilities		(12)		(14)
Derivative Assets (Liabilities), at Fair Value, Net		37		35
Electricity purchases and sales [Member] | Valuation Model [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets	[1]	1		4
Liabilities	[1]	(1)		(5)
Derivative Assets (Liabilities), at Fair Value, Net	[1]	0		(1)
Electricity congestion revenue rights [Member] | Market Approach [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets	[1],[2]	39		38
Liabilities	[1],[2]	(4)		(4)
Derivative Assets (Liabilities), at Fair Value, Net	[1],[2]	35		34
Coal purchases [Member] | Market Approach [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets	[1],[2]			0
Liabilities	[1],[2]			(4)
Derivative Assets (Liabilities), at Fair Value, Net	[1],[2]			(4)
Other [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Assets		9	[1]	7
Liabilities		(7)	[1]	(1)
Derivative Assets (Liabilities), at Fair Value, Net		$ 2	[1]	$ 6
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],[3],[4]	15		30
Hourly price curve shape (in usd per MWh) | $ / Megawatt-hour	[1],[4],[5]	15		20
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],[4],[6]	0		0
Minimum [Member] | Coal purchases [Member] | Market Approach [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair Value Inputs, Illiquid Pricing Variances Between Heat Content | $ / T				0
Illiquid price variances between mines | $ / T	[4],[7]	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],[3],[4]	35		50
Hourly price curve shape (in usd per MWh) | $ / Megawatt-hour	[1],[4],[5]	45		70
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],[4],[6]	10		20
Maximum [Member] | Coal purchases [Member] | Market Approach [Member]
Fair Value Inputs, Assets and Liabilities, Quantitative Information [Line Items]
Fair Value Inputs, Illiquid Pricing Variances Between Heat Content | $ / T				1
Illiquid price variances between mines | $ / T	[4],[7]	0		1
[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 congestion revenue rights contracts consist of forward purchase contracts (swaps and options) used to hedge electricity price differences between settlement points within ERCOT. Coal purchase contracts relate to western (Powder River Basin) coal.
[2]	Based on the historical range of price variances between mine locations.
[3]	Based on the historical range of forward average monthly ERCOT hub and load zone prices.
[4]	The range of the inputs may be influenced by factors such as time of day, delivery period, season and location.
[5]	Based on the historical range of forward average hourly ERCOT North Hub prices.
[6]	Based on historical ranges of forward average prices between different heat contents (potential energy in coal for a given mass).
[7]	Other includes contracts for ancillary services, natural gas, power options, diesel options and coal options.

Fair Value Measurements (Sche78

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 Contract [Member] - Derivative financial instruments, assets and liabilities [Member] - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance at beginning of period		$ 35	$ (973)	$ 29
Total unrealized valuation gains (losses)		27	(97)	(48)
Purchases, issuances and settlements:
Purchases	[1]	49	63	92
Issuances	[1]	(13)	(5)	(7)
Settlements	[1]	(48)	1,053	138
Transfers into Level 3	[2]	1	0	(1,181)
Transfers out of Level 3	[2]	(14)	(6)	4
Net change	[3]	2	1,008	(1,002)
Balance at end of period		37	35	(973)
Unrealized valuation gains (losses) relating to instruments held at end of period		$ 18	$ (5)	$ 435
[1]	Settlements reflect reversals of unrealized mark-to-market valuations previously recognized in net income. Purchases and issuances reflect option premiums paid or received. Settlement amounts in 2014 reflect termination of the TCEH interest rate swaps and include the reversal of a nonperformance risk adjustment as discussed in Note 16.
[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 years presented are in and out of Level 2. Transfers into Level 3 during 2013 reflect a nonperformance risk adjustment in the valuation of the TCEH interest rate swaps, which were secured by a first-lien interest in the same assets of TCEH (on a pari passu basis) with the TCEH Senior Secured Facilities and the TCEH Senior Secured Notes (see Note 12).
[3]	Substantially all changes in values of commodity contracts are reported in the statements of consolidated income (loss) in net gain (loss) from commodity hedging and trading activities. Changes in values of interest rate swaps transferred into Level 3 in 2013 are reported in the statements of consolidated income (loss) in interest expense and related charges (see Note 9). 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 Derivativ79

Commodity And Other Derivative Contractual Assets And Liabilities (Strategic Use of Derivatives) (Narrative) (Details) - USD ($) $ in Millions		8 Months Ended	12 Months Ended
		Dec. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Sep. 30, 2014	May. 02, 2014
Derivative [Line Items]
Net Liability, Interest Rate and Commodity Contract Positions Terminated							$ 1,116
Realized Gain (Loss) On Terminated Interest Rate Derivatives	[1]		$ 0	$ (1,225)	$ 0
Realized Gain (Loss) On Terminated Commodity Related Derivatives			0	117	0
Net Liability, Accounts Payable Related To Matured Interest Rate Swaps Secured By First-Lien Secured Interest			127
Liabilities Subject To Compromise, Liability Under Terminated Agreements, Net		$ 1,235	1,243	1,235		$ 1,243
Noncash liability adjustment arising from termination of interest rate swaps		$ 277	0	$ 277	$ 0
Texas Competitive Electric Holdings Co LLC [Member] | Commodity Contract [Member]
Derivative [Line Items]
Realized Gain (Loss) On Terminated Commodity Related Derivatives			117
Texas Competitive Electric Holdings Co LLC [Member] | Interest Rate Swap [Member]
Derivative [Line Items]
Realized Gain (Loss) On Terminated Interest Rate Derivatives			$ 1,233
[1]	See Note 16.

Commodity And Other Derivativ80

Commodity And Other Derivative Contractual Assets And Liabilities (Financial Statement Effects of Derivatives) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Derivatives, Fair Value [Line Items]
Derivative, Fair Value, Net	$ 271	$ 180
Commodity Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative asset, Fair Value, Gross Asset	475	497
Derivative Liability, Fair Value, Gross Liability	204	317
Derivative asset, Fair Value, Net	475	(497)
Derivative liabilities, Fair Value, Net	204	(317)
Derivative, Fair Value, Net	271	180
Commodity Contract [Member] | Current Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative asset, Fair Value, Gross Asset	465	492
Derivative liabilities, Fair Value, Gross Asset	0	0
Derivative Assets And Liability, Fair Value, Gross Assets	465	492
Commodity Contract [Member] | Noncurrent Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative asset, Fair Value, Gross Asset	10	5
Derivative liabilities, Fair Value, Gross Asset	0	0
Derivative Assets And Liability, Fair Value, Gross Assets	10	5
Commodity Contract [Member] | Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative asset, Fair Value, Gross Liability	0	0
Derivative Liability, Fair Value, Gross Liability	203	(316)
Derivative Assets And Liability, Fair Value, Gross Liability	(203)	(316)
Commodity Contract [Member] | Noncurrent liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative asset, Fair Value, Gross Liability	0	0
Derivative Liability, Fair Value, Gross Liability	1	(1)
Derivative Assets And Liability, Fair Value, Gross Liability	$ (1)	$ (1)

Commodity And Other Derivativ81

Commodity And Other Derivative Contractual Assets And Liabilities (Derivative (Income Statement Presentation) and Derivative type (Income Statement Presentation of Loss Reclassified from Accumulated OCI into Income)) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss)		$ 380	$ (388)	$ 379
Interest Rate Swap [Member]
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)	(35)
Interest Rate Cash Flow Hedge Gain (Loss) to be Reclassified During Next 12 Months, Net		(2)
Net gain (loss) from commodity hedging and trading activities [Member] | Commodity Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss)	[1]	380	17	(54)
Interest expense and related charges [Member] | Interest Rate Swap [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss)	[2]	0	(128)	433
Reorganization Items [Member] | Interest Rate Swap [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Net gain (loss)		$ 0	$ (277)	$ 0
[1]	Amount represents changes in fair value of positions in the derivative portfolio during the period, as realized amounts related to positions settled are assumed to equal reversals of previously recorded unrealized amounts.
[2]	Includes unrealized mark-to-market net gain (loss) as well as the net realized effect on interest paid/accrued, both reported in Interest Expense and Related Charges (see Note 9).

Commodity And Other Derivativ82

Commodity And Other Derivative Contractual Assets And Liabilities (Reconciliation of Derivative Assets and Liabilities as Presented in the Consolidated Balance Sheet to Net Amounts) (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Derivative [Line Items]
Derivative, Fair Value, Net		$ 271	$ 180
Derivative Asset (Liabilit), Collateral, Obligation to Return Cash	[1]	0	0
Derivative Assets (Liability), Fair Value of Collateral, Net	[2]	(141)	(14)
Derivative Assets (Liability), Fair Value, Amount Offset Against Collateral		130	166
Commodity Contract [Member]
Derivative [Line Items]
Derivative asset, Fair Value, Gross Asset		475	497
Derivative Asset, Collateral, Obligation to Return Cash, Offset	[1]	(145)	(298)
Derivative Asset, Fair Value of Collateral	[2]	(147)	(16)
Derivative Asset, Fair Value, Amount Offset Against Collateral		183	183
Derivative Liability, Fair Value, Gross Liability		(204)	(317)
Derivative Liability, Collateral, Right to Reclaim Cash, Offset	[1]	145	298
Derivative Liability, Fair Value of Collateral	[2]	6	2
Derivative Liability, Fair Value, Amount Offset Against Collateral		(53)	(17)
Derivative, Fair Value, Net		$ 271	$ 180
[1]	Amounts presented exclude trade accounts receivable and payable related to settled financial instruments.
[2]	Financial collateral consists entirely of cash margin deposits.

Commodity And Other Derivativ83

Commodity And Other Derivative Contractual Assets And Liabilities (Derivative Volumes) (Details) lb in Thousands, gal in Millions, T in Millions, MMBTU in Millions		Dec. 31, 2015TMMBTUGWhgallb	Dec. 31, 2014TMMBTUGWhgallb
Natural Gas Derivative [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | MMBTU	[1]	1,489	1,687
Electricity (in GWh) [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume		58,022	22,820
Congestion Revenue RIghts (in GWh) [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume	[2]	106,260	89,484
Coal (in tons) [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | T		10	10
Fuel oil (in gallons) [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | gal		35	36
Uranium (in pounds) [Member]
Derivatives, Fair Value [Line Items]
Nonmonetary Notional Volume | lb		75	150
[1]	Represents gross notional forward sales, purchases and options transactions, locational basis swaps and other natural gas transactions.
[2]	Represents gross forward purchases associated with instruments used to hedge electricity price differences between settlement points within ERCOT.

Commodity And Other Derivativ84

Commodity And Other Derivative Contractual Assets And Liabilities (Credit Risk-Related Contingent Features of Derivatives) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Credit Derivatives [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 59	$ 18
Credit risk derivative with contingent feature [Member]
Credit Derivatives [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	58	17
Liquidity exposure associated with liabilities reduced by cash and letter of credit postings with the counterparties	$ 31	$ 5

Commodity And Other Derivativ85

Commodity And Other Derivative Contractual Assets And Liabilities (Concentrations of Credit Risk Related to Derivatives) (Details) - Texas Competitive Electric Holdings Co LLC [Member] - Credit Risk Contract [Member] $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Derivative [Line Items]
Total credit risk exposure to all counterparties related to derivative contracts	$ 527
Net exposure to those counterparties after taking into effect master netting arrangements, setoff provisions and collateral	$ 199
Credit risk exposure to banking and financial sector percentage	78.00%
Net exposure to banking and financial sector percentage	56.00%
Largest net Exposure to single counterparty	$ 110

Pension And Other Postretirem86

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Narrative) (Details) - USD ($) $ in Millions	1 Months Ended		3 Months Ended	12 Months Ended
	Dec. 31, 2015	Feb. 28, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Market-related value of the assets held in trust, realized and unrealized gains or losses included in rolling period				4 years
Market-related value of the assets held in trust, realized and unrealized gains or losses included in rolling period, vesting percentage				25.00%
Market-related value of the assets held in trust, realized and unrealized gains or losses included in preceding periods related to vesting percentage				3 years
Defined Benefit Plan, Portion Of Contributions Provided To Parent, (As A Percent)				24.00%	24.00%
Thift Plan
Employer matching contribution percent of match				75.00%
Employer matching contribution, percent				6.00%
Minimum annual contributions per employee percent				1.00%
Maximum annual contribution per employee, percent				20.00%
Employer discretionary contribution amount				$ 21
Cash Balance Formula of the Retirement Plan [Member]
Thift Plan
Employer matching contribution percent of match				100.00%
Traditional Retirement Plan Formula Of Retirement Plan [Member]
Thift Plan
Employer matching contribution percent of match				75.00%
Multiemployer plans, pension [Member]
Defined Benefit Plan Disclosure [Line Items]
Multiemployer Plans, Collective-Bargaining Arrangement, Percentage of Employer's Contributions					37.00%
Multiemployer Plans, Funded Status, Percentage				80.00%
Pension Plan, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year				$ 3
Assumptions used calculating net periodic benefit cost, discount rate				4.19%	5.07%
Assumptions used calculating net periodic benefit cost, expected long-term return on assets				5.38%
Defined Benefit Plan Contributions By Employer Excluding Affiliated Supplemental Plan	$ 67	$ 84
Pension Plan, Defined Benefit [Member] | Texas Competitive Electric Holdings Co LLC [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions by employer	16		$ 20
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions by employer				$ 8
Defined Benefit Plans, Estimated Future Employer Contributions in Next Fiscal Year				$ 8
Assumptions used calculating net periodic benefit cost, discount rate				3.81%	4.98%	4.10%
Oncor [Member] | Pension Plan, Defined Benefit [Member] | Majority-Owned Subsidiary, Unconsolidated [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions by employer	$ 51	$ 64

Pension And Other Postretirem87

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Pension and OPEB Costs Recognized as Expense) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Net periodic benefit cost		$ 11	$ 12	$ 12
Pension Plan, Defined Benefit [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Net periodic benefit cost	[1]	8	7	9
OPEB [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Net periodic benefit cost		$ 3	$ 5	$ 3
[1]	{F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOjRjOWFmOGZjZDM3MDRhMzdhZTQzMWI3Y2RlODcwOTFifFRleHRTZWxlY3Rpb246OTU4MTczMDNCRTY3OEQ3OEI1RDhCMkJBNzJDOUZBRUMM}

Related-Party Transactions (Nar

Related-Party Transactions (Narrative) (Details) $ in Millions	1 Months Ended			3 Months Ended			8 Months Ended	12 Months Ended
	Dec. 31, 2015USD ($)Rating-Agencies-Downgrades	Apr. 30, 2014USD ($)	Feb. 28, 2014USD ($)	Mar. 31, 2016USD ($)	Mar. 31, 2014USD ($)	Mar. 31, 2012USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2015USD ($)Rating-Agencies-Downgrades	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Jan. 31, 2013USD ($)
Related Party Transaction [Line Items]
Restricted cash	$ 519						$ 2	$ 519	$ 2
Debt Instrument, Description of Variable Rate Basis								LIBOR
Taxes Payable	626							$ 626
affiliate tax sharing liability, reduction due to settlement								604
Due from Affiliates	24						15	24	15
Due from Affiliate, Current	6						8	6	8
Advance to parent (Note 18)	18						7	18	7
Contractual Interest Expense On Pre-Petition Liabilities Classified As Liabilities Subject To Compromise							1,396	2,077
Texas Competitive Electric Holdings Co LLC [Member]
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction								14	45
Related Party Transaction, Sale of Assets To Related Party		$ 52						$ 16
Energy Future Holdings Corp. [Member]
Related Party Transaction [Line Items]
Interest expense, related party									2	$ 5
Debt Instrument, Basis Spread on Variable Rate								5.00%
Intercompany payables							107		107
Accrued income taxes payable to parent								$ 10	16
Related party transaction, expenses from transactions with related party								29	33	137
Texas Competitive Electric Holdings Co LLC [Member]
Related Party Transaction [Line Items]
Contractual Interest Expense On Pre-Petition Liabilities Classified As Liabilities Subject To Compromise							1,392	2,070
Texas Competitive Electric Holdings Co LLC [Member] | Oncor [Member]
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction								1,000
Due to Affiliate							118		118
Delivery fee surcharge remitted to related party									17	16
Due to Affiliate, Noncurrent	409						479	409	479
Letter of credit posted as collateral	6						9	6	9
Event of credit rating downgrade, letter of credit required to be posted to secure payment obligations	$ 170							$ 170
Event of credit rating downgrade, minimum number of rating agencies downgrade below investment grade (in credit agencies downgrades) | Rating-Agencies-Downgrades	2							2
Texas Competitive Electric Holdings Co LLC [Member] | Related Party Transactions, Debt Held By Related Party [Member]
Related Party Transaction [Line Items]
Interest expense, related party								$ 1	13	38
Energy Future Holdings Corp. [Member] | Texas Competitive Electric Holdings Co LLC [Member]
Related Party Transaction [Line Items]
Repayments of Related Party Debt						$ 29			4
Selling, general and administrative expenses from transactions with related party								$ 205	204	241
Related Party Transaction, Selling, General and Administrative Expenses From Transactions With Related Party, Allocated To Subsidiary									$ 10	29
Energy Future Holdings Corp. [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Related Party Transactions, Note Payable, Average Daily Balance Between Affiliated Entities										57
Debt Instrument, Basis Spread on Variable Rate								5.00%	5.00%
Related Party Transaction, Interest Income										$ 3
Letter of Credit [Member] | Texas Competitive Electric Holdings Co LLC [Member]
Related Party Transaction [Line Items]
Letters Of Credit Drawn By Affiliated Party									$ 7
Senior Notes [Member] | Texas Competitive Electric Holdings Co LLC [Member]
Related Party Transaction [Line Items]
Long-term Debt Held by Affiliates	$ 382						382	$ 382	$ 382
Amounts in Escrow Related to August 2012 Debt Issuances [Member] | 11.75% Fixed Senior Secured Second Lien Notes due March 1, 2022 [Member] | Secured Debt [Member] | Energy Future Intermediate Holding Co LLC [Member]
Related Party Transaction [Line Items]
Restricted cash											$ 680
Related Party Transactions, Debt Held By Related Party [Member] | Texas Competitive Electric Holdings Co LLC [Member]
Related Party Transaction [Line Items]
Contractual Interest Expense On Pre-Petition Liabilities Classified As Liabilities Subject To Compromise							$ 25	$ 37
Pension Plan [Member]
Related Party Transaction [Line Items]
Defined Benefit Plan Contributions By Employer Excluding Affiliated Supplemental Plan	67		$ 84
Pension Plan [Member] | Texas Competitive Electric Holdings Co LLC [Member]
Related Party Transaction [Line Items]
Defined Benefit Plan, Contributions by Employer	16				$ 20
Oncor [Member] | Pension Plan [Member] | Majority-Owned Subsidiary, Unconsolidated [Member]
Related Party Transaction [Line Items]
Defined Benefit Plan, Contributions by Employer	$ 51		$ 64
Subsequent Event [Member] | Texas Competitive Electric Holdings Co LLC [Member]
Related Party Transaction [Line Items]
Related party transaction, amounts of transaction				$ 2

Related-Party Transactions (Ene

Related-Party Transactions (Energy Future Competitive Holdings CO Related Party Information) (Details) - USD ($) $ in Millions	8 Months Ended	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2015
Related Party Transaction [Line Items]
Contractual Interest Expense On Pre-Petition Liabilities Classified As Liabilities Subject To Compromise	$ 1,396	$ 2,077
Energy Future Holdings Corp. [Member]
Related Party Transaction [Line Items]
Intercompany payables	107
Texas Competitive Electric Holdings Co LLC [Member]
Related Party Transaction [Line Items]
Contractual Interest Expense On Pre-Petition Liabilities Classified As Liabilities Subject To Compromise	1,392	2,070
Texas Competitive Electric Holdings Co LLC [Member] | Debt held by related party [Member]
Related Party Transaction [Line Items]
Intercompany payables	382
Texas Competitive Electric Holdings Co LLC [Member] | Energy Future Holdings Corp. [Member] | Senior Notes [Member] | Debt held by related party [Member]
Related Party Transaction [Line Items]
Intercompany payables	284	284
Texas Competitive Electric Holdings Co LLC [Member] | Energy Future Holdings Corp. [Member] | Term loan Facilities [Member] | Debt held by related party [Member]
Related Party Transaction [Line Items]
Intercompany payables	19	19
Texas Competitive Electric Holdings Co LLC [Member] | Energy Future Intermediate Holding Co LLC [Member] | Senior Notes [Member] | Debt held by related party [Member]
Related Party Transaction [Line Items]
Intercompany payables	79	79
Debt held by related party [Member] | Texas Competitive Electric Holdings Co LLC [Member]
Related Party Transaction [Line Items]
Contractual Interest Expense On Pre-Petition Liabilities Classified As Liabilities Subject To Compromise	$ 25	$ 37

Supplementary Financial Infor90

Supplementary Financial Information (Schedule of Restricted Cash) (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted Cash and Investments, Current		$ 519	$ 2
Restricted Cash, Noncurrent		507	901
Other Restricted Cash [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted Cash and Investments, Current		0	2
Restricted Cash, Noncurrent		0	0
Texas Competitive Electric Holdings Co LLC [Member] | Amount Related To Texas Competitive Electric Company LLC Debtor-In-Possession Facility [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted Cash and Investments, Current		519	0
Restricted Cash, Noncurrent		0	350
Texas Competitive Electric Holdings Co LLC [Member] | Amounts Related to TCEH's Letter of Credit Facility [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted Cash and Investments, Current	[1]	0	0
Restricted Cash, Noncurrent	[1]	$ 507	$ 551
[1]	See Note 12 for discussion of letter of credit draws in 2014 and 2015.

Supplementary Financial Infor91

Supplementary Financial Information (Schedule of Trade Accounts Receivable) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2011
Receivables [Abstract]
Accounts Receivable, Gross, Current	$ 542	$ 603
Allowance for Doubtful Accounts Receivable, Current	(9)	(15)	$ (14)	$ (9)
Trade accounts receivable — net (Note 19)	533	588
Unbilled Receivables, Current	231	239
Provision for Doubtful Accounts	34	38	33
Allowance for Doubtful Accounts Receivable, Write-offs	$ (40)	$ (37)	$ (28)

Supplementary Financial Infor92

Supplementary Financial Information (Inventories by Major Category and Other Investments) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Inventories by Major Category
Materials and supplies	$ 226	$ 214
Fuel stock	170	215
Natural gas in storage	32	39
Total inventories	428	468
Other Investments
Nuclear plant decommissioning trust	918	893
Assets related to employee benefit plans, including employee savings programs, net of distributions	1	1
Land	36	37
Miscellaneous other	7	10
Total investments	$ 962	$ 941

Supplementary Financial Infor93

Supplementary Financial Information (Nuclear Decommissioning Trust) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule of Schedule of Decommissioning Fund Investments [Line Items]
Cost	[1]	$ 601	$ 564
Unrealized gain		326	333
Unrealized loss		(9)	(4)
Fair market value		918	893
Realized gains		1	11	$ 2
Realized losses		(1)	(2)	(4)
Proceeds from sales of securities		401	314	175
Investments in securities		(418)	(331)	$ (191)
Debt securities [Member]
Schedule of Schedule of Decommissioning Fund Investments [Line Items]
Cost	[1],[2]	310	288
Unrealized gain	[2]	11	13
Unrealized loss	[2]	(2)	0
Fair market value	[2]	$ 319	$ 301
Debt securities, average coupon rate (as a percent)		3.68%	4.35%
Decommissioning Fund Investments, Debt securities, average maturity		8 years	6 years
Decommissioning Fund Investments, debt maturities, one through five years, fair value		$ 102
Decommissioning Fund Investments, debt maturities, five through ten years, fair value		75
Decommissioning Fund Investments, debt maturities, after ten years, fair value		142
Equity securities [Member]
Schedule of Schedule of Decommissioning Fund Investments [Line Items]
Cost	[1],[3]	291	$ 276
Unrealized gain	[3]	315	320
Unrealized loss	[3]	(7)	(4)
Fair market value	[3]	$ 599	$ 592
[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. The debt securities are heavily weighted with municipal bonds. The debt securities had an average coupon rate of 3.68% and 4.35% at December 31, 2015 and 2014, respectively, and an average maturity of 8 years and 6 years at December 31, 2015 and 2014, respectively.
[3]	The investment objective for equity securities is to invest tax efficiently and to match the performance of the S&P 500 Index.

Supplementary Financial Infor94

Supplementary Financial Information (Property, Plant and Equipment) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	$ 11,432	$ 15,512
Less accumulated amortization/depreciation	2,654	3,948
Net of accumulated depreciation	8,778	11,564
Construction work in progress	323	459
Nuclear fuel (net of accumulated amortization of $1.383 billion and $1.237 billion)	248	265
Property, plant and equipment — net	9,349	12,288
Depreciation expense	767	1,154	$ 1,231
Capital Leases, Balance Sheet, Assets by Major Class, Net	1	51
Generation and mining [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	10,886	14,986
Other assets [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	546	526
Nuclear fuel [Member]
Property, Plant and Equipment [Line Items]
Less accumulated amortization/depreciation	$ 941	$ 776
Minimum [Member] | Lignite- And Nuclear-Fueled Generation Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	17 years
Maximum [Member] | Lignite- And Nuclear-Fueled Generation Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	54 years

Supplementary Financial Infor95

Supplementary Financial Information (Asset Retirement and Mining Reclamation Obligations) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance, Liability		$ 614		$ 524
Additions:
Accretion		51		48
Asset Retirement Obligation, Adjustment For New Cost Estimate	[1]	70
Incremental reclamation costs		153	[2]	127	[3]
Reductions:
Payments		(58)		(85)
Ending balance, Liability		614		524		$ 830	$ 614
Less amounts due currently						(66)
Noncurrent liability at December 31, 2015						764	560
Nuclear Plant Decommissioning [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance, Liability		413		390
Additions:
Accretion		25		23
Asset Retirement Obligation, Adjustment For New Cost Estimate	[1]	70
Incremental reclamation costs		0	[2]	0	[3]
Reductions:
Payments		0		0
Ending balance, Liability		413		390		508	413
Less amounts due currently						0
Noncurrent liability at December 31, 2015						508
Mining Land Reclamation [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance, Liability		165		98
Additions:
Accretion		20		22
Asset Retirement Obligation, Adjustment For New Cost Estimate	[1]	0
Incremental reclamation costs		84	[2]	127	[3]
Reductions:
Payments		(54)		(82)
Ending balance, Liability		165		98		215	165
Less amounts due currently						(66)
Noncurrent liability at December 31, 2015						149
Other Asset Retirement Obligations [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance, Liability		36		36
Additions:
Accretion		6		3
Asset Retirement Obligation, Adjustment For New Cost Estimate	[1]	0
Incremental reclamation costs	[3]	69	[2]	0
Reductions:
Payments		(4)		(3)
Ending balance, Liability		$ 36		$ 36		107	$ 36
Less amounts due currently						0
Noncurrent liability at December 31, 2015						$ 107
[1]	The adjustment for nuclear plant decommissioning resulted from a new cost estimate completed in the second quarter of 2015. Under applicable accounting standards, the liability is remeasured when significant changes in the amount or timing of cash flows occurs, and PUCT rules require a new cost estimate at least every five years. The increase in the liability was driven by increased security and fuel-handling costs.
[2]	The adjustment for other asset retirement obligations resulted from the effect on our estimated retirement obligation related to coal combustion residual facilities at our lignite/coal fueled generation facilities that arose from the CCR rule discussed above.
[3]	The increase in the mining reclamation liability of $127 million during 2014 was primarily due to final remediation for certain mines occurring sooner than previously estimated and increases in remediation cost estimates at other mining locations.

Supplementary Financial Infor96

Supplementary Financial Information (Other Noncurrent Liabilities and Deferred Credits) (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Supplementary Financial Information [Abstract]
Uncertain tax positions (including accrued interest) (Note 5)		$ 41	$ 74
Asset retirement and mining reclamation obligations		764	560
Unfavorable purchase and sales contracts		543	566
Nuclear decommissioning fund excess over asset retirement obligation (Note 18)		409	479
Other, including retirement and other employee benefits		23	21
Total other noncurrent liabilities and deferred credits		1,780	1,700
Amortization of Deferred Charges
Amortization of Unfavorable Purchase and Sales Contracts	$ 20	23	$ 23	$ 25
Future Amortization Expense
2,016		24
2,017		24
2,018		24
2,019		24
2,020		$ 24

Supplementary Financial Infor97

Supplementary Financial Information (Fair Value Of Debt) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Debtor-In-Possession Facility [Member] | Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [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, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	49	76
Fair Value, Inputs, Level 2 [Member] | Debtor-In-Possession Facility [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	1,411	1,430
Fair Value, Inputs, Level 2 [Member] | Long-Term Debt, Including Amounts Due Currently [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument, Fair Value Disclosure	$ 53	$ 79

Supplementary Financial Infor98

Supplementary Financial Information (Supplemental Cash Flow Information) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Other Significant Noncash Transactions [Line Items]
Principal Amount Of Affiliate Debt Given In Exchange Transaction			$ 838
Cash payments related to:
Interest paid	[1]	$ 1,302	1,259	$ 2,695
Capitalized interest		(11)	(17)	(25)
Interest paid (net of capitalized interest)	[1]	1,291	1,242	2,670
Income taxes		29	33	137
Reorganization Payments For Legal And Other Consulting Services	[2]	224	93	0
Noncash investing and financing activities:
Effect of Parent's payment of interest on pushed-down debt		0	0	23
Construction expenditures	[3]	75	108	45
Contribution to membership interests (Note 18)		0	2	2
Reduction of debt pushed down from EFH Corp. (Note 12) (d)	[4]	0	0	(420)
Debt exchange transactions	[5]	0	0	(340)
Debt Assumed Related to Acquisition of Owner Participant Interest in Trust, Noncash		$ 0	$ 0	$ (45)
Push Down Debt [Member] | Energy Future Holdings Corp. [Member]
Other Significant Noncash Transactions [Line Items]
Debt Instrument, Percentage of principal plus unamortized premium of Parent Merger-related debt guaranteed by subsidiary		50.00%	50.00%
[1]	Net of amounts received under interest rate swap agreements. For the years ended December 31, 2015 and 2014, this amount also includes amounts paid for adequate protection.
[2]	Represents cash payments for legal and other consulting services.
[3]	Represents end-of-period accruals.
[4]	For the year ended December 31, 2013, represents $838 million principal amount of EFH Corp. debt exchanged (at 50%). See Note 12.
[5]	Principal amounts of incremental loans under the TCEH Term Loan Facilities issued in consideration for the extension of the maturity date of such facilities.

Supplemental Guarantor Conden99

Supplemental Guarantor Condensed Financial Information (Narrative) (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Condensed Financial Statements, Captions [Line Items]
Long-term debt, gross	[1]		$ 38
Push Down Debt [Member]
Condensed Financial Statements, Captions [Line Items]
Long-term debt, gross		$ 30
Energy Future Holdings Senior Notes [Member] | Push Down Debt [Member]
Condensed Financial Statements, Captions [Line Items]
Long-term debt, gross		30
Energy Future Holdings Senior Secured Notes to Parent [Member] | Push Down Debt [Member]
Condensed Financial Statements, Captions [Line Items]
Long-term debt, gross		$ 0
[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.

Supplemental Guarantor Conde100

Supplemental Guarantor Condensed Financial Information (Condensed Consolidating Statements of Income (Loss)) (Details) - USD ($) $ in Millions	1 Months Ended	8 Months Ended	12 Months Ended
	Sep. 30, 2014	Dec. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]
Operating revenues			$ 5,370	$ 5,978	$ 5,899
Fuel, purchased power costs and delivery fees			(2,692)	(2,842)	(2,848)
Net gain from commodity hedging and trading activities			334	11	(54)
Operating costs			(834)	(914)	(881)
Depreciation and amortization			(852)	(1,270)	(1,333)
Selling, general and administrative expenses			(676)	(708)	(756)
Impairment of goodwill	$ (1,600)		(2,200)	(1,600)	(1,000)
Impairment of long-lived assets (Note 8)			(2,541)	(4,670)	(140)
Other income			17	16	9
Other deductions			(93)	(281)	(22)
Interest income			0	0	5
Interest expense and related charges			(1,293)	(1,758)	(1,933)
Reorganization items (Note 10)		$ (521)	(1)	(521)	0
Loss before income taxes			(5,461)	(8,559)	(3,054)
Income tax benefit (expense)			858	2,330	737
Equity earnings (losses) of subsidiaries			0	0	0
Net loss			(4,603)	(6,229)	(2,317)
Net loss attributable to noncontrolling interests			0	0	107
Net loss attributable to noncontrolling interests			2	1	6
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest			(4,601)	(6,228)	(2,311)
Net income (loss) attributable to EFCH			(4,603)	(6,229)	(2,210)
Comprehensive loss attributable to EFCH			(4,601)	(6,228)	(2,204)
Parent/ Guarantor [Member]
Condensed Financial Statements, Captions [Line Items]
Operating revenues			0	0	0
Fuel, purchased power costs and delivery fees			0	0	0
Net gain from commodity hedging and trading activities			0	0	0
Operating costs			0	0	0
Depreciation and amortization			0	0	0
Selling, general and administrative expenses			0	0	0
Impairment of goodwill			0	0	0
Impairment of long-lived assets (Note 8)			0	0	0
Other income			0	0	0
Other deductions			0	0	0
Interest income			0	1	1
Interest expense and related charges			(6)	(10)	(19)
Reorganization items (Note 10)			100	0
Loss before income taxes			94	(9)	(18)
Income tax benefit (expense)			(20)	9	5
Equity earnings (losses) of subsidiaries			(4,677)	(6,229)	(2,304)
Net loss			(4,603)	(6,229)	(2,317)
Net loss attributable to noncontrolling interests			0	0	107
Net loss attributable to noncontrolling interests			2	1	6
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest			(4,601)	(6,228)	(2,311)
Net income (loss) attributable to EFCH			(4,603)	(6,229)	(2,210)
Comprehensive loss attributable to EFCH			(4,601)	(6,228)	(2,204)
Issuer [Member]
Condensed Financial Statements, Captions [Line Items]
Operating revenues			0	0	0
Fuel, purchased power costs and delivery fees			0	0	0
Net gain from commodity hedging and trading activities			0	(90)	(56)
Operating costs			0	0	0
Depreciation and amortization			(8)	0	0
Selling, general and administrative expenses			5	(29)	(64)
Impairment of goodwill			(2,200)	(1,600)	(1,000)
Impairment of long-lived assets (Note 8)			0	0	0
Other income			0	0	0
Other deductions			(2)	(4)	0
Interest income			26	81	243
Interest expense and related charges			(1,419)	(2,045)	(2,716)
Reorganization items (Note 10)			(1,428)	(500)
Loss before income taxes			(5,026)	(4,187)	(3,593)
Income tax benefit (expense)			697	846	828
Equity earnings (losses) of subsidiaries			(348)	(2,888)	461
Net loss			(4,677)	(6,229)	(2,304)
Net loss attributable to noncontrolling interests			0	0	107
Net loss attributable to noncontrolling interests			2	1	6
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest			(4,675)	(6,228)	(2,298)
Net income (loss) attributable to EFCH			(4,677)	(6,229)	(2,197)
Comprehensive loss attributable to EFCH			(4,675)	(6,228)	(2,191)
Other Guarantors [Member]
Condensed Financial Statements, Captions [Line Items]
Operating revenues			5,370	5,978	5,899
Fuel, purchased power costs and delivery fees			(2,692)	(2,842)	(2,848)
Net gain from commodity hedging and trading activities			334	101	2
Operating costs			(834)	(914)	(881)
Depreciation and amortization			(844)	(1,270)	(1,333)
Selling, general and administrative expenses			(681)	(677)	(723)
Impairment of goodwill			0	0	0
Impairment of long-lived assets (Note 8)			(2,541)	(4,670)	0
Other income			12	14	9
Other deductions			(91)	(277)	(22)
Interest income			125	285	795
Interest expense and related charges			(19)	(802)	(2,462)
Reorganization items (Note 10)			1,327	(21)
Loss before income taxes			(534)	(5,095)	(1,564)
Income tax benefit (expense)			164	1,710	664
Equity earnings (losses) of subsidiaries			1	1	(23)
Net loss			(369)	(3,384)	(923)
Net loss attributable to noncontrolling interests			0	0	0
Net loss attributable to noncontrolling interests			0	0	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest			(369)	(3,384)	(923)
Net income (loss) attributable to EFCH			(369)	(3,384)	(923)
Comprehensive loss attributable to EFCH			(369)	(3,384)	(923)
Non-guarantors [Member]
Condensed Financial Statements, Captions [Line Items]
Operating revenues			0	0	59
Fuel, purchased power costs and delivery fees			0	0	0
Net gain from commodity hedging and trading activities			0	0	0
Operating costs			0	0	0
Depreciation and amortization			0	0	0
Selling, general and administrative expenses			0	(2)	(28)
Impairment of goodwill			0	0	0
Impairment of long-lived assets (Note 8)			0	0	(140)
Other income			5	2	0
Other deductions			0	0	0
Interest income			0	0	0
Interest expense and related charges			0	0	(10)
Reorganization items (Note 10)			0	0
Loss before income taxes			5	0	(119)
Income tax benefit (expense)			(4)	1	4
Equity earnings (losses) of subsidiaries			0	0	0
Net loss			1	1	(115)
Net loss attributable to noncontrolling interests			0	0	107
Net loss attributable to noncontrolling interests			0	0	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest			1	1	(115)
Net income (loss) attributable to EFCH			1	1	(8)
Comprehensive loss attributable to EFCH			1	1	(8)
Eliminations [Member]
Condensed Financial Statements, Captions [Line Items]
Operating revenues			0	0	(59)
Fuel, purchased power costs and delivery fees			0	0	0
Net gain from commodity hedging and trading activities			0	0	0
Operating costs			0	0	0
Depreciation and amortization			0	0	0
Selling, general and administrative expenses			0	0	59
Impairment of goodwill			0	0	0
Impairment of long-lived assets (Note 8)			0	0	0
Other income			0	0	0
Other deductions			0	0	0
Interest income			(151)	(367)	(1,034)
Interest expense and related charges			151	1,099	3,274
Reorganization items (Note 10)			0	0
Loss before income taxes			0	732	2,240
Income tax benefit (expense)			21	(236)	(764)
Equity earnings (losses) of subsidiaries			5,024	9,116	1,866
Net loss			5,045	9,612	3,342
Net loss attributable to noncontrolling interests			0	0	(214)
Net loss attributable to noncontrolling interests			(2)	(1)	(6)
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest			5,043	9,611	3,336
Net income (loss) attributable to EFCH			5,045	9,612	3,128
Comprehensive loss attributable to EFCH			$ 5,043	$ 9,611	$ 3,122

Supplemental Guarantor Conde101

Supplemental Guarantor Condensed Financial Information (Consolidating Statements of Comprehensive Income (Loss)) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Net loss	$ (4,603)	$ (6,229)	$ (2,317)
Net loss attributable to noncontrolling interests	2	1	6
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	(4,601)	(6,228)	(2,311)
Comprehensive (Income) Loss, Net of Tax, Attributable to Noncontrolling Interest	0	0	107
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	(4,601)	(6,228)	(2,204)
Parent/ Guarantor [Member]
Net loss	(4,603)	(6,229)	(2,317)
Net loss attributable to noncontrolling interests	2	1	6
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	(4,601)	(6,228)	(2,311)
Comprehensive (Income) Loss, Net of Tax, Attributable to Noncontrolling Interest	0	0	(107)
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	(4,601)	(6,228)	(2,204)
Issuer [Member]
Net loss	(4,677)	(6,229)	(2,304)
Net loss attributable to noncontrolling interests	2	1	6
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	(4,675)	(6,228)	(2,298)
Comprehensive (Income) Loss, Net of Tax, Attributable to Noncontrolling Interest	0	0	(107)
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	(4,675)	(6,228)	(2,191)
Other Guarantors [Member]
Net loss	(369)	(3,384)	(923)
Net loss attributable to noncontrolling interests	0	0	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	(369)	(3,384)	(923)
Comprehensive (Income) Loss, Net of Tax, Attributable to Noncontrolling Interest	0	0	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	(369)	(3,384)	(923)
Non-guarantors [Member]
Net loss	1	1	(115)
Net loss attributable to noncontrolling interests	0	0	0
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	1	1	(115)
Comprehensive (Income) Loss, Net of Tax, Attributable to Noncontrolling Interest	0	0	(107)
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	1	1	(8)
Consolidation, Eliminations [Member]
Net loss	5,045	9,612	3,342
Net loss attributable to noncontrolling interests	(2)	(1)	(6)
Comprehensive Income (Loss), Net of Tax, Including Portion Attributable to Noncontrolling Interest	5,043	9,611	3,336
Comprehensive (Income) Loss, Net of Tax, Attributable to Noncontrolling Interest	0	0	214
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	$ 5,043	$ 9,611	$ 3,122

Supplemental Guarantor Conde102

Supplemental Guarantor Condensed Financial Information (Condensed Consolidating Statements of Cash Flows) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]
Cash provided by (used in) operating activities	$ 229	$ 437	$ (271)
Cash flows – financing activities:
Proceeds from the DIP Facility before fees paid (Note 11)	0	1,425	0
Fees paid for the DIP Facility (Note 10)	(9)	(92)	0
Notes/advances due to affiliates	0	0
Repayments/repurchases of debt	(34)	(235)	(105)
Net borrowings under accounts receivable securitization program	0	0	(82)
Proceeds from Contributions from Affiliates			0
Contributions from noncontrolling interests		1
Other, net	0	1	13
Cash provided by (used in) financing activities	(43)	1,099	(174)
Cash flows – investing activities:
Capital expenditures	(337)	(336)	(472)
Nuclear fuel purchases	(123)	(77)	(116)
Settlements of notes due from affiliates	(16)	(15)	698
Investment in subsidiary			0
Purchase of right to use certain computer-related assets from parent (Note 18)	0	(4)	(29)
Acquisition of combustion turbine trust interest	0	0	(40)
Changes in restricted cash	(123)	42	2
Proceeds from sales of nuclear decommissioning trust fund securities (Note 19)	401	314	175
Investments in nuclear decommissioning trust fund securities (Note 19)	(418)	(331)	(191)
Other, net	(13)	(32)	(11)
Cash provided by (used in) investing activities	(629)	(439)	16
Net change in cash and cash equivalents	(443)	1,097	(429)
Cash and cash equivalents — beginning balance	1,843	746	1,175
Parent/ Guarantor [Member]
Condensed Financial Statements, Captions [Line Items]
Cash provided by (used in) operating activities	(8)	(7)	(1)
Cash flows – financing activities:
Proceeds from the DIP Facility before fees paid (Note 11)		0
Fees paid for the DIP Facility (Note 10)	0	0
Notes/advances due to affiliates	21	19
Repayments/repurchases of debt	(13)	(12)	(11)
Net borrowings under accounts receivable securitization program			0
Proceeds from Contributions from Affiliates			0
Contributions from noncontrolling interests		0
Other, net			12
Cash provided by (used in) financing activities	8	7	1
Cash flows – investing activities:
Capital expenditures	0	0	0
Nuclear fuel purchases	0	0	0
Settlements of notes due from affiliates	0	0	0
Investment in subsidiary			0
Purchase of right to use certain computer-related assets from parent (Note 18)		0	0
Acquisition of combustion turbine trust interest			0
Changes in restricted cash	0	0	0
Proceeds from sales of nuclear decommissioning trust fund securities (Note 19)	0	0	0
Investments in nuclear decommissioning trust fund securities (Note 19)	0	0	0
Other, net	0	0	0
Cash provided by (used in) investing activities	0	0	0
Net change in cash and cash equivalents	0	0	0
Cash and cash equivalents — beginning balance	0	0
Issuer [Member]
Condensed Financial Statements, Captions [Line Items]
Cash provided by (used in) operating activities	(1,607)	(1,498)	(1,643)
Cash flows – financing activities:
Proceeds from the DIP Facility before fees paid (Note 11)		1,425
Fees paid for the DIP Facility (Note 10)	(9)	(92)
Notes/advances due to affiliates	1,297	1,462
Repayments/repurchases of debt	0	(203)	(64)
Net borrowings under accounts receivable securitization program			0
Proceeds from Contributions from Affiliates			0
Contributions from noncontrolling interests		0
Other, net			1,461
Cash provided by (used in) financing activities	1,288	2,592	1,397
Cash flows – investing activities:
Capital expenditures	(2)	0	0
Nuclear fuel purchases	0	0	0
Settlements of notes due from affiliates	0	0	0
Investment in subsidiary			(146)
Purchase of right to use certain computer-related assets from parent (Note 18)		0	0
Acquisition of combustion turbine trust interest			0
Changes in restricted cash	(124)	44	2
Proceeds from sales of nuclear decommissioning trust fund securities (Note 19)	0	0	0
Investments in nuclear decommissioning trust fund securities (Note 19)	0	0	0
Other, net	(13)	(37)	0
Cash provided by (used in) investing activities	(139)	7	(144)
Net change in cash and cash equivalents	(458)	1,101	(390)
Cash and cash equivalents — beginning balance	1,826	725
Other Guarantors [Member]
Condensed Financial Statements, Captions [Line Items]
Cash provided by (used in) operating activities	1,846	1,947	1,458
Cash flows – financing activities:
Proceeds from the DIP Facility before fees paid (Note 11)		0
Fees paid for the DIP Facility (Note 10)	0	0
Notes/advances due to affiliates	0	0
Repayments/repurchases of debt	(21)	(20)	(30)
Net borrowings under accounts receivable securitization program			0
Proceeds from Contributions from Affiliates			0
Contributions from noncontrolling interests		0
Other, net			0
Cash provided by (used in) financing activities	(21)	(20)	(30)
Cash flows – investing activities:
Capital expenditures	(335)	(336)	(467)
Nuclear fuel purchases	(123)	(77)	(116)
Settlements of notes due from affiliates	(1,336)	(1,496)	(758)
Investment in subsidiary			10
Purchase of right to use certain computer-related assets from parent (Note 18)		(4)	(29)
Acquisition of combustion turbine trust interest			(40)
Changes in restricted cash	1	(2)	0
Proceeds from sales of nuclear decommissioning trust fund securities (Note 19)	401	314	175
Investments in nuclear decommissioning trust fund securities (Note 19)	(418)	(331)	(191)
Other, net	(9)	5	(11)
Cash provided by (used in) investing activities	(1,819)	(1,927)	(1,427)
Net change in cash and cash equivalents	6	0	1
Cash and cash equivalents — beginning balance	16	16
Non-guarantors [Member]
Condensed Financial Statements, Captions [Line Items]
Cash provided by (used in) operating activities	(2)	(5)	(85)
Cash flows – financing activities:
Proceeds from the DIP Facility before fees paid (Note 11)		0
Fees paid for the DIP Facility (Note 10)	0	0
Notes/advances due to affiliates	2	0
Repayments/repurchases of debt	0	0	0
Net borrowings under accounts receivable securitization program			(82)
Proceeds from Contributions from Affiliates			136
Contributions from noncontrolling interests		1
Other, net			(4)
Cash provided by (used in) financing activities	2	1	50
Cash flows – investing activities:
Capital expenditures	0	0	(5)
Nuclear fuel purchases	0	0	0
Settlements of notes due from affiliates	0	0	0
Investment in subsidiary			0
Purchase of right to use certain computer-related assets from parent (Note 18)		0	$ 0
Acquisition of combustion turbine trust interest
Changes in restricted cash	0	0	$ 0
Proceeds from sales of nuclear decommissioning trust fund securities (Note 19)	0	0	0
Investments in nuclear decommissioning trust fund securities (Note 19)	0	0	0
Other, net	9	0	0
Cash provided by (used in) investing activities	9	0	(5)
Net change in cash and cash equivalents	9	(4)	(40)
Cash and cash equivalents — beginning balance	1	5
Eliminations [Member]
Condensed Financial Statements, Captions [Line Items]
Cash provided by (used in) operating activities	0	0	0
Cash flows – financing activities:
Proceeds from the DIP Facility before fees paid (Note 11)		0
Fees paid for the DIP Facility (Note 10)	0	0
Notes/advances due to affiliates	(1,320)	(1,481)
Repayments/repurchases of debt	0	0	0
Net borrowings under accounts receivable securitization program			0
Proceeds from Contributions from Affiliates			(136)
Contributions from noncontrolling interests		0
Other, net			(1,456)
Cash provided by (used in) financing activities	(1,320)	(1,481)	(1,592)
Cash flows – investing activities:
Capital expenditures	0	0	0
Nuclear fuel purchases	0	0	0
Settlements of notes due from affiliates	1,320	1,481	1,456
Investment in subsidiary			136
Purchase of right to use certain computer-related assets from parent (Note 18)		0	0
Acquisition of combustion turbine trust interest			0
Changes in restricted cash	0	0	0
Proceeds from sales of nuclear decommissioning trust fund securities (Note 19)	0	0	0
Investments in nuclear decommissioning trust fund securities (Note 19)	0	0	0
Other, net	0	0	0
Cash provided by (used in) investing activities	1,320	1,481	1,592
Net change in cash and cash equivalents	0	0	$ 0
Cash and cash equivalents — beginning balance	$ 0	$ 0

Supplemental Guarantor Conde103

Supplemental Guarantor Condensed Financial Information (Condensed Consolidating Balance Sheets) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Current assets:
Cash and cash equivalents	$ 1,400	$ 1,843	$ 746	$ 1,175	$ 1,175
Restricted cash	519	2
Advances to affiliates		8
Accounts receivable	533	588
Income taxes receivable		0
Accounts Receivable, Related Parties, Current	0
Accounts receivable from affiliates	6	8
Inventories	428	468
Commodity and other derivative contractual assets	465	492
Other current assets	71	68
Total current assets	3,422	3,469
Restricted cash	507	901
Investments	962	941
Property, plant and equipment	9,349	12,288
Advance to parent	18	7
Goodwill	152	2,352
Identifiable intangible assets – net	1,179	1,336
Accumulated deferred income taxes	0	0
Other noncurrent assets	39	39
Total assets	15,628	21,333
Current liabilities:
Short-term Debt	1,425
Notes/advances from affiliates		0
Notes, loans and other debt	31	35
Trade accounts payable	394	382
Trade accounts and other payables to affiliates	119	165
Commodity and other derivative contractual liabilities	203	316
Margin deposits related to commodity positions	152	26
Accumulated deferred income taxes	0	114
Accrued income taxes payable to parent	10	16
Accrued taxes other than income	98	107
Accrued interest	120	117
Other current liabilities	274	264
Total current liabilities	2,826	1,542
Accumulated deferred income taxes	213	1,022
Notes or other liabilities due affiliates	0
Debtor-in-Possession Financing, Borrowings Outstanding	0	1,425
Long-term Debt and Capital Lease Obligations	23	85
Liabilities subject to compromise (Note 12)	33,776	34,033
Other noncurrent liabilities and deferred credits	1,780	1,700
Total liabilities	38,618	39,807
EFCH membership interests		(18,474)
Noncontrolling interests in subsidiaries		0
Total membership interests	(22,990)	(18,474)	(12,268)
Total liabilities and membership interests	15,628	21,333
Parent/ Guarantor [Member]
Current assets:
Cash and cash equivalents	0	0	0		0
Restricted cash	0	0
Advances to affiliates		0
Accounts receivable	0	0
Income taxes receivable		0
Accounts Receivable, Related Parties, Current	0
Accounts receivable from affiliates	0
Inventories	0	0
Commodity and other derivative contractual assets	0	0
Other current assets	0	0
Total current assets	0	0
Restricted cash	0	0
Investments	(32,818)	(28,114)
Property, plant and equipment	0	0
Advance to parent	0	0
Goodwill	0	0
Identifiable intangible assets – net	0	0
Accumulated deferred income taxes	0	0
Other noncurrent assets	0	0
Total assets	(32,818)	(28,114)
Current liabilities:
Short-term Debt	0
Notes/advances from affiliates		8
Notes, loans and other debt	15	13
Trade accounts payable	0	0
Trade accounts and other payables to affiliates	0	2
Commodity and other derivative contractual liabilities	0	0
Margin deposits related to commodity positions	0	0
Accumulated deferred income taxes		24
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	15	47
Accumulated deferred income taxes	0	40
Notes or other liabilities due affiliates	0
Debtor-in-Possession Financing, Borrowings Outstanding		0
Long-term Debt and Capital Lease Obligations	20	34
Liabilities subject to compromise (Note 12)	44	144
Other noncurrent liabilities and deferred credits	0	0
Total liabilities	79	265
EFCH membership interests		(28,379)
Noncontrolling interests in subsidiaries		0
Total membership interests	(32,897)	(28,379)
Total liabilities and membership interests	(32,818)	(28,114)
Issuer [Member]
Current assets:
Cash and cash equivalents	1,368	1,826	725		1,115
Restricted cash	519	0
Advances to affiliates		8
Accounts receivable	0	0
Income taxes receivable		176
Accounts Receivable, Related Parties, Current	92
Accounts receivable from affiliates	6
Inventories	0	0
Commodity and other derivative contractual assets	0	0
Other current assets	3	9
Total current assets	1,988	2,019
Restricted cash	507	901
Investments	9,095	10,845
Property, plant and equipment	12	34
Advance to parent	18	7
Goodwill	152	2,352
Identifiable intangible assets – net	31	14
Accumulated deferred income taxes	438	757
Other noncurrent assets	1	3
Total assets	12,242	16,932
Current liabilities:
Short-term Debt	1,425
Notes/advances from affiliates		1,171
Notes, loans and other debt	0	0
Trade accounts payable	21	7
Trade accounts and other payables to affiliates	0	7
Commodity and other derivative contractual liabilities	0	0
Margin deposits related to commodity positions	0	0
Accumulated deferred income taxes		47
Accrued income taxes payable to parent	0	0
Accrued taxes other than income	0	0
Accrued interest	119	116
Other current liabilities	32	37
Total current liabilities	1,597	1,385
Accumulated deferred income taxes	0	0
Notes or other liabilities due affiliates	0
Debtor-in-Possession Financing, Borrowings Outstanding		1,425
Long-term Debt and Capital Lease Obligations	0	0
Liabilities subject to compromise (Note 12)	43,468	42,239
Other noncurrent liabilities and deferred credits	(4)	(3)
Total liabilities	45,061	45,046
EFCH membership interests		(28,114)
Noncontrolling interests in subsidiaries		0
Total membership interests	(32,819)	(28,114)
Total liabilities and membership interests	12,242	16,932
Other Guarantors [Member]
Current assets:
Cash and cash equivalents	22	16	16		15
Restricted cash	0	2
Advances to affiliates		1,179
Accounts receivable	533	588
Income taxes receivable		0
Accounts Receivable, Related Parties, Current	0
Accounts receivable from affiliates	0
Inventories	428	468
Commodity and other derivative contractual assets	465	492
Other current assets	68	59
Total current assets	1,516	2,804
Restricted cash	0	0
Investments	983	958
Property, plant and equipment	9,334	12,251
Advance to parent	0	0
Goodwill	0	0
Identifiable intangible assets – net	1,148	1,322
Accumulated deferred income taxes	393	0
Other noncurrent assets	38	36
Total assets	13,412	17,371
Current liabilities:
Short-term Debt	0
Notes/advances from affiliates		0
Notes, loans and other debt	16	22
Trade accounts payable	373	375
Trade accounts and other payables to affiliates	211	154
Commodity and other derivative contractual liabilities	203	316
Margin deposits related to commodity positions	152	26
Accumulated deferred income taxes		43
Accrued income taxes payable to parent	10	192
Accrued taxes other than income	98	107
Accrued interest	1	1
Other current liabilities	242	227
Total current liabilities	1,306	1,463
Accumulated deferred income taxes	0	944
Notes or other liabilities due affiliates	0
Debtor-in-Possession Financing, Borrowings Outstanding		0
Long-term Debt and Capital Lease Obligations	3	51
Liabilities subject to compromise (Note 12)	31,601	32,581
Other noncurrent liabilities and deferred credits	1,784	1,703
Total liabilities	34,694	36,742
EFCH membership interests		(19,371)
Noncontrolling interests in subsidiaries		0
Total membership interests	(21,282)	(19,371)
Total liabilities and membership interests	13,412	17,371
Non-guarantors [Member]
Current assets:
Cash and cash equivalents	10	1	5		45
Restricted cash	0	0
Advances to affiliates		0
Accounts receivable	0	0
Income taxes receivable		0
Accounts Receivable, Related Parties, Current	0
Accounts receivable from affiliates	0
Inventories	0	0
Commodity and other derivative contractual assets	0	0
Other current assets	0	0
Total current assets	10	1
Restricted cash	0	0
Investments	5	8
Property, plant and equipment	3	3
Advance to parent	0	0
Goodwill	0	0
Identifiable intangible assets – net	0	0
Accumulated deferred income taxes	11	15
Other noncurrent assets	0	0
Total assets	29	27
Current liabilities:
Short-term Debt	0
Notes/advances from affiliates		0
Notes, loans and other debt	0	0
Trade accounts payable	0	0
Trade accounts and other payables to affiliates	0	2
Commodity and other derivative contractual liabilities	0	0
Margin deposits related to commodity positions	0	0
Accumulated deferred income taxes		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	2
Accumulated deferred income taxes	0	0
Notes or other liabilities due affiliates	2
Debtor-in-Possession Financing, Borrowings Outstanding		0
Long-term Debt and Capital Lease Obligations	0	0
Liabilities subject to compromise (Note 12)	0	0
Other noncurrent liabilities and deferred credits	0	0
Total liabilities	2	2
EFCH membership interests		25
Noncontrolling interests in subsidiaries		0
Total membership interests	27	25
Total liabilities and membership interests	29	27
Eliminations [Member]
Current assets:
Cash and cash equivalents	0	0	$ 0		$ 0
Restricted cash	0	0
Advances to affiliates		(1,179)
Accounts receivable	0	0
Income taxes receivable		(176)
Accounts Receivable, Related Parties, Current	(92)
Accounts receivable from affiliates	0
Inventories	0	0
Commodity and other derivative contractual assets	0	0
Other current assets	0	0
Total current assets	(92)	(1,355)
Restricted cash	0	0
Investments	23,697	17,244
Property, plant and equipment	0	0
Advance to parent	0	0
Goodwill	0	0
Identifiable intangible assets – net	0	0
Accumulated deferred income taxes	(842)	(772)
Other noncurrent assets	0	0
Total assets	22,763	15,117
Current liabilities:
Short-term Debt	0
Notes/advances from affiliates		(1,179)
Notes, loans and other debt	0	0
Trade accounts payable	0	0
Trade accounts and other payables to affiliates	(92)	0
Commodity and other derivative contractual liabilities	0	0
Margin deposits related to commodity positions	0	0
Accumulated deferred income taxes		0
Accrued income taxes payable to parent	0	(176)
Accrued taxes other than income	0	0
Accrued interest	0	0
Other current liabilities	0	0
Total current liabilities	(92)	(1,355)
Accumulated deferred income taxes	213	38
Notes or other liabilities due affiliates	(2)
Debtor-in-Possession Financing, Borrowings Outstanding		0
Long-term Debt and Capital Lease Obligations	0	0
Liabilities subject to compromise (Note 12)	(41,337)	(40,931)
Other noncurrent liabilities and deferred credits	0	0
Total liabilities	(41,218)	(42,248)
EFCH membership interests		57,365
Noncontrolling interests in subsidiaries		0
Total membership interests	63,981	57,365
Total liabilities and membership interests	$ 22,763	$ 15,117